ML20071J446
| ML20071J446 | |
| Person / Time | |
|---|---|
| Site: | Catawba  |
| Issue date: | 05/20/1983 |
| From: | Tucker H DUKE POWER CO. |
| To: | Adensam E, Harold Denton Office of Nuclear Reactor Regulation |
| References | |
| RTR-NUREG-0452, RTR-NUREG-452 NUDOCS 8305270005 | |
| Download: ML20071J446 (741) | |
Text
{{#Wiki_filter:DUKE POWER GOMPANY P.O. HOX 33180 CIIAHLOTrE, N.C. 28242 ILE B. TUCKER retzenown vna r.e.som.T (704) 373 4531 m m.... <<no. May 20, 1983 l Mr. Harold R. Denton, Director Office of Nuclear Reactor Regulation U. S. Nuclear Regulatory Commission Washington, D. C. 20555 Attention: Ms. E. G. Adensam, Chief Licensing Branch No. 4 Re: Catawba Iiuclear Station, Unit 1 Docket No. 50-413
Dear Mr. Denton:
Please find enclosed seven (7) copies of the proposed Cat awba Unit 1 Technical Specifications. These proposed Technical Specifications are in the form of marked-up NUREG-0452 Rev. 4 Standard Technical Specifications for Westinghouse Pressurized Water Reactors. If you have any questions regarding these proposed Catawba Unit 1 Technical Specifications, please contact Mr. Roger Ouellette at (704) 373-7530. Very truly yours, C' C l Hal B. Tucker RWO/php O Enclosures 3 cc: (w/o enclosure) Mr. James P. O'Reilly, Regional Administrator / / U. S. Nuclear Regulatory Commission Region II 101 Marietta Street, NW, Suite 2900 Atlanta, Georgia 30303 Mr. P. K. Van Doorn NRC Resident Inspector Catawba Nuclear Station Mr. Robert Guild, Esq. Attorney-at-Law Palmetto Alliance P. O. Box 12097 2135h Devine Street Charleston, South Carolina 29205 Columbia, South Carolina 29205 0305270005 830520 PDR ADDCK 05000413 A PDR
_cD -e:> - L. NUREG-0452 Revision 4
= = == c.mm Standard Technical Specifications for Westinghouse Pressurized Water Reactors 1 Revision Issued Fall 1981 Supercedes NUREG-0452, Revision 3 U.S. Nuclear Regulatory Commission
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l NUREG-0452 l Revision 4 l l l Standard Technical Specifr,ations for Westinghouse Pressurized Water Reactors Revision issued Fall 1981 Supercedes NUREG-0452, Revision 3 l
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I Available from GPO Sales Program Division of Technical Information and Document Control . U. S. Nuclear Regulatory Commission Washington, D. C. 20555 Printed copy price: $11.00 and National Technical Information Service Springfield, Virginia 22161
FOREWORD The following paragraphs briefly describe the applicability, format and imple-mentation of the Westinghouse Standard Technical Specification package. APPLICABILITY This Standard Technical Specification (STS) has been structured for the broadest possible use on Westinghouse plants currently being reviewed for an Operating License. Accordingly, the document contains specifications applicable to plants with (1) either 3 or 4 loops and (2) with and without loop stop valves. In addition, four separate and discrete containment specification sections are provided for each of the following containment types: Atmospheric, Ice Condenser, Sub-Atmospheric, and Dual. Optional specifications are provided for those features and systems which may be included in individual plant designs but are not generic in their scope of application. Alternate specifications are provided in a limited number of cases to cover situations where alternate specification requirements are necessary on a generic basis because of design differences. FORMAT The format of the STS addresses the categories required by 10 CFR and consists of six sections covering the areas of: Definitions, Safety Limits and Limiting Safety System Settings, Limiting Conditions for Operation, Surveillance Require-ments, Design Features, and Administrative Controls. The Limiting Conditions for Operation and Surveillance Requirements (Sections 3 and 4) are presented in a combined format with each LC0 appearing at the top of the page followed immediately by the applicable Surveillance Requirements. The combined Section 3/4 is further subdivided into ten subsections covering the areas of:
- 1. Reactivity Control,
- 2. Power Distribution,
- 3. Instrumentation,
- 4. Reactor Coolant System,
- 5. Emergency Core Cooling System,
- 6. Containment Systems,
, 7. Plant Systems, l i.
- 8. Electrical
- 9. Refueling Operations, and j 10. Special Test Exceptions.
- s The values of those parameters and variables which may vary because of plant design appear as either blanks or parenthesized numbers throughout the STS.
The actual value for each parameter will be provided by individual applicants as appropriate for their plants. The values in parentheses are for illustra-tion only. IMPLEMENTATION The implementation of the STS on an individual license application will proceed in three phases. The major steps within each phase are indicated below. Phase I The applicant should:
- 1. Obtain copies of the STS from the NRC.
- 2. Select the appropriate containment specification section and set aside the non-applicable containment sections and related bases.
- 3. Identify and mark those specifications not required because of plant design or other factors. Specifications within this category should be retained in position within the document package for later review and discussion.
i , 4. Identify those areas where specifications are required but are not provided in the STS.
- 5. Provide the applicable values of the parameters and variables identified by blanks or parenthes;;s in the STS. This information must be consistent with the SAR and other supporting documents.
- 6. Provide the figures, graphs and other information required to complete the STS document package.
Phase II
- 1. The Comission staff will review the information provided in the marked up STS document package resulting from the Phase I pre-paration.
1 i
- 2. Applicant / staff meeting will be held to resolve noted differences of position and other related coments from the applicant, vendor and A.E.
Phase III
- 1. The Comission will provide a Proof and Review edition of the technical specification for final review by all parties based upon the resolution of coments and positions in Phase II.
- 2. Final coments and corrections will be incorporated into the document as received.
- 3. The Technical Specifications will be issued by the Commission as Appendix "A" of the Operating License.
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INDEX DEFINITIONS SECTION PAGE 1.0 DEFINITIONS 1.1 ACTI0N........................................................ 1-1 1.2 ACTUATION LOGIC TEST.......................................... 1-1
- 1. 3 ANALOG CHANNEL OPERATIONAL TEST.............................. 1-1 1.4 AXIAL FLUX DIFFERENCE......................................... 1-1 1.5 CHANNEL CALIBRATION........................................... 1-1 1.6 CHANNEL CHECK................................................. 1-1
- 1. 7 CONTAINMENT INTEGRITY......................................... 1-2
- 1. 8 CONTROLLED LEAKAGE............................................ 1-2
- 1. 9 CORE ALTERATION............................................... 1-2 1.10 DOSE EQIVALENT I-31.......................................... 1-2 1.11 E-AVERAGE DISINTEGRATION ENERGY.............................. 1-2 1.12 ENGINEERED SAFETY FEATURES RESPONSE TIME..................... 1-3 1
l.g *13 FREQUENCY NOTATION 1-3 Di&ki WibiJMri%6fAr:<M .WhWM ' * ' ' ' ' ' *
- 1.1/5 IDENTIFIED LEAKAGE........................................... 1-3 enme 1-3 p.g 1.1% MASTER RELAY TEST. . . . . ec
. . . . . .bu. n . . .ats. a . %. . a. n. . . .a. . :n. . .(cin. . . .). . . . .
1.158 OPERABLE-OPERABILITY....................................... 1-3 1.1/9OPERATIONALMODE-M0DE...................................... 1-3
- 1 4 2. PHYSICS TESTS................................................ 1-4
,, n 1.Ma PRESSURE BOUNDARY LEAKAGEg.R!MA. .@7.d.%.D.M . . . . . . . . . . . 1-4 t0 1. 2%f QUADRANT POWER TILT RATIO}.T"'. M 4 .t"8AW. . . . . . . . . . . . . . . . . . . . 1-4 i.24 1. 2/5 RATED THERMAL POWER. T.r;A. se eros. . . . . . . . .rr. .F4. . . . r4WrP. . . . . . . . . . . . . . 1-4
- 1. 2jf7- REACTOR TRIP SYSTEM RESPONSE TIME. . . . . . . : . . . . . . . . . . . . . . . . . . . . 1-4 1.2/6REPORTABLEOCCURRENCE........................................ 1-4
,a . . . . . . . , , , , , , . . . . . . _ _ _ _ _ _
.. w .w m- m wniii.................................... -l- _r 1.25i SHUTDOWN MARGIN.............................................. 1-5
,, p 1.263 SLAVE RELAY TEST....fh.*.'f'.'d7/M........................... 1-5 t '52 1. s STAGGERED TEST BA5 5D. 8'.".".".
. . . .N. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-5
- 1.25kiTHERMAL P0WER................................................ 1-5 1.29# TRIP ACTUATING DEVICE OPERATIONAL TEST....................... 1-6
,, 1.)65 UNIDENTIFIED LEAKAGE. . . .WWI5.W!*d Arw,q, yeo,trasff, g!TM. . . . 1-6 l
! i 1 38 TABLE 1.1 O P ERATIONAL MOD ES . . .V.4M. . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-7 l , iABLE 1.2 FREQUENCY N0TATION...................................... 1-8 i W-STS I SEP 151981 L
l INDEX SAFETY LIMITS AND LIMITING SAFETY SYSTEM SETTINGS 1 SECTION PAGE ! I 2.1 SAFETY LIMITS 1 2.1.1 REACTOR C0RE................................................ 2-1 2.1.2 REACTOR COOLANT SYSTEM PRESSURE............................. 2-1 2.2 LIMITING SAFETY SYSTEM SETTINGS 2.2.1 REACTOR TRIP SYSTEM INSTRUMENTATION SETP0INTS............... 2-4 l 1.2. 2. (A%iN664th SAf4*TY FliATMtf AcTEA4Tlad CYSftM .TASTAUM64TATJos ! SGT1% fats . . . . . . . . , , , , , . , Z.2.3 'AEAcTae Tgsr/egenegen TAArrV FEA7uds Acn4f77a4 SVSfEM TATiLL.ocy $LTPOWYS . . . . . . . . . BASES i SECTION PAGE 2.1 SAFETY LIMITS 2.1.1 REACTOR C0RE................................................ B 2-1 f 2.1.2 REACTOR COOLANT SYSTEM PRESSURE.......................,...... B 2-2 z . i.3 xorreuwar4.rios serp.,e rs . . . . . . . .
- 2. 2 LIMITING SAFETY SYSTEM SETTINGS 2.2.1 REACTOR TRIP SYSTEM INSTRUMENTATION SETP0INTS............... B 2-3 2.2. 2. EM619GL9.Gk SMGTt rentaa.G Acrun tion sysrcM .. . . . .
) .2.5 1.GALTotL T1LttlE.N48NEdLth SAGETY CGA~tMC AC'fuhT10Al sys re a I MTcG. locks . . . . . . .. . . . . .
- W-STS
- II APR 30 7979 l
L . - .- -- --
INDEX LIMITING CONDITIONS FOR OPERATION AND SURVEILLANCE REQUIREMENTS SECTION _PAGE 3/4.0 APPLICABILITY............................................... 3/4 0-1 3/4.1 REACTIVITY CONTROL SYSTEMS 3/4.1.1 BORATION CONTROL Shutdown Margin - T,yg > 200 F........................... 3/4 1-1 Shutdown Margin - T,yg < 200*F........................... 3/4 1-3 Moderator Temperature Coefficient........................ 3/4 1-4 Minimum Temperature for Criticality...................... 3/4 1-6 3/4.1.2 BORATION SYSTEMS Flow Path - Shutdown..................................... 3/4 1-7 l Flow Paths - Operating................................... 3/4 1-8 Charging Pump - Shutdown................................. 3/4 1-9 Charging Pumps - Operating.................. ............ 3/4 1-10 Borated Water Source - Shutdown.......................... 3/4 1-11 l' Borated Water Sources - Operating........................ 3/4 1-12 3/4.1.3 MOVABLE CONTROL ASSEMBLIES Group Height............................................. 3/4 1-14 Position Indication Systems - Operating...,....... ...... 3/4 1-17 Position Indication System - Shutdown.................... 3/4 1-18 l Rod Drop Time............................................ 3/4 1-19 Shutdown Rod Insertion Limit............................. 3/4 1-20 Control Rod Insertion Limits............................. 3/4 1-21 T... L...,t.', P~. :.::r'4-- '4 4+- -
? f " '
W-STS III iiOV 2 01980
INDEX LIMITING CONDITIONS FOR OPERATION AND SURVEILLANCE REQUIREMENTS SECTION PAGE 3/4.2 POWER DISTRIBUTION LIMITS 3/4.2.1 AXIAL FLUX DIFFERENCE.................................... 3/4 2-1 3/4.2.2 HEAT FLUX HOT CHANNEL FACT 0R............................. 3/4 2-4 i 3/4.2.3 RCS FLOW RATE AND NUCLEAR ENTHALPY RISE HOT CHANNEL FACT 0R................................................. 3/4 2-8 3/4.2.4 QUADRANT POWER TILT RATI0................................ 3/4 2-12 3/4.2.5 DNB PARAMETERS........................................... 3/4 2-15
>g 3/4.3 INSTRUMENTATION Ih 3/4.3.1 REACTOR TRIP SYSTEM INSTRUMENTATION...................... 3/4 3-1 m
k 3/4.3.2 EhGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION........................................ 3/4 3-16 3/4.3.3 MONITORING INSTRUMENTATION (d qg w-s r Radiation Monitoring..................................... 3/4 3-48 6$ Movable Incore Detectors................................. 3/4 3-54 h Seismic Instrumentation.................................. 3/4 3-55 d: x eg Meteorological Instrumentation........................... 3/4 3-58 hN Remote Shutdown Instrumentation.......................... 3/4 3-61 5 . Oc: d Accident Monitoring Instrumentation...................... 3/4 3-64 l r Chlorine Detection Systems............................... 3/4 3-67 Jire Detection Instrumentation........................... 3/4 3-68 II
- Loose-Part Detection Instrumentation..................... 3/4 3-70 t
3/4.3.4 TURBINE OVERSPEED PROTECTION............................. 3/4 3-71
-%A: he Gosem EHlw4 Ankrty %-IcanuAdibn
- Q:.adia. Q4 E-f$lued knkr% bdrum<dbo^
W-STS
- IV
.NOV 2 .m81
INDEX LIMITING CONDITIONS FOR OPERATION AND SURVEILLANCE REOUIREMENTS SECTION PAGE 3/4.4 REACTOR COOLANT SYSTEM 3/4.4.1 REACTOR COOLANT LOOPS AND COOLANT CIRCULATION S tartup and Power Ope rati on. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3/4 4-1 Hot Standby.............................................. 3/4 4-2 Hot Shutdown............................................. 3/4 4-3 Col d Shutdown - Loops Fi11 ed. . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3/4 4-5 Col d Shutdown - Loops Not Fi11 ed. . . . . . . . . . . . . . . . . . . . . . . . . 3/4 4-6
,__. . ,n .,
....... uwer. . _ , , .
_ . , , -w ___._.. move o ..ur. 3/4.4.2 SAFETY VALVES Shutdown............................................... 3/4 4-9 Operating............................................. 3/4 4-10 3/4.4.3 PRESSURIZER.............................................. 3/4 4-11 3/4.4.4 RELIEF VALVES............................................ 3/4 4-12 2/4.4.5 STEAM GENERATORS......................................... 3/4 4-13 3/4.4.6 REACTOR COOLANT SYSTEM LEAKAGE Leakage Detection Systems..........................'...... 3/4 4-20 Operational Leakage...................................... 3/4 4-21 3/4.4.7 CHEMISTRY................................................ 3/4 4-24 3/4.4.8 SPECIFIC ACTIVITY........................................ 3/4 4-27 3/4.4.9 PRESSURE / TEMPERATURE LIMITS Reactor Coolant System................................... 3/4 4-31 Pressurizer.............................................. 3/4 4-35 Ove rpres sure Protection Systems. . . . . . . . . . . . . . . . . . . . . . . . . . 3/4 4-36 3/4.4.10 STRUCTURAL INTEGRITY..................................... 3/4 4-38 W-STS V
'NOV 2 1981
INDEX LIMITING CONDITIONS FOR OPERATION AND SURVEILLANCE REOUIREMENTS SECTION PAGE 3/4.5 EMERGENCY CORE COOLING SYSTEMS 3/4.5.1 ACCUMULATORS __ 2,'" : I f 3/4.5.2 ECCS SUBSYSTEMS - T,yg > 350*F........................... 3/4 5-3 3/4.5.3 ECCS SUBSYSTEMS - T,yg < 350*F...................'........ 3/4 5-7 3/4.5.4 BORON INJECTION SYSTEM Boron Injection Tank..................................... 3/4 5-9 Heat Tracing............................................. 3/4 5-10 3/4.5.5 REFUELING WATER STORAGE TANK............................. 3/4 5-11
- --- liffse l%d hfec.Non Aeamda. hrs .. . .. . .
_ 6(1 Lag L gec. b n A ce W k rs. . . . W-STS VI 0 SO
INDEX LIMITING CONDITIONS FOR OPERATION AND SURVEILLANCE REOUIREMENTS SECTION P E W - ATMOSPHERIC TYPE CONTAINMENT 3/4.6 CONT MENT SYSTEMS 3/4.6.1 PRIMAR ONTAINMENT-Containmen ntegrity............................. ...... 3/4 6-1A Containment Le age............................ ........ 3/4 6-2A Containment Air L ks........................ ........... 3/4 6-5A Containment Isolatio Valve and Channel Wel Pressurization Syste .................. .............. 3/4 6-7A Internal Pressure........ ............ ................ 3/4 6-8A Air Temperature.............. ....... .................. 3/4 6-9A Containment Structural Integrit .. .................... 3/4 6-10A Containment Ventilation System... ...................... 3/4 6-17A 3/4.6.2 DEPRESSURIZATION AND COOLING SY EMS Containment Spray System..... ........... ............... 3/4 6-18A Spray Additive System..... ............... ............ 3/4 6-21A Containment Cooling Syst .................... .......... 3/4 6-22A 3/4.6.3 IODINE CLEANUP SYSTE ........................... ...... 3/4 6-24A 3/4.6.4 CONTAINMENT ISO LA'.ON VALVES. . . . . . . . . . . . . . . . . . . . . . . . . . . . 3/4 6-26A 3/4.6.5 COMBUSTIBLE G CONTROL Hydrogen Mo tors........................................ 3/4 6-29A Electric drogen Recombiners............................ 4 6-30A Hydrog Purge System.................................... 3/ 6-31A Hydr en Mixing System................................... 3/4 33A 3/4.6.6 P ETRATION ROOM EXHAUST AIR CLEANUP SYSTEM.............. 3/4 6-3 3/4.6.7 ACUUM RELIEF VALVES..................................... 3/4 6-36A s W-STS VII-A AUG 6 1CBI
INDEX LIMITING CONDITIONS FOR OPERATION AND SURVEILLANCE REQUIREMENTS SECTION PAGE W - ICE CONDENSER TYPE CONTAINMENT 3/4.6 CONTAINMENT SYSTEMS 3/4.6.1 *M99MPr CONTAINMENT , Containment Integrity.................................... 3/4 6-1B Containment Leakage...................................... 3/4 6-28 Containment Air Locks.................................... 3/4 6-6B
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Internal Pressure........................................ 3/4 6-98 Air Temperature.......................................... 3/4 6-10B Containment Vessel Structural Integrity.................. 3/4 6-11B Gbacf= :: . ;' d Buil di ng Structural Integri ty. . . . . . . . . . . . . . . . . . . . . 3/4 6-128 A 4 5 %4lilaNe^ . C'... 2 System....................................... 3/4 6-138 Containment Ventilation System........................... 3/4 6-158 3/4.6.2 DEPRESSURIZATION AND COOLING SYSTEMS Containment Spray System................................. 3/4 6-168
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3/4. 6. / 5 CONTAINMENT ISO LATION VALVES. . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3/4 6-25B 3/4.6.74 COMBUSTIBLE GAS CONTROL l Hydrogen Monitors........................................ 3/4 6-288 l Electric Hydrogen Recombiners............................ 3/4 6-298 \ .. , ___ n,....- - .__ ,,.n ,ne m,m.e3 o . . . , _ _.__ _, ., ___ - x . ___ o_ ; _-./ __ - ,,n
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7 o om-- Hdi gen f.edel 'bwfrifeli nifim g Sys/em . . . . . . . . . W-STS
- VII-B AUG 6 1981 l
INDEX i I LIMITING CONDITIONS FOR OPERATION AND SURVEILLANCE REOUIREMENTS . 1 SECTION PAGE
- ,, ,m,,,,..... --
s/,.... ......u .*wn avun CAMMU36 MAK LLCMaur a n a a m s,= - m w aww-3/4.6.lJT ICE CONDENSER Ice Bed.................................................. 3/4 6-35B Ice Bed Temperature Monitoring System.................... 3/4 6-37B Ice Condenser Doors...................................... 3/4 6-38B Inlet Door Position Monitoring System.................... 3/4 6-40B Divider Barrier Personnel Access Doors and Equipment Hatches...... 3/4 6-41B en s ~ar sys+ee gyu ir;_1.y i .. . ;,.'_;; .................... Co ntai nme n t Ai r ;;en asa M k; . . . . . k. . . . . . . . . . . . . . . . . . . . . . ... 3/4 6-428 Floor Dr4 ins............................................. 3/4 6-43B Refueling Canal Drains................................... 3/4 6-44B Divider Barrier Seal..................................... 3/4 6-45B _,..w-
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nemice vnu.m - l l l 1 1 l l l l ~. l g-STS VIII-B APR 3 01979
i INDEX l LIMITING CONDITIONS FOR OPERATION AND SURVEILLANCE REQUIREMENTS SECTION PAGE s r. e o errnun .ov re. - -. - . . _
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'd-STS VIII-D APR 3 01979 i
INDEX LIMITING CONDITIONS FOR OPERATION AND SURVEILLANCE REQUIREMENTS SECTION PAGE W - SUBATMOSPHERIC TYPE CONTAINMENT 3/4.6 TAINMENT SYSTEMS 3/4.6.1 PR ARY CONTAINMENT Conta me n t I n t e g r i ty . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3/4 6-1C Containm t Leakage............................. ........ 3/4 6-2C Containment ir Locks........................ ........... 3/4 6-5C Containment Is ation Valve and Channel Wel Pressurization stems................. ............... 3/4 6-7C Internal Pressure... .................. ................. 3/4 6-8C Ai r Temp e ratu re . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3/4 6-10C Containment Structural I egrity.. ...................... 3/4 6-12C Containment Ventilation Sys m.. ........................ 3/4 6-19C 3/4.6.2 DEPRESSURIZATION AND COOLING TEMS Containment Quench Spray 5 tem.. ...................... 3/4 6-20C Containment Recirculatio Spray Sys m................... 3/4 6 21C Spray Additive System. ................ ................. 3/4 6-22C 3/4.6.3 CONTAINMENT ISOLATI VALVES.............. .............. 3/4 6-23C u 3/4.6.4 COMBUSTIBLE GAS NTROL i Hydrogen Moni rs.............................. ........ 3/4 6-26C Electric Hy ogen Recombiners..................... ...... 3/4 6-27C Hydrogen rge Cleanup System........................ ... 3/4 6-28C Hydroge Mixing System................................. 3/4 6-30C 3/4.6.5 SUBA SPHERIC PRESSURE CONTROL SYSTEM St am Jet Air Ejector.................................... 4 6-31C chanical Vacuum Pumps.................................. 3/4 -32C 3/4.6.6 VACUUM RELIEF VALVES..................................... 3/4 6- C W-STS VII-C 6 1981 AUG
INDEX LIMITING CONDITIONS FOR OPERATION AND SURVEILLANCE REQUIREMENTS SECTION PAGE, W - DUAL TYPE CONTAINMENT 3/4.' CONTAINMENT SYSTEMS 3/4.6.1 RIMARY CONTAINMENT Co . inment Integrity................................ ... 3/4 6-1D Contai ent Leakage............................... ..... 3/4 6-2D Containmen Air Locks................. ......... ........ 3/4 6-60 Containment I ation Valve and Channel Weld Pressurization stems................... ............ 3/4 6-8D Internal Pressure... .................... ............... 3/4 6-90 Air Temperature........ ............. ................. 3/4 6-100 Containment Vessel Structu 1 integr' y.................. 3/4 6-11D Containment Ventilation Syste .. ....................... 3/4 6-120 3/4.6.2 DEPRESSURIZATION AND COOLING S' S Containment Spray System... ........ ................... 3/4 6-130 Spray Additive System.... .............. ................ 3/4 6-160 Containment Cooling Sy em................ ............. 3/4 6-170 3/4.6.3 IODINE CLEANUP SYST' ......................... .......... 3/4 6-190 3/4.6.4 CONTAINMENT ISO ION VALVES..................... ..... . 3/4 6-210 3/4.6.5 COMBUSTIBLE S CONTROL Hydrogen M itors..................................... . 3/4 6-240 Electric ydrogen Recombiners............... ............ 3/4 6-25D Hydro n Purge Cleanup System............................ 3/4 6-260 Hyd gen Mixing System................................... 3 6-280 3/4.6.6 NETRATION ROOM EXHAUST AIR CLEANUP SYSTEM. . . . . . . . . . . . . . . 3/4 90 3/4.6. VACUUM RELIEF VALVES...................................... 3/4 6-31D s j W-STS VII-0 AUG 6 1981 1 i
i INDEX i LIMITING CONDITIONS FOR OPERATION AND SURVEILLANCE RE0VIREMENTS SECTION PAGE 3/4.7 PLANT SYSTEMS 3/4.7.1 TURBINE CYCLE Safety Valves............................................ 3/4 7-1 Auxiliary Feedwater System............................... 3/4 7-4 e __ _ _ ~ _ - wu--.---w, 4 Q 3 W-
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wp w Activity................................................. 3/4 7-7 Main Steam Line Isolation Va1ves......................... 3/4 7-9 3/4.7.2 STEAM GENERATOR PRESSURE / TEMPERATURE LIMITATION.......... 3/4 7-10 s 3/4.7.3 COMPONENT COOLING WATER SYSTEM........................... 3/4 7-11 h McLEAR. g 3/4.7.4 3 SERVICE WATER SYSTEM..................................... 3/4 7-12 b 3/4.7.5 4+i+MfHtE*THi4M.4r4,5mef,4myg,sF.4ff Md.VA ?*19. . . . . . . . . 3/4 7-13
,9 g -3/4.7.o TL,GD ra6T; TIJ;- ^'4 7 1?
4t44 VuriL4rsons 6 3/4. 7. h CONTROL 6 SYSTEM................ 3/4 7-15 3
$ FILTfFl0Al y 3/4. 7.h (ECCS PUMP ROOM EXHAUST A AIR %5dMP SYSTEM'). 3/4 7-18 .........
i S 1 3/4.7.16 SNUBBERS................................................. 3/4 7-20 4 3/4.7.169 SEALED SOURCE CONTAMINATION.............................. 3/4 7-27 f j 3/4.7. & FIRE SUPPRESSION SYSTEMS Fire Suppression Water System............................ 3/4 7-29 T Sp ray and/o r Sp ri n k1 c r Sys tems . . . . . . . . . . . . . . . . . . . . . . . . . . . 3/4 7-32 CO 2 Systems.............................................. 3/4 7-34
, , , , 1 ___ ,,, , ,,
I du 3 %f 4 5 efg up er w urv __ __ wr ww-Fire Hose Stations....................................... 3/4 7-37 aws W a au w 4 IJ W 6 G 5 6 W .T ut 3M 4 6J W e M 4 8 b 4 8v vb i--- -_ .r i ef er eArtietP(w rehrt.As 3/4.7.)fn FIRE30AT C A';;",0L: 3.................................... 3/4 7-41 3/4.7.1MzAREA TEMPERATURE M0NITORING.............................. 3/4 7-43 3]4.3. ss 4RouDwMEt LEVEL. W-STS
- IX
'NOV 2 1981
1 l l l INDEX l l l LIMITING CONDITIONS FOR OPERATION AND SURVEILLANCE REQUIREMENTS i l SECTION PAGE 3/4.8 ELECTRICAL POWER SYSTEMS 3/4.8.1 A.C. SOURCES 0perating................................................ 3/4 8-1 Shutdown................................................. 3/4 8-8 I 3/4.8.2 0.C. SOURCES 0perating................................................ 3/4 8-9 Shutdown................................................. 3/4 8-12 3/4.8.3 ONSITE POWER DISTRIBUTION SYSTEMS 0perating................................................ 3/4 8-13 Shutdown................................................. 3/4 8-15 3/4.8.4 ELECTRICAL EQUIPMENT PROTECTION DEVICES Containment Penetration Conductor Overcurrent Protective Devices..................................... 3/4 8-16 t .w kw 6 wpw6 ubGu , ,_ _ .__., _, rw6 esJ . 4 4G 3 444u e w d E4 awww i - - - - , wTau wjpudd wwW 4www m re n am ws - -- 1 \ l i l - 1 t E-STS X
'NOV 2 1981 l
i
INDEX LIMITING CONDITIONS FOR OPERATION AND SURVEILLANCE REQUIREMENTS SECTION PAGE 3/4.9 REFUELING OPERATIONS 3/4.9.1 BORON CONCENTRATION...................................... 3/4 9-1 3/4.9.2 INSTRUMENTATION.......................................... 3/4 9-2 3/4.9.3 DECAY TIME............................................... 3/4 9-3 3/4.9.4 CONTAINMENT BUILDING PENETRATIONS........................ 3/4 9-4 3/4.9.5 COMMUNICATIONS........................................... 3/4 9-5 3/4.9.6 MANIPULATOR CRANE........................................ 3/4 9-6 3/4.9.7 CRANE TRAVEL - SPENT FUEL STORAGE P0OL BUILDING.......... 3/4 9-7 3/4.9.8 RESIDUAL HEAT REMOVAL AND COOLANT CIRCULATION High Water Leve1......................................... 3/4 9-8 Low Water Level.......................................... 3/4 9-9 _ . . , , , . . , , , , . . . . . . _ . . . _ _ ._ . , . . . . - . ...,..,,,,.,,,._m m .... .....mnow. renum nnu mone . tom..., .... m .......... ,u-,.,,.,
?
3/4.9.MT WATER LEVEL - REACTOR VESSEL............................. 3/4 9-11
- 2. ". . ^ . O ' .T:" '. :' "". - STO RAG E POO L . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3/4 9-12
'A WA1 3/4.9.yf STORAGE POOL AI'; %_prvfLe mann U P 3 YSfet. . . . . . . . . . . . . . . . . . . . . . . . . . 3/4 9-13 3}4,*l.st Tact. HAoun4 Vc>mLf*Tled [xHfMSY &$7&h1 , , . ,
3/4.10 SPECIAL TEST EXCEPTIONS 3/4.10.1 SHUTDOWN MARGIN.......................................... 3/4 10-1 3/4.10.2 GROUP HEIGHT, INSERTION AND POWER DISTRIBUTION LIMITS.... 3/4 10-2 3/4.10.3 PHYSICS TESTS............................................ 3/4 10-3 3/4.10.4 REACTOR COOLANT L00PS.................................... 3/4 10-4 3/4.10.5 POSITION INDICATION SYSTEM - SHUTD0WN.................... 3/4 10-5 user .r/4.u / 3/4'. a W-STS XI JUL 2 71981 1
INDEX ' BASES SECTION PAGE 3/4.0 APPLICABILITY............................................... B 3/4 0-1 3/4.1 REACTIVITY CONTROL SYSTEMS 3/4.1.1 BORATION CONTR0L.......................................... B 3/4 1-1 3/4.1.2 BORATION SYSTEMS.......................................... B 3/4 1-2 3/4.1.3 MOVABLE CONTROL ASSEMBLIES................................ B 3/4 1-3 3/4.2 POWER DISTRIBUTION LIMITS 3/4.2.1 AXIAL FLUX DIFFERENCE..................................... B 3/4 2-1 3/4.2.2 and 3/4.2.3 HEAT FLUX HOT CHANNEL FACTOR and RCS FLOW 8 RATE AND NUCLEAR ENTHALPY RISE HOT CHANNEL FACTOR. . . . . . . B 3/4 2-2 3/4.2.4 QUADRANT POWER TILT RATI0................................. 3 3/4 2-5 3/4.2.5 DNB PARAMETERS............................................ B 3/4 2-5 3/4.3 INSTRUMENTATION 3/4.3.1 and 3/4.3.2 REACTOR TRIP SYSTEM and ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION................ B 3/4 3-1 3/4.3.3 MONITORING INSTRUMENTATION................................ B 3/4 3-2 3/4.3.4 TURBINE OVERSPEED PROTECTION.............................. B 3/4 3-4 W-STS XII .mgy g g 1930 i
m)SERTioA Fo* W xx
] INDEX LIMITING CONDITIONS FOR OPERATION AND SURVEILLANCE REOUIREMENTS SECTION PAGE 3/J.11 RADI0 ACTIVE EFFLUENTS 3/4.11.1 LIQUID EFFLUENTS Concentration. . . . . . . ... . . . . . . . . . . . . . . . . . . 3/4 11-1 Dose. .... . . . . . . . . . . . . . . ... . . . . . . . . . . . . 3/4 11-5 Liquid Waste Treatment... . . . . . . . . . . . . . . . . . 3/4 11-6 Liquid Holdup Tanks.. . .
. . . . . . . . . . . . . . 3/4 11-7 Chemical Treatment Ponds.... .... . . . . . . . . . . . . . . 3/4 11-8 3/4.11.2 GASECUS EFFLUENTS Dose Rate. . . . . .. . . . . . . . . . . 3/4 11-9 Dese-Noble Gases. . . . . . . . . . . . . . . . . . . . 3/4 11-13 Dose-Radiciodines, Radioactive Materials In Particulate Form, and Radionuclides Other than Noble Gases. .... . . . . . . . . . . . . . . . . . . . . . . 3/4 11-14 Gaseous Racwaste Treatment. . .... . . . . . . . . . . . . . . . . . 3/4 11-15 Explosive Gas Mixture... . ... .. . ... . . . . . . . . . 3/4 11-16 Gas Storage Tanks... . .. . .. .. ... ...... ... . 3/4 11-17 3/4.11.3 SOLID RADI0 ACTIVE WASTE...... .....'............... . . 3/4 11-18 3/4.11.4 TOTAL 00SE..... . . . . . . . . ... .. ........ .... . .... 3/4 11-20 3/4.12 RADIOLOGICAL ENVIRONMENTAL MONITORING ~
3/4.12.1 MONITORING PROGRAM.. . . . .......... .. . . . . . . . . . . 3/4 12-1 3/4.12.2 LAND USE CENSUS..... ......... .......... . . . . . . 3/4 12-10 1 3/4.12.3 INTERLABORATORY COMPARISON PROGRAM.... . . . . . . . . . . . . . . 3/4 12-11 CATAWBA - UNIT 1 XIII e' w + vpy 9,w-- --nwgw-r -,-a-w'-------=y+ yyurwmeemyyi+--m ew w- *-w's*~-w e s*g-F -,-> - + - - -M m---- - -- ------y-e--w-em-yyy- ---wv---P -w - -- --- 1
INDEX BASES SECTION PAGE 3/4.4 REACTOR COOLANT SYSTEM 3/4.4.1 REACTOR COOLANT LOOPS AND COOLANT CIRCULATION. . . . . . . . . . . . . B 3/4 4-1 3/4.4.2 SAFETY VALVES............................................. B 3/4 4-2 3/4.4.3 PRESSURIZER............................................... B 3/4 4-2 3/4.4.4 RELIEF VALVES............................................. B 3/4 4-3 3/4.4.5 STEAM GENERATORS.......................................... B 3/4 4-3 3/4.4.6 REACTOR COO LANT SYSTEM LEAKAGE. . . . . . . . . . . . . . . . . . . . . . . . . . . B 3/4 4-4 3/4.4.7 CHEMISTRY................................................. B 3/4 4-5 3/4.4.8 SPECIFIC ACTIVITY......................................... B 3/4 4-5 3/4.4.9 PRESSURE / TEMPERATURE LIMITS.............................. B 3/4 4-6 3/4.4.10 STRUCTURAL INTEGRITY..................................... B 3/4 4-15 3/4.5 EMERGENCY CORE COOLING SYSTEMS 3/4.5.1 AC C UMU LATO R S . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . B 3/4 5-1 3/4.5.2 and 3/4.5.3 ECCS SUBSYSTEMS............................... 8 3/4 5-1 3/4.5.4 BORON INJECTION SYSTEM.................................... "B 3/4 5-2 3/4.5.5 REFUELING WATER STORAGE TANK.............................. B 3/4 5-2 W-STS XIII 'NOV 2 01980
INDEX BASES SECTION PAGE W - ATMOSPHERIC TYPE CONTAINMENT 3/4.6 C NMENT SYSTEMS 3/4.6.1 PRIMARY AINMENT............................ ......... B 3/4 6-1A 3/4.6.2 DEPRESSURIZATION COOLING SYSTEMS... ................. B 3/4 6-3A 3/4.6.3 I0 DINE CLEANUP SYSTEM...... ... ......................... B 3/4 6-4A 3/4.6.4 CONTAINMENT ISOLATION V 5...... ..................... B 3/4 6-5A 3/4.6.5 COMBUSTIBLE GAS TR0L.................... ............. B 3/4 6-5A 3/4.6.6 PENETRA ROOM EXHAUS T AIR FILTRATION SYSTEM. . . . . ..... B 3/4 6-6A 3/4.6.7 UUM RELIEF VALVES. .................................... 3/4 6-6A W-STS XIV-A APR 3 01979
INDEX BASES SECTION PAGE y - ICE CONDENSER TYPE CONTAINMENT 3/4.6 CONTAINMENT SYSTEMS 3/4.6.1 PRIMARY CONTAINMENT............'........................... B 3/4 6-1B 1 l 3/4.6.2 DEPRESSURIZATION AND COOLING SYSTEMS...................... B 3/4 6-38 l , , . . ,
., . .. ,- . ,. .. .mmanur
.. ,m -
! _ m ., . .. 3/4. 6./3 CONTAINMENT ISO LATION VALVES. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . B 3/4 6-5B 3/4.6.fYCOMBUSTIBLEGASCONTR0L................................... B 3/4 6-5B
.mmm.nn. tun avun canavai sin riu.an..... ..oicn-- , ,,, , ,,
3 /4. 6 . /f I C E CON 0 EN S E R . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .B. .3/4
. . .6-5B .<>..- .muovn acticr .nm. .. ,,,,e_,m o
l l l l y-STS XIV-B APR 3 o 7979
,INDEX 1
1 BASES l SECTION PAGE 1 W - SUBATMOSPHERIC TYPE CONTAINMENT 3/4.6 INMENT SYSTEMS 3/4.6.1 PRIMARY NMENT.......................... .......... B 3/4 6-1C 3/4.6.2 DEPRESSURIZATION A LING SYST ...................... B 3/4 6-3C 3/4.6.3 CONTAINMENT ISOLATION S.... ....................... L 3/4 6-3C 3/4.6.4 COMBUSTIBLE NTR0L.................... ............ B 3/4 6-4C 3/4.6.5 SU PHERIC PRESSURE CONTROL SYSTEM............... .. B 3/4 6-4C 3/ . VACUUM RELIEF VALVES...................................... 4 6-4C s \ W-STS XIV-C APR 3 0 579
INDEX BASES SECTION PAGE W - DUAL TYPE CONTAINMENT b ONTAINMENT SYSTEMS 3/4.6.1 PRIMA AINMENT...................................... 3/4 6-10 3/4.6.2 DEPRESSURIZATION 00 LING SYSTEMS.......... ......... B 3/4 6-30 3/4.6.3 IODINE REMOVAL SYSTEMS....... .....- ................... B 3/4 6-4L 3/4.6.4 CONTAINMENT ISOLATION VALVES ....... ................... B 3/4 6-40 3/4.6.5 COMBUSTIBLE GAS CON ...................... ........... B 3/4 6-50 3/4.6.6 PENETRATION EXHAUST AIR FILTRATION SYSTEM...... .... B 3/4 6-50 3/4.6.7 V RELIEF VALVES...................................... 3/4 6-50 3/ .8 SECONDARY CONTAINMENT..................................... B3 -5D I 79 W-STS XIV-D
INDEX BASES SECTION PAGE 3/4.7 PLANT SYSTEMS 3/4.7.1 TURBINE CYCLE............................................. B 3/4 7-1 3/4.7.2 STEAM GENERATOR PRESSURE / TEMPERATURE LIMITATION........... B 3/4 7-3 h 3/4.7.3 COMPONENT COOLING WATER SYSTEM............................ B 3/4 7-3 & guets4A h 3/4.7.4 SERVICE A WATER SYSTEM...................................... B 3/4 7-3 3/4.7.S tM4MAiPMfEA>44Mt.$WP8Y .$.W.4 Mav,sg ,e!M ,y,4.t . . . . . . . . . B 3/4 7-3 =
^
g . .22S [. Ibb5wr K ARGA 4cTusved 5 3/4. 7. h CONTRO Ljm SYSTEM. . . . . . . . . . . . . . . . . B 3/4 7-4 1 3/4.7.4?DCCSPUMPROOMEXHAUSTAIRFILTRATIONSYSTEM)............ B 3/4 7-4 j 3 /4. 7. !t e SNUB B E RS . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . B 3/4 7-s I g 3/4. 7. M9 5EALED SOURCE CONTAMINATION. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8 3/4 7-6 3/4.7.,d# FIRE SUPPRESSION SYSTEMS.................................. B 3/4 7-6 g 3/4.7. M FIRE p@.T::l6f. ;~ PgAJfff47WI
~ ; :;..................................... B 3/4 7-7 '
j 3/4.7.MAREATEMPERATUREMONITORING............................... B 3/4 7-7 314.~f.15 6goupbWA1rff. Lgv6!. . . . . . . . . . . . 3/4.8 ELECTRICAL POWER SYSTEMS 3/4.8.1, 3/4.8.2 and 3/4.8.3 A.C. SOURCES, D.C. SOURCES AND ONSITE POWER DISTRIBUTION SYSTEMS....................... B 3/4 8-1 3/4.8.4 ELECTRICAL EQUIPMENT PROTECTION DEVICES................... B 3/4 8-3 l l 4 1 W-STS
- XV
'NOV 2 1931
INDEX BASES SECTION PAGE 3/4.9 REFUELING OPERATIONS -- 3/4.9.1 BORON CONCENTRATION....................................... B 3/4 9-1 3/4.9.2 INSTRUMENTATION........................................... B 3/4 9-1 3/4.9.3 DECAY TIME................................................ B 3/4 9-1 3/4.9.4 CONTAINMENT BUILDING PENETRATIONS. . . . . . . . . . . . . . . . . . . . . . . . . B 3/4 9-1 3/4.9.5 COMMUNICATIONS............................................ B 3/4 9-1 3/4.9.6 MAN I PU LATO R C RAN E . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . B 3/4 9-2 3/4.9.7 CRANE TRAVEL - SPENT FUEL STORAGE BUILDING. . . . . . . . . . . . . . . . B 3/4 9-2 3/4.9.8 RESIDUAL HEAT REMOVAL AND COOLANT CIRCULATION. . . . . . . . . . . . . B 3/4 9-2 L ,.:. - 5 0,
- TA:nn;J ru=; n;6 1.AJ T ::AAT:::: C'!:T ._ -
- 2 3/4.9.k and 3/4.9.k WATER LEVEL - REACTOR VESSEL and STO RAG E P00 L . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . B 3/4 9-3 l u suu. awuws E.xurar -
3/4. 9. )f WelMee960t g VENTILATION SYSTEM. j .......................... B 3/4 9-3 3/4.10 SPECIAL TEST EXCEPTIONS 3/4.10.1 SHUTDOWN MARGIN........................................... B 3/4 10-1 3/4.10.2 GROUP HEIGHT, INSERTION AND POWER DISTRIBUTION LIMITS..... B 3/4 10-1 3/4.10.3 PHYSICS TESTS............................................. B 3/4 10-1 3/4.10. 4 R EACTO R COO LANT L00 P S . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . B 3/4 10-1 3/4.10.5 POSITION INDICATION SYSTEM - SHUTD0WN..................... B 3/4 10-1 W-STS XVI SEP 151981
DUKE POWER COMPANY Fcam 001S4 (6 81
. Dev./ Station Unit File No.
Subject By Date
- l Sheet No. _ of Problem No. Checked By Date !
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li H I ! . 3/4.11 RADIOACTIVE EFFLUENTS : 3/4.11.1 LIQUID EFFLUENTS. . ........ . ..... .... . . . B 3/4 11-1 .,
'i B 3/4 11-3 "; !!
3/4.11.2 GASEOUS EFFLUENTS... ........... . ... . .. 3/4.11.3 SOLID RADI0 ACTIVE WASTE. .... ... .... .. . . B 3/4 11-6 i-I! B 3/4 11-6 1/4.11.4 TOTAL DOSE... . . .. ..... . .. . . . ......
- l i
-i l , 3/4.12 RADIOLOGICAL ENVIRONMENTAL MONITORING t;
i 3/4.12.1 MONITORING PROGRAM.... .. . . .. . .. . .. B 3/4 12-1
- I
, 3/4.12.2 LAND USE CENSUS............. ...... .. .. .. .. ... . B 3/4 12-1 l .I 3/4.12.3 INTERLABORATORY COMPARISON... ... ... ... ... ... .. B 3/4 12-2 ji i
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INDEX DESIGN FEATURES SECTION PAGE 5.1 SITE 5.1.1 EXCLUSION AREA.............................................. 5-1 5.1. 2 LOW POPULATION 20NE......................................... 5-1 S. I.5 LtGass MswmHfLUCATS.. unessimren Anas ree enuoxnvr SArsew 4ab
- 5. 2 CONTAINMENT . .
5.2.1 CONFIGURATION............................................... 5-1 5.2.2 DESIGN PRESSURE AND TEMPERATURE............................. 5-1 5.3 REACTOR CORE 5.3.1 FUEL ASSEMBLIES............................................. 5-4 5.3.2 CONTROL ROD ASSEMBLIES...................................... 5-4 5.4 REACTOR COOLANT SYSTEM 5.4.1 DESIGN PRESSURE AND TEMPERATURE............................. 5-4 5.4.2 V0LUME...................................................... 5-4
- 5. 5 METEORO LOGICAL TOWER LOCATION. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-4 5.6 FUEL STORAGE 5.6.1 CRITICALITY................................................. 5-5 5.6.2 DRAINAGE.................................................... 5-5 5.6.3 CAPACITY.................................................... 5-5
- 5. 7 COMPONENT CYCLIC OR TRANSIENT LIMIT........................... 5-5 s
W-STS XVII NOV 151979
e-1 1 l 1 I INDEX j ACMINI5TRATIVE CONTROLS l SECTION PAGE 6.1 RESPONSIBILITY................... ............................ 6-1 6.2 ORGANIZATION 0ffsite....................................................... 6-1 Unit Staff................... ................................ 6-1 Catawba Safety Review Group............... ................... 6-5 Shift Tech 7ical Advisor...... ............ ................. 6-5
- 6. 3 UNIT STAFF OUALIFICATIONS...... .............................. 6-5 6.4 TRAINING............... ... ..................... .. ........ 6-5 6.5 REVIEW AND AUDIT 6.5.1 TECHNICAL REVIEW AND CONTROL Activities.................................................. 6-6 6.5.2 NUCLEAR SAFETY REVIEW BOARD Function.................................................... 6-7 Organization....... ......... ............................. 6-8 Subjects Requiring Review................................... 6-9 Audits................................. ... ................ 6-9 Authority.. ....................... . ... ... ....... ..... 6-10 Records...................... .... ....................... 6-11 6.6 REPORTABLE OCCURRENCE ACTION......... ......... .. ........... 6-11 6.7 SAFETY LIMIT VIOLATION...... ............ ....... ........... 6-11 6.8 PROCEDURES AND PROGRAMS................. ..... ....... ..... 6-12 CATAWBA - UNIT 1 XXI
INDEX ACMINISTRATIVE CONTROLS SECTION PAGE 6.9 REPORTING REQUIREMENTS 6.9.1 ROUTINE REPORTS AND REPORTABLE OCCURRENCES.................. 6-15 6.9.2 SPECIAL REPORTS... ......................................... 6-23 6.10 RECORD RETENTION............................................. 6-23 6.11 RAOIATION PROTECTION PROGRAM........... ..................... 6-24 6.12 PROCESS CONTROL PR0 GRAM.................................... . 6-24 6.13 0FFSITE DOSE CALCULATICN MANUAL. . . . . . . . . . . . . ...... ..... 6-25 6.14 MAJOR CHANGES TO RADI1 ACTIVE WASTE TREATMENT SYSTEMS......... 6-26 t l l l 1 l l CATAWBA - UNIT 1 XXII l
SECTION 1.0 DEFINITIONS i i l l t i
1.0 DEFINITIONS The defined terms of this section appear in capitalized type and are applicable throughout these Technical Specifications. ACTION 1.1 ACTION shall be that part of a Specification which prescribes remedial measures required under designated conditions. ACTUATION LOGIC TEST 1.2 An ACTUATION LOGIC TEST shall be the application of various simulated input combinations in conjunction with each possible interlock logic state and verification of the required logic output. The ACTUATION LOGIC TEST shall include a continuity check, as a minimum, of output devices. ANALOG CHANNEL OPERATIONAL TEST 1.3 An ANALOG CHANNEL OPERATIONAL TEST shall be the injection of a simulated signal into the channel as close to the sensor as practicable to varify OPERABILITY of alarm, interlock and/or trip functions. The ANALOG CHANNEL OPERATIONAL TEST shall include adjustments, as necessary, of the alarm, inter-lock and/or trip setpoints such that the setpoints are within the required range and accuracy. - AXIAL FLUX DIFFERENCE 1.4 AXIAL FLUX DIFFERENCE shall be the difference in normalized flux signals between the top and bottom halves of a two section excore neutron detector. CHANNEL CALIBRATION i 1.5 A CHANNEL CALIBRATION shall be the adjustment, as necessary, of the channel such that it responds with the required range and accuracy to known values of input. The CHANNEL CALIBRATION shall encompass the entire channel including the sensors and alarm, interlock and/or trip functions and may be performed by any series of sequential, overlapping, or total channel steps such that the entire channel is calibrated. CHANNEL CHECK , 1.6 A CHANNEL CHECK shall be the qualitative assessment of channel behavior during operation by observation. This determination shall include, where possible, comparison of the channel indication and/or status with other indications and/or status derived from independent instrument channels measuring the same parameter. W-STS 1-1 SEP 151981
! DEFINITIONS CONTAINNENT INTEGRITY 1.7 CONTAlletENT INTEGRITY shall exist when: I
- a. All penetrations required to be closed during accident conditions are either:
- 1) Capable of being closed by an OPERABLE containment automatic isolation valve system, or
- 2) Closed by manual valves, blind flanges, or deactivated automatic valves secured in their closed positions, except as provided in Table (3.6-7) of Specification (3.6.9e+).
- 2. 3
- b. All equipment hatches are closed and sealed,
- c. Each air lock is OPERABLE pursuant to Specification (3.6.l.3),
- d. The containment leakage rates are within the limits of Specification (3.6.1.2), and
- e. The sealing mechanism associated with each penetration (e.g., welds, bellows, or 0-rings) is OPERABLE.
CONTROLLED LEAKAGE 1.8 CONTROLLED LEAKAGE shall be that seal water flow supplied to the reactor coolant pump seals. CORE ALTERATION 1.9 CORE ALTERATION shall be the movement or manipulation of any component within the reactor pressure vessel with the vessel head removed and fuel in , the vessel. Suspension of CORE ALTERATION shall not preclude completion of l movement of a component to a safe conservative position. DOSE EQUIVALENT I-131 1.10 DOSE EQUIVALENT I-131 shall be that concentration of I-131 (microcurie / gram) which alone would produce the same thyroid dose as the quantity and isotopic mixture of I-131, I-132, I-133, I-134, and I-135 actually present. The thyroid dose conversion factors used for this calculation shall be those listed in , Table III of TID-14844, " Calculation of Distance Factors for Power and Test l i Reactor Sites." l E - AVERAGE DISINTEGRATION ENERGY 1.11 E shall be the average (weighted in proportion to the concentration of each radionuclide in the reactor coolant at the time of sampling) of the sum of the average beta and gamma energies per disintegration (in MeV) for isotopes, other than iodines, with half lives greater than 15 minutes, making up at least 95% of the total noniodine activity in the coolant.
-W-STS 1-2 SEP 151981
l l DEFINITIONS . l ENGINEERED SAFETY FEATURE RESPONSE TIME l 1.12 The ENGINEERED SAFETY FEATURE RESPONSE TIME shall be that time interval l from when the monitored paramater exceeds its ESF actuation setpoint at the channel sensor until the ESF equipment is capable of performing its safety function (i.e., the valves travel to their required positions, pump discharge pressures reach their required values, etc.). Times shall include diesel generator starting and sequence loading delays where applicable. FREQUENCY NOTATION 1.13 The FREQUENCY NOTATION specified for the performance of Surveillance hg w Requirements shall correspond to the intervals defined in Table 1.2. N 1-
- W M,g IDENTIFIED LEAKAGE EE 2Mg 1.14 IDENTIFIED LEAKAGE shall be:
H% a. Leakage (except CONTROLLED LEAKAGE) into closed systems, such as pump seal or valve packing leaks that are captured and conducted to a sump or collecting tank, or
- b. Leakage into the containment atmosphere from sources that are both specifically located and known either not to interfere with the operation of leakage detection systems or not to be PRESSURE BOUNDARY LEAKAGE, or
- c. Reactor coolant system leakage through a steam generator to the secondary system.
- 1 MASTER RELAY TEST 1.15 A MASTER RELAY TEST shall be the energization of each master relay and 3^ verification of OPERABILITY of each relay. The MASTER RELAY TEST shall include
}--.G$ a continuity check of each associated slave relay.
Cd W$a---eOPERABLE - OPERABILITY MD J . Qg; 1.16 A system, subsystem, train, component or device shall be OPERABLE or have OPERABILITY when it is capable of performing its specified function (s), bhq3 and when all necessary attendant instrumentation, controls, electrical power, cooling or seal water, lubrication or other auxiliary equipment that are required for the system, subsystem, train, component, or device to perform its function (s) are also capable of performing their related support function (s). OPERATIONAL MODE - MODE 1.17 An OPERATIONAL MODE (i.e., MODE) shall correspond to any one inclusive combination of core reactivity condition, power level, and average reactor coolant temperature specified in Table 1.1. W-STS 1-3 SEP 151981
k Q DEFINITIONS h g PHYSICS TESTS d 1.18 PHYSICS TESTS shall be those tests performed to measure the fundamental nuclear characteristics of the reactor ccre and related instrumentation (1) described in Chapter (14.0) of the FSAR, (2) authorized under the g {f, provisions of 10 CFR 50.59, or (3) otherwise approved by the Commission. A0 j g PRESSURE BOUNDARY LEAKAGE N 1.19 PRESSURE BOUNDARY LEAKAGE shall be leakage (except steam generator tube Ileakage)throughanonisolablefaultinaReactorCoolantSystemcomponent
, body, pipe wall, or vessel wall.
T I QUADRANT POWER TILT RATIO 1.20 QUADRANT POWER TILT RATIO shall be the ratio of the maximum upper excore detector calibrated output to the average of the upper excore detector cali-brated outputs, or the ratio of the maximum lower excore detector calibrated . output to the average of the lower excore detector calibrated outputs, whichever l is greater. With one excore detector inoperable, the remaining three detectors ! > shall be used for computing the average. w W RATED THERMAL POWER y) Q ,, 1.21 RATED THERMAL POWER (.RTF) shall be a total reactor core heat transfer rate to 3 w the reactor coolant of 3W/ MWt. u Qb
}' -
4 REACTOR TRIP SYSTEM RESPONSE TIME g
$ 1.22 The REACTOR TRIP SYSTEM RESPONSE TIME shall be the time interval from F when the monitored parameter exceeds its trip setpoint at the channel sensor until loss of stationary gripper coil voltage. .
1 REPORTABLE OCCURRENCE 1.23 A REPORTABLE OCCURRENCE shall be any of those conditions specified in Specifications 6.9.1.8 and 6.9.1.9. l f ( l f-STS 1-4 SEP 151981
DEFINITIONS 2::L: CL':L^: Z IPT:^^:Tl 1.24 ~;;;:' 0 mHT' nTun :y7:r;7l ,,,,, , _ ,; ; _ ,,, c.- ewh door in each access opening is closed except when the opening used for normal transit entr , then at least one door s losed,
- b. The shield buildin
ion syste . c BLE, and
- c. ing mechanism associated with each penetrati ., welds, bellows, or 0-rings) is OPERABLE. .
SHUTDOWN MARGIN 1.25 SHUTDOWN MARGIN shall be the instantaneous amount of reactivity by which the reactor is subcritical or would be subcritical from its present condition
- b. assumingi cd.
g 2. = 2x;: ' ,. . . . n . . . .. . . . o g....., .. .: 6 1 full length rod cluster assemblies (shutdown and control) are fully inserted except for the single rod cluster assembly of highest reactivity worth which is assumed to be fully withdrawn. M3
- & SLAVE RELAY TEST
]E M y g 5 1.26 A SLAVE RELAY TEST shall be the energization of each slave relay and w f, verification of OPERABILITY of each relay. The SLAVE RELAY TEST shall include 1
' Q continuity check, as a minimum, of associated testable actuation devices.
STAGGERED TEST BASIS 1.27 A STAGGERED TEST BASIS shall consist of:
- a. A test schedule for n systems, subsystems, trains, or other designated components obtained by dividing the specified test interval into n equal subintervals,
- b. The testing of one system, subsystem, train, or other designated component at the beginning of each subinterval.
THERMAL POWER 1.28 THERMAL POWER shall be the total reactor core heat transfer rate to the reactor coolant. W-STS 1-5 SEP 151981
DEFINITIONS TRIP ACTUATING DEVICE OPERATIONAL TEST 1.29 A TRIP ACTUATING DEVICE OPERATIONAL TEST shall consist of operating the Trip Actuating Device and verifying OPERABILITY of alarm, interlock and/or trip functions. The TRIP ACTUATING DEVICE OPERATIONAL TEST shall include adjustment, as necessary, of the Trip Actuating Device such that it actuates at the required setpoint within the required accuracy. UNIDENTIFIED LEAKAGE
% 1.30 UNIDENTIFIED LEAKAGE shall be all leakage which is not IDENTIFIED LEAKAGEj pr CONTROLLED LEAKAGEg er PR,essues %ws4g.V trakass.
i Q
- Mt47=> 04AufT TF44r#47 5957v6 l h w YorriM4 D
l
' -STS f 1-6 SEP 151c81
l0SE1LT lo/JS FoR wpipiTroMS I 1.0 DEFINITIONS I CH k t CALIBRATION
}' 1.9 A CHs CL CALIBRATION shall be the adjustment, as necessa , of the j channel outp such that it responds with the necessary ran and accuracy to known values f the parameter which the channel monitor . The CHANNEL CALIBRATION shall ncompass the entire channel includin he sensor and i
alam and/or trip f ctions, and shall include the CH EL FUNCTIONAL TEST. iThe CHANNEL CALIBRATI may be performed by any ser' s of sequential, over-
; lapping or total channe teps such that the enti channel is calibrated.
lCHANNELCHECK g l.10 A CHANNEL CHECK shall be the ua tative assessment of channel be-o havior during operation by observati . This detemination shall include,
- where possible, comparison of the an 1 indication and/or status with
.other indications and/or status rived om independent instrumentation
; channels measuring the same pa eter.
CHANNEL FUNCTIONAL TEST 1.11 A CHANNEL FUNC' NAL TEST shall be:
- a. Analog annels - the injection of a simulated ignal into the annel as close to the sensor as practicab to verify OPFJiBILITY including alam and/or trip functions.
- b. istable channels - the injection of a simulated sign into the sensor to verify OPERABILITY including clam and/or rip
.: functions.
E l i!SOURCECHECK 1.h A SOURCE CHECK shall be the qualitative assessment of channel jresponse when the channel sensor is exposed to a radioactive source. PROCESS CONTROL PROGRAM 1.% 1,JC A PROCESS CONTROL PROGRAM (PCP) shall be the manual or set of operating procedures detailing the program of sampling, analysis, and evaluation within which SOLIDIFICATION of radioactive wastes from liquid systems is assured. Requirements of the PCP are provided in Specifica-tion 6.14. l PWR-STS-1 1-1 t
y $ @ T\D @ FCC M flNITI W ! '1. 0 CEFINITICNS (Centinued)
^CL:::F;;ATICe
^;;;;;.;;nT.a saa.. su ...e
;;7;;rg': :' ;d':; tic; 3:t:- 'm
..m 2, .em w . ov...w enegus iao o .., . . . . ..e,.....-._, .
'-^^ " d r d ::l i d ,, . wu wwiiu. . wl o.u. onu anags, . ... . :; d i; : :::b ' 1 0,. ^ f; s wi w . a i. s uu i vuwiine an ali aswsa '7 ;; ;t;-ding',g 0FFSITE DOSE CALCULATION MANUAL (CDCM)
- 1. An CFFSITE DOSE CALCULATION MANUAL (CDCM) shall be a manual contain-ing the methodology and parameters to be used in tne calculation of off-site doses due to radioactive gaseous and liquid effluents and in the calculation of gaseous and liquid effluent monitoring instrumentation alar n/ trip setpoints. Requirements of the ODCM are provided in Specification 6.15.
I GASEOUS RADWASTE TREATMENT SYSTEM
- 1. A GASEOUS RADWASTE TREATMENT SYSTEM is any system designed and in-stalled to reduce radioactive gaseous effluents by collecting primary coolant system offgases from the primary system and providing for delay jor holduo for the purpose of reducing the total radioactivity prior to l release to the enviroment.
VENTILATION EXHAUST TREATMENT SYSTEM
- 1. A VENTILATION EXHAUST TREATMENT SYSTEM is any system designed and installed to reduce gaseous radiofodine or radioactive material in parti-culate fonn in effluents by passing ventilation or vent exhaust gases through charcoal adsorbers and/or HEPA filters for the purpose of removing iodines or particulates from the gaseous exhaust stream prior to the release to the enviroment. Such a system is not considered to have any effect on noble gas effluents. Engineered Safety Feature (ESF) atmospheric cleanup systems are not considered to be VENTILATION EXHAUST TREATMENT SYSTEM components.
Soc.:D pacarsoA) 1.31 Soubo!!c4rMA) shall be /be immolllieadon olved endonebW wasfer yn+ restas, slud3 <s, and rwerse osmos} r canceidiule.r suek as a resas es arafar Lollwu,4 +h*"*ghl faPr=uuo t ~W"8 dewadeEYPC &R sounwacwe agcnico += 4=c~ a he s-landin ldh wi-ik chem *eal and ek,sseaI chaeaelenslies sensed in the.g nenoProcess confco/ heg PWR-STS-1 1-2
DUKE POWER COMPANY Form 00184 (6-81) Dev./ Station Unit File No. - ! Subject h N N I _ [-__ lN ) By Date i
. Sheet No. of Problem No. Checked By Date '
,1 l i ,
! j i l l l ! l i
; i i i i ! , ! ! !
l l ! ! l l ! tj l r l l l l ! l l l ! ! l l I ! 4- 1 PURGE - PURGING l , i I i i l i ! l ! l i I l I
~
l i i l l l 1.23 PURGE or PURGING is the controlled process of discharging air or gas , - from a confinement to maintain temperature, pressure, humidity, concentration I l or other operating condition, in such a manner that replacement air or gas is j required. ll ! , I [
'. , , 4 i 1 i i : i i ! i i l , !f ,'
REACTOR BUILDING INTEGRITY l
! j !
l 1.26 REACTOR BUILDING INTEGRITY shall exist when: {
, I. '
a. The door in each access opening is closed except when the access ! ll ; opening is being used for normal transit entry and exit, I i i l b. The annulus ventilation system is OPERABLE, and
- i ; ;f ij -
; c. The sealing mechanism associated with each penetration (e.g., welds, !
i- bellows or 0-rings) is OPERABLE. ; jj , , i 6 ' I i i
' i i
j! i I ! I ' l I
! l I ! l l l l l l I I l
- i. VENTING il l > i
! ! 1.38 VENTING is the controlled process of discharging air or gas from a l t !
i l confinement to maintain temperature, pressure, humidity, concentration or l l l other operating condition, in such a manner that replacement air or gas is I ' I i , not provided or re;uired during VENTING. Vent, used in system names, does ! ; l .l not imply a VENTING process. l I i
' ! I I ! l l t l ! !
l I l, I! ! l : ; i ! : ! i i I l j 1 i I I l l l i i l ii ! ! ! : l ! !i l ! l ! l! ! l l l l ! l 1I i : l i; ! I I : : : I i! ! i j i !! i l i ! ! l ! l l i
! ! l l l l l l l t l I ;
l l ! ! , i i i
!! l ! l ! i l I I l i r i ! I i i l ! l l l ; ! ! ! ! ! l ! I i ll l l i i i ! : ,
! l
! l ! : i ;I i ! i i i i ,
H i i . i
. . . , o 8 I ! j i ! l l l ! ! l ! i i ll l i l i i
l !l ! ! i , ! l l ! ! il l
! I l I i l i l l
!! l l l i l ! , ! ! l l l ! ; l
TABLE 1.1 OPERATIONAL MODES REACTIVITY % RATED AVERAGE COOLANT MODE CONDITION, K THERMAL POWER
- TEMPERATURE df
- 1. POWER OPERATION > 0.99 > 5% > 350*F
- 2. STARTUP > 0.99 5 5% > 350*F
- 3. HOT STANDBY < 0.99 0 > 350*F
- 4. HOT SHUTDOWN < 0.99 0 350*F
> 200*F> T*V9
- 5. COLD SHUTDOWN < 0.99 0 1 200*F
- 6. REFUELING ** i 0.95 0 $ 140*F
- Excluding decay heat.
** Fuel in the reactor vessel with the vessel head closure bolts less than fully l l tensioned or with the head removed.
l l l i jf-STS 1-7 Ayg 7 195
a TABLE 1.2 FREQUENCY NOTATION NOTATION FREQUENCY S At least once per 12 ' urs. O At least once per 24 hours. W At least once per 7 days. M - At least once per 31 days Q At least once per 92 days. SA At least once per 184 days. R At least once per 18 months. S/U Prior to each reactor startup.
'? doenpleled pelar .fo tack release, N.A. Not applicable. ,
w-sTs 1-8
SECTION 2.0 SAFETY LIMITS AND LIMITING SAFETY SYSTEM SETTINGS J i
2.0 SAFETY LIMITS AND LIMITING SAFETY SYSTEM SETTINGS 2.1 SAFETY LIMITS REACTOR CORE 2.1.1 The combination of THERMAL POWER, pressurizer pressure, and the highest operating loop coolant temperature (T shall not exceed the limits shown in Figures 2.1-1 2nd 2. ' 2 '.. En" '*VE);3 : operation., ::p;;ti;;'js APPLICABILITY: MODES 1 and 2. I'*P ACTION: Vah Whenever the point defined by the combination of the highest operating loop average temperature and THERMAL POWER has exceeded the appropriate pressurizer pressure line, be in HOT STANDBY within 1 hour, and comply with the require-ments of Specification 6.7.1. REACTOR COOLANT SYSTEMjPRESSURE 2.1.2 The Reactor Coolant System pressure shall not exceed 2735 psig. APPLICABILITY: MODES 1, 2, 3, 4, and 5. ACTION: l ( MODES 1 and 2 Whenever the Reactor Coolant System pressure has exceeded 2735 psig, be in HOT STANDBY with the Reactor Coolant System pressure within its limit within 1 hour, and comply with the requirements of Specification 6.7.1. MODES 3, 4 and 5 Whenever the Reactor Coolant System pressure has exceeded 2735 psig, i reduce the Reactor Coolant System pressure to within its limit within ) 5 minutes, and comply with the requirements of Specification 6.7.1. i l 1 l l r l l
-W-STS 2-1 SEP 2 81981
680 i i, ' .> , , , , ,_ . , , m 1 r6 , 3 iii t i
.. ,i , , , , .
, ; a . 6
' > i 4
UN ACCEPTA B LE :
-l' 2400 PSI A . 'll' O PER ATIO N 660 -
, ml' ' '
;,' ',l, l . ,,
+; ,
- + 3
-m Nm ' ii %
i z m .N ,s , i m, i , 640 C . L
,m, , _ ..
s
.s.
i 2250 PSI A#' '
~
A l
N l m ,. &
THIS FIGURE FOR ILLUSTRATION ONLY
' N C ,. m . DO NOT USE FOR OPERATION m s 620
, m ,<
s.s.
, , , , ii , m . s . .
. ... . ... ,, .# ,i w 1 4 . s
( 2000 PSI A I' i i N L s. " i8 ' o, m ,. m ,' s s s s w
- s. s: s, e m . . .
m 4
, .-s
.m- ,
s s s s s'. s
< 600,l i N
, m i 'k s
s s
=
i i , , , i os .m i . s. s, u ..s F" p t i N 4 s. s, , 'Li M1700 PSI A-1
+ . ' w
.~ ,
i s, x,' g_
, m . = s m.'s s,
, s 5 , 4 i i
'h ' L,
, , . , , ,, . m q ,,
. m s.
s' 1
.t I s 580 s s .s
, , i w ,s s.
i i % , % 1 1 , i s 'Li i s, s-
, s
~ W* s
'a' lW' 560' AC CEPTAB LE ,, ,
,\.,
O PE R ATIO N l ' :
'4
.'s--
1 540 ,
, , , i e:-
l > 520 0 0.2 0.4 0.6 0.8 1.0 1.2 FRACTION OF RATED THERMAL POWER FIGURE 2.1-1 REACTOR CORE SAFETY LIMIT - FOUR LOOPS IN OPERATION W-STS 2-2 SEP 1 1974
.s....
. . . n... ._ .... . . ..... . .....i.
.. _ . , . ~..
. . . . = _ ...U_ __ _. --.- _.
.,.._..1,._..__. ,
. ___ . . _____._... _... ..J..._. -
. . _ . . . . . . . ..-,2400 PSIA 660 _ _ . . _ _ . . . .
_ - -- . . UNACCEPT . LE._ -
.. a.._ ._... _ . . f_._.... ...
OPERA
. . _ _ n...,- . - .... .. ...._,.
_ _ _ .. N . . -.. _ . . . . _ . . , _ , f._
- q. . . .._..
.. ._. .. . ._ :I. . . _.._...
- w. _ . . . _ _.. . . . . . _ _ . . ._
._.. h.. ._.t._
.. _w ._.. ..p . __ .
_ . . . _.._. .. .. .. ~ . _. .,4... ._ , ._ .. . ._ .__. ._.
....t...
%. . ~ - . _ . ._ .. r_._
.... _ t . .,% , .._ .. .. . _ . ._. . _ _ _
.. ..... 4. .... . . . . _ .
. . . . . r. .. ..- . .
.. . . .~ . __ . ._._.._
.._..f._.. .
..... 2250 PSI A,
... . ._-~ ..
....+ -- .- - - . _..
< - - .- ! - m- ---- -- -. - - -.-._ - ---i - -
- 1. . .. . . . .
......t.... ..(
(. . . p_._ . , , _ ___l +.. = .
.. ..+..... .. . ,_ _. _.. .. .-
c.
..._4.__.
,- ww _ r_ v
. . .. . . . . . . . . .. ,f %._ ..
_mt.:._ . ._.
. .... ._. + = .. ._. .. . _ . - . . ...
. . . L. .. .
.... ... . 3 . ... .
._.I r_ . .,.
M. C
.... _ . .' . _ ._ s- .
- .k . ..~ .. ...~ .. ... .
. ._.-4..... . .. .. . -
. _ _ %_..__,.g__- .. . . . .. . .
, en
. -t ....2000 PSI A'. i . ...- -
.. - - . ._ .. . _ ... . ...-- H. - . _ -_. - .. . . _ . * . - ~ . . .
4 . . .,-....p.... ,
. ..g .. . . . .. . ...
H *
. ~* :. :.. - .I 3
THIS Fl RE FOR IL STRATION ONLY
. ;t ' '
. : p" *:
-- ~
l .- NOT USE FOR ERATION , m .
._...r...., .. . . . . .
o .,. . c: 600
, , ,r. ... . . - . . ..
........_.w
... .... ..._. , . .. .. . .. _4_...
. ,i.. - .i.. ...
.t.. ... ... ... 1.. ...
.... ..t.....
1.. .
..t..
. . . . .(.. .
.e
.. .. . + _ . . .
(....._
. . . . . ..4 AC TABLE 9..
. . . . .. c .. ... . . . _ . . . ,
RA I N ..
. .y L. . .. . . . . _ . .
.t. . . .. . ..I.
.. ... ...t 560
. .4 4 .. g. .. 4 0 0.2 0.4 0.6 0.8 FM%i aviv Oi ha i tu I HERMAL ruvv ch -
e cint mc o .1- o we.,1 U R CU H t: 5Al- t: 11
- t. i m . .
. . .. ni nc nr-rw emi - -_ _ _ . _ . . , v r u na l IU N 'W-STS 2-3 SP1 1gy
SAFETY LIMITS AND LIMITING SAFETY SYSTEM SETTINGS 2.2 LIMITING SAFETY SYSTEM SETTINGS REACTOR TRIP SYSTEN INSTRUMENTATION SETPOINTS 2.2.1 The reactor trip tystem instrumentation and interlocks setpoints shall be set consistent with the Trip Setpoint values shown in Table 2.2-1. APPLICABILITY: As shown for each channel in Table 3.3-1. ACTION: gy G ,e raak u m stkf5 only) With a reactor trip system instrumentation :r i..te. ?:2 setpoint 1ess 3 conserv-ative than the value shown in the Allowable Values column of Table 2.2-1, *+.-., declare the channel inoperable and apply the applicable ACTION statement requirement of Specification 3.3.1 until the channel is restored to OPERABLE status with its trip setpoint adjusted consistent with the Trip Setpoint value. s a ,, M .,m,.. u 4. fit ~ry r fi., u - i-4.c.n, .r.L w a..,,s, 2 @S 4 T4 u% ace:
'l , L n Ga .(c. n col w n 4. of ~1able 2.2-l he L Nedel &nn*I, y u ~.s ~. sad ' du an ganea) ,4 cacL ac;4 Ac A< a(4d d ci, nat,
$ = de A< as rna.surab <a ka on encas 3 ,( s seas,,. J,.;p, ,, g, g, ;,
colum S of Tale 2.2.-l b ne effed.J ch.n 4 and 3 T4 - 4he value from co! TA aJ takt. 2 2.-I Ac 44, aff<cfe/ ch nnel o r-l l PSTS 2-4 SEP 1 1979 l l
I LE 2.2-I REACTOR TRIP SYSTEM INS F ATION TRIP SETPOINTS
" TRIP SETPOINT ALLOWABLE VALUES FUNCTIONAL UNIT
- 1. Manual Reactor Trip Not Applicable Not Applicable
{
- 2. Power Range, Neutron Flux Low Setpoint 1 (25)% of RATED Low Setpoint - 1 (26)% of RATED
. THERMAL POWER THERMAL POWER l l High Setpoint - 1.(109)% of RATED High Setpoint - 1 (110)% of RATED K
! THERMAL POWER THERMAL POWER t
- 3. Power Range, Neutron Flux, < (5)% of RATED THERMAL POWER with < (5.5)% of RATED THERMAL POWER High Positive Rate a ti4e constant > (1) second with a time constant > (1) second 01
- 4. Power Range, Neutron Flux, 1 (3)% of RATED THERMAL POWER with 5 (3.5)% of RATED THERMAL POWER i
High Negative Rate a time constant > (1) second with a time constant > (1) second 4, 5. Intermediate Range, Neutron 1 (25)% of RATED THERMAL POWER 1 (30)% of RATED THERMAL POWER 2 Flux g , 5 5
- 6. Source Range, Neutron Flux $ (10 ) counts per second 5 (1.3 x 10 ) counts per second g
- 7. Overtemperature AT See Note 1 See Note 3
- U 1 8. Overpower AT See Note 2 See Note 3 '
< 9. Pressurizer Pressure--Low > (1865) psig > (1855) psig j 10. Pressurizer Pressure--High. 1 (2385) psig 1 (2395) psig I 11. Pressurizer Water Level--High 5 (92)% of instrument span 1 (93)% of instrument span g
- 12. Loss of Flow > (90)% of design flow per loop *
> (89)% of design flow per loop
- m '
N
- Design flow is ( ) gpm per loop. i O
3 1 4
F TA 4E 2.2- (Continued) REACIORTRIPSYSTEh/kSTRUMENTATIONTRIPSETPOINTS FUNCTIONAL UNIT TRIPSETP0ld ALLOWABLE VALUES i 13. Steam Generator Water 1 (10%) narrow ange instrument 1 (9%) of narrow range instrument Level--Low-Low span-e steam De rator span-each steam generator i 1 14. Steam Generator Water 1 (25%) of narrow ran e instru- 1 (24%) of narrow range instru-I Level-Low ment span--each steam generator ment span--each steam generator Coincident With Steam /Feedwater 5 (40%) of full steam flow at Flow Mismatch 5 (42.5%) of full steam flow at RATED THERMAL POWER RATED THERMAL POWER i
- 15. Undervoltage-Reactor 1 (2750) volts each bus Coolant Pumps 1 (2710) volts each bus
- 16. Underfrequency-Reactor m 1 (57.5) Hz each bus
& Coolant Pumps 1 (57.4) Hz - each bus
- 17. Turbine Trip A. Low Trip System 1 (900) psig 1 (800) psig Pressure B. Turbine Stop Valve 1 (1%) open 1 (1%) open Closure
- 18. Safety Injection Input Not Applicable Not Applicable from ESF
- 19. Reactor Coolant Pump Not Applicable Not Applicable Breaker Position Trip E o 00 lb
TABLE -1 (Conti ) REACTOR TRIP SYSTEM INS ENJ ION TRIP SETPOINTS FUNCTIONAL UNIT TRIP / 0 I ALLOWABLE VALUES
- 20. Reactor Trip System Interlocks A. Intermediate Range Neutron > 1 x 10 -10 an.ps > 6 x 10'II amps Flux, P-6
{ i B. Low Power Reactor Trips Block, P-7
- a. P-10 Input 10% of RATED < 11% of RATED lilERMAL POWER > 9%, E POWER TilERMA
- b. P-13 Input < 10% RTP Turbine < 11% RTP Turbine Impulse Pressure Impulse Pressure "4 Equivalent Equivalent C. Power Range Neutron Flux, P-8 5 35% of RATED $ 36% of RA1ED THERMAL POWER TilERMAL POWER D. Low Setpoint Power Range Neutron 10% of RATED > 9%, < 11% of RATED Flux, P-10 TilERMAL POWER IllERMAE POWER E. Turbine Impulse Chamber Pressure, < 10% RTP Turbine < 11% RTP Turbine P-13 Impulse Pressure Tapulse Pressure Equivalent Equivalent
- 21. Reactor Trip Breakers Not Applicable Not Applicable
- 22. Automatic Trip Logic Not Applicable Not Applicable es Q) e
TAILLE 2.2-1 (Continued) REACTOR TRIP SYST TRUMENTATI RIP SETPOINTS x NOTATION 1 1+1S7 1 NOTE 1: Overtemperature AT (1 *y t S) $ AT, {K1 - 2 (1 + gS)[T(3 7 3)-T'] + K3 (P-P') - fy(AI)] I where: y,7
= Lag compensa r on measured AT 1 e 1 =
1 Time constants utilized in the lag compensator for AT3 '1 = (2) secs.
= Indicated AT at RATED TilERMAL POWER AT, Ky 3 (1.1<)
'? K = (0.009)
= 2 1+1 25
=
3,73 The function generated by the lead-lag controller for T,yg dynamic compensation
=
r2' E '3 Time constants utilized in the lead-lag controller for T,yg, r2= 13 = (4) secs. secs., T = Average temperature "F l
=
y,7 g Lag compensator on measured T,yg l 1 = l u 4 Time constant utilized in the measured T,yg lag compensator, 14 = (2) secs. E T' i -(E?'2 . ^Ti Reference T,yg at RATED THERMAL POWER oo = K 3 (0.00043) (O l i
a T
,V TABLE 2.2-1 (Continue REACTOR TRIP SYSTEM STRUMENTATI TRIP SE1P0lNIS NOTATIO Contfued)
NOTE 1: (Continued) ,,/ \
/
P = Pressurize.<hressure,psig s\ ' l P' = (2235) p ig (Nominal RCS operating sure) , S = Laplace transform operator, sec and f j (AI) is a function of the indicated difference between top and bottom detectors of the power-range nuclear ion chambers; with gains to be selected based on measured instrument response during plant startup tests such that: (i) for q g gb between (- 30) percent and (+ 4) percent, fj (AI) = 0, where qt ""d Ub ' I 4 are percent RATED THERMAL POWER in the top and bottom halves of the core respectively, and qt
- 9b s o al Tham NR in percent of RAM THRMAL NR.
(ii) for each percent that the magnitude of qt qbexceeds (-30) percent, the AT trip setpoint shall be automatically reduced by (0.89) percent of its value at RATED THERMAL POWER.
- (iii) for each percent that the magnitude of qt ~Ub exceeds (+4) percent, the AT trip l setpoint shall be automatically reduced by (0.80) percent of its value at RATED 1 THERMAL POWER.
1 i C
- o ao E &
o a
N LE 2.2-1 (Continued $ REACTOR TRIP SYST SIRUMENTAT TRIPSETP0lNy NOTATION ( ti g
/'; c \
N01E 2: l rS 1 \ 1 Overpower AT (1
- r S) 1 AT, {K 4 -K 3 (y ,,f '/t3)(y,73)T- h y
5 4
) - I"] - f I^III 2
Where: y, = as defined in N e1 3
=
1 3 as defined in Note 1 AT g = as defined in Note 1 K 4 5 (1.087) c 7 K =
- G 5 (0.02/"F) temperaturefor increasing average temperature and (0) for decreasing averaue l
- '50 =
y,73
- 5 The function Generated by the rate-lag controller for T,yg dynamic compensation t =
5 Time constant utilized in the rate-lag controller for T,yg, 13 = (10) secs.
=
y,g3 as defined in Note 1
=
1 4 as defined in Note 1 1 K = 6 1 p (0.0012) for T > T" and K6 = (0) for T 1 T" 8 T = as defined in Note 1 ao I" = w (1 578.2 F) Reference T,yg at RATED TilERMAL POWER 9 5 = as defined in Note 1 f 2(AI) = 0 for all Al
f TABk2.2-1(Continue #[ HEAC10R TRIP SYSTEM TRUMENTAT TRIP SE1 POINTS x .. 4 NOTATION (Continued) 1 Note 3: The channel's maximum trip point shall not excee s'its computed trip point by more than 2 percent. N T M i f C m .i m b
\AFETYLIMITSANDLIMITINGSAFETYSYSTEMSETTINGS x
- 2. MITING SAFETY SYSTEM SETTINGS INSTRUME ETPOINTS REACTOR TRIP TEM 2.2.1 The Reactor i ip System instrumentation set ints shall be set consis-tent with the Trip Seu int values shown in Tabl .2-1.
APPLICABILITY: As shown each channel in ble 3 3-1. ACTION: A. With a reactor Trip System in ruyntation channel setpoint (for rack components only) less conservati than the value shown in the Allewable Values column of Table 2.2-1, efti determine that the following equationismetfortheaffecpdcha el: Z + R + S 1 TA where:
=
Z the value from clumn Z of Table 2.2-1 fo the affected channel, R = the "as mea red" value (in percent) of rac drift for the affected channel, S = either e "as measured" value (in percent) of e sensor drift, or the value in column S of Table 2.2-1 for the 'fected channel, and
' TA = t value from column TA of' Table 2.2-1 for the affe ed channel, or d lae the channel inoperable and apply the applicable A TION state-men requirement of Specification 3.3.1.1 until the channel i. restored to OPERABLE Status with its trip setpoint adjusted consistent ith the ip Setpoint value. -
l l \ CATAWBA - UNIT 1 2-3
g TABLE 2.2-1 s2 g REACTOR 1 RIP SYSTEM INSTRUMENTATION TRIP SETPOINTS SENSOR g FUNCTIONAL UNIT TOTAL All0WANCE (lA} Z DRIFT (S) TRIP SETPOINT ALLOWABLE VAluE G
~ 1. Manual Reactor Trip Not Applicable NA NA NA NA
- 2. Power Range, Neutron Flux, Low Setpoint 8.3 4.61 0 1 2S% of RTP 1 27.1% of RIP liigh Setpoint 7.5 4.61' 0 1109% of RTP 1111.1% of RTP
- 3. Power Range, Neutron SJ9./2 5cced.f /2 Secoads flux,liigh Positive 2.0 0.5 0 1 4-GEJof RTP i* 6.
i -- - ^30~ f* RT 3% P J t' 2 Rate ai" : *'r _
" * ? ^ - ' '
T 2"li .1 '- 2 sesende
'$ 4. Power Range, Neutron flux, liigh Negative Rate 2.0 0. 5 0 < S.0% of RTP < 6.3% of RlP with a Uith a time time constant 2 2 seconds constant > 2 seconds S. Intermediate Range, Heutron Flux 17.0 10.01 0 1 25% of RTP 1 31.9% of RIP
- 6. Source Range, Neutron flux 17.0 10.01 0 1 105 cps i 1.37 x 105 cps
- 7. Overtemperature af 4.43 1.71 0.8 See Note 1 See Note 2
- 8. Overpower AT 4.29 1.32 0.2 See Note 3 See Note 4
- 9. Pressurizer Pressure -
Low 3.0 0.71 1. 5 > 1945 psig > 1935 psig l
y 2
. TAuli .2-1 (cont inued)
[w REACTOR TRIP SYSTEM INSTRUMENTAT10N TRIP SEIPOINIS w N SENSOR [ FUNCTIONAL UNIT TOTAL ALLOWANCE (TA) Z DRIFT (S) TRIP SETPOINT ALLOWABLE VAlt!!_ E 10. Pressurizer Pressure - liigh 3.1 0.71 1.5 1 2385 psig i 2396 psig
- 11. Pressurizer Water Level - liigh 5. 0 2.18 1. 5 5 92% of in- i 93.75% of instrument strument span span
- 12. Loss of Flow 2. 5 1.0 1. 5 g 90% of loop 2 89.2% of loop design design flow
- flow"
- 13. Steam Generator oj Water Level - 'P ,
Low-Low 15.0 12.18 1.5 3 12% of span '), 2 0.25% of span from 0% from 0% to to RTP increasing RTi$ increasing linearly to 2 53.15% of linearly to 1 span f rom WE to 100% 7 54.9% of span RTP. 3o'/, ui from JdK to 100% RIP 30 %
- 14. Undervoltage -
Reactor %72 kv Coolant Pumps 5.0 SAR SAR 1 se 7x .=- SAR
-velte
- 15. Underfrequency -
Reactor Cool-ant Pumps 1. 3 SAR SAR 156/liz SAR
- 16. Turbine Trip 550 500 A. '_ ..e32- 7 SAR SAR SAR 1 $E'psig l g psig
, .._...m m B. Tu, u me aup vaive u.omo,m SAR SAR SAR 1 1% open 1 1% open
- Loop design flow = 96,900 gpm i
TABLE 2.2-1 (continued) SI REACTOR 1 RIP SYSTEM INSTRUMENTAIION TRIP SETPOINTS i c- SENSOR } FUNCIl0NAL UNIT TOTAL All0WANCE (TA) Z DRIFT _(S) TRIP SETPOINT ALLOWABLE VAlut
- 17. Safety Injection Input from ESF NA NA NA NA NA
- 18. Reactor Trip Breakers NA NA NA NA NA
- 19. Automatic Trip Logic Ne NA NA NA NA 1*rS 1 1+rS l 4 N01E 1: Overtemperature al (y , 3) (g , g) 1 AI, {K3 -K 2 I l*t S) [T(7 , , g)-T'] + K 3(P-P') - f (AI))
3 l Where: 1+I gS 7, 3 = Lead-la0 compensator on measured AT r,r g 2
= Time constants utilized in the lead-lag controller for AT,17 = 8 secs, 1 2= 3 secs. l 1
3, = Lag compensator on measured Al 1 3 = lime c nstants utilized in the lag compensator for AT, 13 = 2 secs. Al g = Indicated AI at RATED TilERMAL POWER
- u K
g = ,L M i.o93 K 2
* #iM"8" 0 IMI P** 'f' Ie 1 4S 3, 3 = The function generated by the lead-lag controller for Tavg dynamic compensation
9 g TABLE 2.2-1 (continued) r E REACTOR TRIP SYSTEM INSTRUMENTATION TRIP SETPOINTS E SENSOR [ FUNCTIONAL UNIT TOTAL ALLOWANCE (TA) Z DRIFT (S) TRIP SETPOINT ALLOWABLE VALU! NOTE 1: (continued)
.35 14, 15 = Time constants utilized in the lead-lag controller for Tavg, T4, = d6 secs, 1
5 = 4 secs. J T = Average temperature *F I
- y. 3 - Lag compensator on measured Tavg 1
6 = Time constant utilized in the measured Tavg lag compensator, 16 = 2 secs 588.2 T' i 409,F F (Nominal Tavg at RATED TilERMAL POWER) K 3 = W . coe m y,,, p,7 P = Pressurizer pressure, psig P' = 2235 psig (Nominal RCS operating pressure) l S = Laplace transform operator and f, (AI) is a function of the indicated difference between top and bottom detectors of the power-range nuclear ion chambers; with gains to be selected based on measured instrument
, response during plant startup tests such that:
e
?
( i) for qt 9b between -43 percent and -6.5 percent (fy (AI) = 0 (where q t and ob are l percent RATED TilERMAL POWER in the top and bottom halves of the core respectively, and qt + qb is total THERMAL POWER in percent of RATED THERMAL POWER). l i
lABLE 2.2-1 (continued) S3 REACIOR 1 RIP SYSTEM INSIRUMENTATION TRIP SETPOINTS ( ii) for each percent that the magnitude of (q t 9b) exceeds -43 percent, the AT trip l
~ setpoint shall be automatically reduced by 2 percent of its value at RATED filERMAL POWER.
(iii) for each percent that the magnitude of (q qb) exceeds -6.5 percent, the AT trip l setpoint shall be automatically reduced by 1.641 percent of its value at RAl[0 TilERMAL POWER. NOTE 2: The channel's maximum trip setpoint shall not exceed its computed trip point by more than 2.S4 percent. 1& I S TjS 1
'[ NOTE 3: Overpower AT (3 , g g ) (3 , g ) < AT, ( K4 -K 5 Il e t 73) (y , )T-K6 [T(7 , 3) - I"] - f p(AI)}
Where: 1+t Sy = as defined in Note 1 1+1 2b 13, 12 = as defined in Note 1 I
= as defined in Note 1 1*1 3b
'3 = as detined in Note 1 AT, = as defined in Note 1 K
4
=2.07:37 t.ogos K
S = 0.02 M for increasin0 average temperature and 0 for decreasing averaga temperature
'7b = lhe function generated by the rate-lag centroller for Tavg dynamic compensation 1*1 75
i l j] TABLE 2.2-1 (continued) f5 REACTOR TRIP SYSTEM INSTRUMENTATION TRIP SE1 POINTS EE NOTE 3: (continued) I El , JF 1 7 = Time constant utilized in the rate-lag controller for Tavg, t = 7JWT secs. 1 = as defined in Note 1 1+t 6b 1 6 = as defined in Note 1
. oo : z62.
K 6 = JG+ileMS/*F for T > T" and K6 = 0 for T 5 T" T = as defined in Note 1 T" = Indicated Tavg at RATED TilERMAL POWER (Calibration temperature for AT inst rumentation, 7
- 1 530 8 F) ses.z 5 = as defined in Note 1 f 2(AI) = 0 for all Al NOTE 4: The channel's maximum trip setpoint shall not exceed its computed trip point by more than 2.96 percent.
i l 4 I i
6
- 2. 2 LIMITING SAFETY SYSTEM SETTINGS INSTRUMENTATION SETPOINTS ENGINEERED SAFETY FEATURE ACTUATION SYSTEM 2.2.2 The Engineered Safety Feature Actuation System (ESFAS) instrumentation setpoints shall be set consistent with the Trip Setpoint values shown in Table 2.2-2.
APPLICABILITY: As shown for each channel in Table 3.3-3. ACTION: , A. With an ESFAS' instrumentation channel setpoint (for rack components only) less conservative than the value shown in the Allowable Values column of Table 2.2-2, either determine that equation 2.2-1 is met fer the affected channel: where: Z = the value from column Z of Table 2.2-2 for the affected channel, R = the "as measured" value (in percent) of rack drift for the ' affected channel, S = either the "as measured" value (in percent) of the sensor drift, or the value in column S of Table 2.2-2 for the affected channel, and TA = the value from column TA of Table 2.2-2 for the affected channel, j or declare the channel inoperable and apply the applicable ACTION r statement requirement of Specification 3.3.2.1 until the channel is restored to OPERABLE status with its trip setpoint adjusted consistent with the Trip Setpoint value. l l 1 CATAWBA - UNIT 1 2-10
!) TABLE 2.2-2 ll ENGINEERING SAFEIY FEATURE ACTUATION SYSTEM INSTRUMENTATION TRIP SETPOINTS SENSOR -i FUNCTIONAL UNIT TOTAL ALLOWANCE (TA) Z DRIFT (S) TRIP SE1POINI ALLOWADLE VALUF
- 1. SAFETY INJECTION, TURBINE TRIP AND FEEDWATER ISOLATION A. Manual Initiation NA NA NA NA NA B. Automatic Actuation Logic NA NA NA NA NA C. Containment Pressure
- High 3.0 0.71 1. 5 1.2 psig 1.37 psig D. Pressurizer Pressure
- Low 13.0 10.71 1. 5 1 1845 psig 2 1835 psig E. Steamline Pressure arg s n - Low 3.3 0.71 1. 5 2 JWTFpsig 1 697 psig (Note 5)
- 2. CONTAINMENT SPRAY A. Manual Initiation NA NA NA NA NA B. Automatic Actuation Logic NA NA NA NA NA C. Containment Pressure
- High-liigh 3.0 0.71 1. 5 3.0 psig 3.17 psig
- 3. CONTAINMENT ISOLATION A. Phase "A" Isolation
- 1. Manual NA NA NA NA NA
- 2. Safety Injection See 1 above (all SI setpoints)
- 3. Automatic Actua-tion Logic NA NA NA NA -
NA B. Phase "B" Isolation
- 1. Manual NA NA NA NA NA
- 2. Automatic Actua-tion Logic NA NA NA NA NA
TABLE 2.2-2 (continued)
$! ENGINEERING SAFE lY FEATURE ACTUATION SYSTEM INSTRUMENTATION TRIP SETPOINTS SENSOR EE FUNClIONAL UNIT TOTAL ALLOWANCE (TA) Z DRIFT (S) 1 RIP SETPOINT ALLOWABLE VAltlE
-i r- 3. Containment Pres-sure - liigh-liigh 3.0 0.71 1.5 3.0 psig 3.17 psig C. Purge and Exhaust Isolation
- 1. Safety Injection See 1 above (all SI setpoints)
- 2. Automatic Acuation Logic NA NA NA NA NA
- 3. Containment Radio-activity liigh SAR SAR SAR SAR SAR
- 4. STEAM LINE ISOLATION na a
A.' Manual NA NA NA NA NA B. Automatic Actua-tion Logic NA NA NA NA NA C. Containment Pres-sure - liigh-liigh 3.0 0.71 1. 5 3.0 psig 3.17 psig D. Steamline Pressure
- Low 3.3 0.71 1. 5 > 710 psig > 691 psig (Note 5)
E. Negative Steam Pres-sure Rate-liigh 4.2 0.71 1.5 5 100 psi 1 121 psi (Note 6)
- 5. TURBINE TRIP & FEED-WATER ISOLATION -
A. Steam Generator Water Level - liigh-liigh S.0 2.18 1. 5 5 82% of narrow 1 83.76% of narrow range instrument range instrument span span B. Automatic Actua-tion Logic NA NA NA NA NA
O w TABLE 2.2-2 (continued) f ENGINEERING SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION TRIP SEIP0lNTS SENSOR E FUNCTIONAL UNIT TOTAL ALLOWANCE (TA) Z DRIFT (S) TRIP SETPOINT ALLOWAHLE VAllif I _4
- 6. CONTAINMENT PRESSURE CONTROL SYSTEM
~ ~
A. : - " %d Peronirske B . '-- - i . . ". Temin de
- 7. AUXILIARY FEEDWATER ~
1 A. Manual NA NA NA NA NA j B. Automatic Actua-tion Logic NA NA NA NA NA C. Steam Generator i ro Water Level - ' h Low-Low 15.0 12.18 1.5 > P . ^~ '
> q . "....'. . . ' ,n.p n 3w _ .
., -,n.
D. Safety Injection See 1 above (all SI setpoints) E. Station Blackout SAR SAR SAR SAR SAR F. Auxiliary Feedwater Suction Pressure - Low > 2 psig'
~ ~> 1 psig i
G. Trips of Main Feed- ~ ' ~ water Pumps NA NA NA NA NA
- 8. CONTAINMENT SUMP RE-CIRCULATION A.fWSTLevel-Low " -> 120 inches -> 114 inches B. Automatic Actua- --""'" -
tion Logic NA NA NA NA NA g I2.#4 el reda b'*
- t t o.r.sbfspa [%
*% b so% 1:w sucmi.,
0"fo k 30 % KTP v~ tv ineeming \;oswl la p , ;g %3,q e s4, 1.os
;w ,,, z d y 54.<} % .( sf . m lo y*
wa% J A gg.
TABLE 2.2-2 (continued) @ ENGINEERING SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION TRIP SETPOINTS E SENSOR 4 IllNCTIONAL UNIT 101AL ALLOWANCE (TA) Z DRIFT (S) TRIP SETPOINT ALLOWABLE VALUE
- 9. LOSS Of POWER A. Grid Degraded ~
Voltage
~
3500 1 175 > 3200 volts volts with a 8.5 1 0.5 second time delay N01E 5: Time constants utilized in the lead-lag controller for Steam Pressure-Low are 17 > S0 seconds and 12 # b seconds. NOTE 6: The time constant utilized in the rate-lag controller for Negative Steaki Pressure Rate-liigh = 50 secs.
SAFETY LIMITS AND LIMITING SAFETY SYSTEM SETTINGS
- 2. 2 LIMITING SAFETY SYSTEM SETTINGS REACTOR TRIP / ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INTERLOCKS 2.2.3 The Reactor Trip System and Engineered Safety Feature Actuation System interlock setpoints shall be consistent with the Trip Setpoint values shown in Table 2.2-3.
APPLICABILITY: As shcwn for each channel in Table 3.3-5. ACTION: With a reactor trip system or engineered safety feature actuation system interlock setpoint less conservative than the value shown in the Allowable Value column of Table 2.2-3 declare the channel inoperable and apply the applicable ACTION statement of Table 3.3-5 until the channel is restored to O'ERABLE status with its trip setpoint adjusted consistent with the Trip Setpoint value. CATAWBA - UNIT 1 2-15
O m *J
- C 3 GJ
@ m 'v :. -
0 1
- E7 C - >
- E O 2: e O c:: w 2:: 2 -
@ e'3 wa @m ww Cw U
> P= 3 0 3 H3 <3 w3 : C"
- <C - 6 +J <o Ck: C >- O C1 C1 -w
@ _ 24 4 C. O Ck: C. A <A - - 4 t 6 @ % c= m W 6 cJ 4 o %J z cJ e %J ou a c. 1 3 s.
m - o< >= m m o< < %< h s 3 I - > Z Z or m e e o x M ct: Mm* z c c e m . m
- -w M.-ea s cn w w Mw m cn M.-e e
- c ee= -+ E c- e= = cn = -e -e -6 c.
M v
< Al v l>- vi- W v l>- v ik- A l>- vi Al v lo. Z C
J Ck: W
>=
Z
==
J Z < w Z @
>=
m m W .4 W -C 1
>=
m m O
=
>=
3 GJ
- c. 6 C. -
Z G Em 3 C - > c *J m C Ck: m QQ w ::3 2 -
- C ww 0 m ww > ww @
H o C -3
<Q CQ M3 < P- 3 C C"
== - 6 +3 <O 2. < C -w D C. t Ck: A 4 Q. C Gk: A Ck: O. O C 4
& ee u o %
c O.9
- - k G U
< m r %J 3C- % -.J o %J e W 3 6 o4 WWm o< o< C. C. >= 3 W
X X - > Z Ck: Z m M d' M Ck: M3- M Cz; O y p gg; a e pa ow i z - - o c. s c3 w 3 ow m m o cJ < N = b m= -* E c" e= o -= cn m - 6 . Al v l>= v l*== W v!W vl1 Aim - - vl1 Z m < w
%J w a
== >.
< w -
- w w
m c w x w W
.z e
z w +4 *a
= =
N CL 1
- a. =
- ..a. .-
x
>= c M
, - s I 2 9 t I C C. C.
>=
a w L Ck: C
=
l 0 @ E
- s. e c = - u m l
ca e, o o o -o = = .= e, a - s - a e u 4 = a. un a a a e m :.
= m m I 3 3 O Q 2 $M
, = cc , n =. v v o .. u W- , i a c= z z z :. c. - . ox . = c. , - *a = -
- e o o= :. s c. -=
m C e- oa em escn ei - o- . E i s.
-6 3u O s =i O s N- N - -
o 1 oo m e. m e. m =. o
- oe c. - z c= = . . = .. :. e s. :.
+J Eo == I I a 3 3 0 u L L L L L L me m - e .ca C @ *J Q C. Q X C X 0 X m m- 4m U
= a = x .- 2: x= x= o~ o~ w o a
- u. = e o s. c- : - :- . .e . =- c
-z w- c. w . u. :w c. z c. c. -. ::
m
- M e e. e s e en CATAWBA - UNIT 1 2-16 Rev. 1
BASES FOR SECTION 2.0 SAFETY LIMITS AND LIMITING SAFETY SYSTEM SETTINGS
NOTE The BASES contained in succeeding pages summarize the reasons for the Specifications in Section 2.0, but in accordance with 10 CFR 50.36 are not part of these Technical Specifications. 1 1 e AUG 7 1980
2.1 SAFETY LIMITS BASES i 2.1.1 REACTOR CORE ' The restrictions of this Safety Limit prevent overheating of the fuel and possible cladding perforation which would result in the release of fission products to the reactor coolant. Overheating of the fuel cladding is prevented by restricting fuel operation to within the nucleate boiling regime where the heat transfer coefficient is large and the cladding surface temperature is slightly above the coolant saturation temperature. Operation above the upper boundary of the nucleate boiling regime could result in excessive cladding temperatures because of the onset of departure h C from nucleate boiling (DNB) and the resultant sharp reduction in heat transfer R coefficient. DNB is not a directly measurable parameter during operation and therefore THERMAL POWER and Reactor Coolant Temperature and Pressure have been related to DNB." ' ' ' - - - - - ' - " - - " "' " -----'"" Jhasbeen developed to predict the DNB flux and the location of DNB for axially uniform and non-uniform heat flux distributions. The local DNB heat flux ratio, DNBR, defined as the ratio of the heat flux that would cause DNB at a particular core location to the local heat flux, is indicative of the margin to DNB. value of the DNBR during steady state al operational transien s,
- is imited to 1.30. This value corres en probabi i t confidence level that i not occur and is chosen as an appropriate margin to .
erating conditions. The curve '2.' s O sho tthe loci of points of THERMAL POWER,y of Figure Reactor Coolant / (2.1-1) System u.d and average temperature for pressure which the minimum DNBR is no less than 1.30, or the average enthalpy at the vessel exit is equal to the enthalpy of saturated liquid. is tuc& rw % Is y These curved ace based on app enthalpy3 hot channel factor, F f 1. E and areferencecosinewithapeagof1.55foraxialpowershape. AkH,llowanceis-a included for an increase in F g at reduced power based on the expression: N M 3 Fg = 1. E [1+ 0.3 (1-P)] where P is the fraction of RATED THERMAL POWER These limiting heat flux conditions are higher than those calculated for the range of all control rods fully withdrawn to the maximum allowable control rod insertion assuming the axial power imbalance is within the limits of the (delta I) function of the Overtemperature trip. When the axial power f) im balance is not within the tolerance, the axial power imbalance effect on the Overtemperature delta T trips will reduce the setpoints to provide protection consistent with core safety limits. 1 1 B 2-1 W-STS gg 7 g 7g7g
SAFETY LIMITS BASES 2.1.2 REACTOR COOLANT SYSTEM PRESSURE The restriction of this Safety Limit protects the integrity of the Reactor Coolant System from overpressurization and thereby prevents the release of radionuclides contained in the reactor coolant from reaching the containment atmosphere. The reactor pressure vessel and pressurizer are designed to Section III of the ASME Code for Nuclear Power Plant which permits a maximum transient pressure of 110% (2735 psig) of design pressure. ": U. . . :::!:.-t 0::: -- W ' ;, > ^ x x d t ;:, ;. _ f x t;nd t : "::: ; ;1.; :2t': , l ! : P p . . ... . w a .no , n-. 6.ans.enw ,. ... ..' ;2:~ CCC: ;;f;; ' ---- - d t'------~ The Safety Limit of 2735 psig is therefore consistent with the design criteria and associated code requirements. The entire Reactor Coolant System is hyorotested at 3107 psig,125% of design pressure, to demonstrate integrity prior to initial operation. 2.1.3 INSTRUMENTATION SETPOINTS The Reactor Trip and Engineered Safety Feature Actuation System Setooint l Limits specified in Table 2.2-1 are the nominal values at which the Reactor ! Trips are set for each functional unit. The Trip Setpoints have been se-l lected to ensure that the reactor core and reactor coolant system are pre-vented from exceeding their safety limits during normal operating and design I basis anticipated operational occurrences and to mitigate the consequences of accidents. The various reactor trip circuits automatically open the re-actor trip breakers whenever a condition monitored by the Reactor Protection System reaches a preset or calculated level. In addition to reduncant cnan-nels and trains, the design approach provides Reactor Protection and Engi-neered Safety Feature Actuation Systems which monitor numerous system vari-ables, therefore, providing protection system functional diversity. The Reactor Protection System initiates a turbine trip signal whenever reactor trip is initiated. This prevents the reactivity insertion that would otherwise result from excessive reactor system cooldown and thus avoids un-necessary actuation of the Engineered Safety Features Actuation System. Operation with a trip set less conservative than its Trip Setpoint but within its specified Allowable Value is acceptable on the basis that the difference between each Trip Setpoint and the Allowable Value is less than or equal to the "as measured" rack drift allowance assumed for each trip in the safety analyses. At the option of the plant staff either ".as measured" values of sensor drift or the value of S in Tables 2.2-1 and 2.2-2 may be used to satisfy the requirements of Equation 2.2-1.
-W-STS B 2-2 M R 1 5 1o79
DUKE POWER COMPANY Form 00134 (C Bli
!' Dev./ Station Unit File No.
; Subject By Date i
Il Sheet No. -of
' Problem No. Checked By Date ,
j ,
,i , , -
. I I I i 4 ; l ! ,
! i l I l 6 !
f l- ! i i [ l ! l l I l I I I il
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l i l ! 2.//! l I I i { l ! l I l
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- i j i i I l j l I i
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. ' l h , !
i ! ! I I ' The DNB design basis is as follows: there must be at least a 95 percent i ! } l l !I ! I
! ' probability that the minimum DNBR of the limiting rcd during Condition 1 and ,i II events is greater than or equal to the DNBR limit of the DNB correlation j
{b ' being used (the WRB-1 correlation in this application). The correlation ! j
' _ DNBR limit is established based on the entire applicaole experimental data i set such that there is a 95 percent probability with 95 percent confidence j j that DNB will not occur when the minimum DNBR is at the DNBR limit. t l
i . l \ !' i i In meeting this design basis, uncertainties in plant operating para- ! meters, nuclear and thermal parameters, and fuel fabrication parameters are l { !l - i _ consioered statistically such that there is at least a 95 conficence that i the minimum DNBR for the limiting rod is greater than or equal to the DNBR ' l l limit. The uncertainties in the above plant parametars are used to deter-I mine the plant DNBR uncertainty. This DNBR uncertainty, combined with the l i i - i! i
' correlation DNBR limit, establishes a design DNBR value which must be met ! I l j! in plant safety analyses using values of input parameters without uncertain- l ,; ties. l l 4 >
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2.2 LIMITING SAFETY SYSTEM SETTINGS BASES 2.2.1 REACTOR TRIP SYSTEM INSTRUMENTATION SETPOINTS The Reactor Trip Setpoint Limits specified in Table 2.2-1 are the nominal values at which the Reactor Trips are set for each functional unit. The Trip Setpoints have been selected to ensure that the reactor core and reactor coolant system are prevented from exceeding their safety limits during normal operation and design basis anticipated operational occurrences and to assist the Engineered Safety Features Actuation System in mitigating the consequences of accidents. The various reactor trip circuits automatically open the reactor trip breakers whenever a condition moniured by the Reactor Protection Systen reaches a preset or calculated level. In addition to redundant channels and trains, the design approach provides a Reactor Protection System which monitors
- numerous system variables, therefore, providing protection system functional diversity.
The Reactor Protection System initiates a turbine trip signal whenever reactor trip is initiated. This prevents the reactivity insertion that would otherwise result from excessive reactor system cooldown and thus avoids unnecessary actuation of the Engineered Safety Features Actuation System. Operation with a trip set less conservative than its Trip Setpoint but within its specified Allowable Value is acceptable on the basis that the difference between each Trip Setpoint and the Allowable Value is equal to or less than the drift allowance for all trips including those trips assumed in the safety analyses. Manual Reactor Trip The Reactor Protection System includes manual reactor trip capability. Power Range, Neutron Flux l In each of the Power Range Neutron Flux channels there are two independent ! bistables, each with its own trip setting used for a high and low range trip setting. The low setpoint trip provides protection during subcritical and low power operations to mitigate the consequences of a power excursion beginning from low power, and the high setpoint trip provides pro,tection during power operations to mitigate the consequences of a reactivity excursion from all power levels. l l P B 24 SEP i 51981 t
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1 LIMITING SAFETY SYSTEM SETTINGS 1 1 BASES Power Range, Neutron Flux (Continued) The low setpoint trip may be manually blocked above P-10 (a power level of approximately 10 percent of RATED THERMAL POWER) and is automatically reinstated beow the P-10 setpoint. Power Range, Neutron Flux, High Rates ", l The Power Range Positive Rate trip p:ovides protection against rapid flux increases which are characteristic of a rupture of a control rod drive housing. Specifically, this trip complements the Power Range Neutron Flux High and Low trips to ensure that the criteria are met for rod ejection from mid power. b kgn1wotvalu The Power Range Negative Rateftrip provides protection to ensure that the c.J,ukted em+eum DNBR is maintained above SE& for control rod drop accidents. At high power a single or multiple rod drop accident could cause local flux peaking which, when in conjunction with nuclear power being maintained equivalent I to turbine power by action of the automatic rod control system, could cause an unconservative local DNBR to exist. ' t " c r t ..;; " .;;t' - 'f a 't 21' p r:.;.t th'; . . - 21' n..A .. -
; . . ' .; 4 tri;;' ; *" :::t:r ':
l ..J J A u. w . . i Intermediate and Source Range, Nuclear Flux The Intermediate and Source Range, Nuclear Flux trips provide reactor core protection during reactor startup to mitigate the consequences of an uncontrolled rod cluster control assembly bank withdrawal from a subcritical condition. These trips provide redundant protection to the low setpoint trip of the Power Range, Neutron Flux chgnnels. The Source Range channels will initiate a reactor trip at about 10 5 counts per second unless manually blocked when P-6 becomes active. The Intermediate Range channels will initiate a reactor trip at a current level equivalent to approximately 25 percent of RATED THERMAL POWER unless manually blocked when P-10 becomes active. No credit was taken for operation of the trips associated with either the Intermediate or Source Range Channels in the accident analyses; however, their j functional capability at the specified trip settings is required by this specification to enhance the overall reliability of the Reactor Protection System. 1 1 l W-STS B 2-4 SEP 151081
l LIMITING SAFETY SYSTEM SETTINGS BASES Overtemperature AT The Overtemperature delta T trip provides core protection to prevent DNB for all combinations of pressure, power, coolant temperature, and axial power distribution, provided that the transient is slow with respect to piping transit delays from the core to the temperature detectors (about 4 seconds), and pressure is within the range between the Pressurizer high and low pressure trips. The setpoint is automatically varied with 1) coolant temperature to correct for temperature induced changes in density and heat capacity of water and includes dynamic compensation for piping delays from the core to the loop temperature detectors, 2) pressurizer pressure, and 3) axial power distribution. With normal axial power distribution, this reactor trip limit is always below the core safety limit as shown in Figure 2.1-1. If axial peaks are greater than design, as indicated by the difference between top and bottom power range nuclear detectors, the reactor trip is automatically reduced according to the notations in Table 2.2-1. ^ rn '"" "" "L"N: F:'" r :0 "-1 LO P ^^:Ta u d per
- h a reactor coolant loop out of service below the p P-8 setpoint does n ire reactor protection system set) ~
ification because the P-8 setpoint an iated trip will during (n-1) loop operation exclusive of the Ove
- ta T setpoint. (n-1) loop operation above the (n) loop P-8 1 issible after resetting the K1 input to the Overt e delta T channels a " sing the P-8 setpoint to its (n-1 a ue. In this mode of operation, the *nterlock and tri ons as a High Neutron Flux trip at the reduced power 1.
Overoower AT The Overpower delta T reactor trip provides assurance of fuel integrity, e.g., no fuel pe.11et cracking or melting, under all possible overpower conditions, limits the required range for Overtemperature delta T protection, and provides a backup to the High Neutron Flux trip. The setpoint is automatically varied with 1) coolant temperature to correct for temperature induced changes in density and heat capacity of water, (and) 2) rate of change of temperature for dynamic compensation for piping delays from the core to the loop temperature detectorsr(ZI ') * ' P~^- M di .. ..,) to ensure that the allowable heat generation rate (Kw/ft) is not exceeded. The overpower AT trip provides protection to mitigate the consequences of various size steam breaks as reported in WCAP 9226, " Reactor Core Response to Excessive Secondary Steam Break." pSTS B 2-5 SEP 151981
LIMITING SAFETY SYSTEM SETTINGS BASES Pressurizer Pressure In each of the pressure channels, there are two independent bistables, each with its own trip setting to provide for a high and low pressure trip thus limiting the pressure range in which reactor operation is permittec. The low setpoint trip protects against low pressure which could lead to DN8 by tripping the reactor in the event of a loss of reactor coolant pressure. On decreasing power the low setpoint' trip is automatically blocked by P-7 (a power level of approximately 10 percent of RATED THERMAL POWER with turbine impulse chamber pressure at app-oximately 10 percent of full power equivalent); and on increasing power, automatically reinstated by P-7. The high setpoint trip functions in conjunction with the pressurizer ralief and safety valves to protect the Reactor Coolant System against system overpressure. Pressurizer Water Level The pressurizer high water level trip is provided to prevent water relief through the pressurizer safety valves. On decreasing power the pressurizer high water level trip is automatically blocked by P-7 (a power level of approximately 10 percent of RATED THERMAL POWER with a turbine impulse chamber pressure at approximately 10 percent of full equivalent); and on increasing power, automatically reinstated by P-7. Loss of Flow The Loss of Flow trips provide core protection to prevent DNB by mitigating the consequences of a loss of flow resulting from the loss of one or more reactor coolant pumps. On increasing power above P-7 (a powerde el of approximately 10 percent ' of RATED THERMAL POWER or a turbine impul chamber pressure at approximately 10 percent of full power equivalent), an automatic reactor trip will occur if the flow in more than one loop drops belo (90%) of nominal full loop flow. Above P-8 (a power level of approximately percent of RATED THERMAL POWER) an automatic reactor trip will occur if the flow in any single loop drops below (90 percent) of nominal full loop flow. Conversely on decreasing power between P-8 and the P-7 an automatic reactor trip will occur on loss of flow in more than one loop and below P-7 the trip function is automatically blocked.
'f-STS B 2-6 SEP 151081
LIMITING SAFETY SYSTEM SETTINGS i BASES Loss of Flow (Continued) CP U CN".L r^^ "L." i: "E"" T :: N 1 LOGF 0; e TION trip will prevent the minimum value of the DNB The - . going below 1.30 during ' operational transients and + ed transients when (n-1) loops are in operatio the Overte delta T trip setpoint is adjusted to the value specified fo ps in operation. With the Overtemperature delta T t
- nt adjuste the value specified for (n-1) loop oper *
, e P-8 trip at (76%) RATED POWER will prevent the mi
- a ue of the DNBR from going below 1.30 during 1 operational 1ents and anticipated transients with (n-1) loops in operati -
Steam Generator Water Level The steam generator water level low-low trip protects the reactor from loss of heat sink in the event of a sustained steam /feedwater flow mismatch resulting from loss of normal feedwater. The specified setpoint provides allowances for starting delays of the auxiliary feedwater system.
" ~ % dwater Flow Mic==+rh =nd '~"c'--- t r. ; r n; . '. _ , - ,
e steam /feedwater flow mismatch in coincidence with a steam genera low wate 1 trip is not used in the transient and accident anal ut is included in Ta 2-1 to ensure the functional capability of + specified trip settings and the enhance the overall reliabilit he Reactor Protection System. This tr redundant to the Generator Water Level Low-Low trip. The Steam /Feedwat ow Mism portion of this trip is activated when the steam flow exceeds edwater flow by greater than or equal to (1.42 x 108) lbs/ hour, eam ator Low Water level portion l of the trip is activated whe water level dr elow (25) percent, as
- indicated by the narrow e instrument. These trip ues include sufficient allowance in exce= normal operating values to preclude rious trips but will initiat eactor trip before the steam generators are dr . Therefore, the re capacity and starting time requirements of the auxilia eedwater pum are reduced and the resulting thermal transient on the Reactor Coo tem and steam generators is minimized.
Undervoltage and Underfrequency - Reactor Coolant Pump Busses The Undervoltage and Underfrequency Reactor Coolant Pump Bus trips provide reactor core protection against DNB as a result of complete loss of forced coolant flow. The specified setpoints assure a reactor trip signal is generated before the low flow trip setpoint is reached. Time delays are incorporated in the underfrequency and undervoltage trips to prevent spurious reactor trips from momentary electrical power transients. For undervoltage, l I W-STS
- B 2-7 SEP 151981
I l LIMITING SAFETY SYSTEM SETTINGS l BASES l Undervoltage and Underfrequency - Reactor Coolant Puso Busses (Continued) the delay is set so that the time required for a signal to reach the reactor trip breakers following the simultaneous trip of two or more reactor coolant pump bus circuit breakers shall not exceed (1.2) seconds. For underfrequency, the delay is set so that the time required for a signal to reach the reactor trip breakers after the underfrequency trip setpoint is reached shall not exceed (0.3) seconds. On decreasing power the Undervoltage and Underfrequency Reactor Coolant Pump Bus trips are automatically blocked by P-7 (a power level of approximately 10 percent of RATED THERMAL POWER with a turbine impulse chamber pressure at approximately 10 percent of full power equivalent); and on increasing power, reinstated automatically by P-7. Turbine Trip A Turbine Trip initiates a reector trip. " . . _. eas i us gv.m we i.u ru . . .. . u .g is ou w mai..s.??3 L L m uy 77 ( yo -m im : . T ..,. . .,,-: c.,.L :, 1G p . m.c.t y? ".".Tg J.37eim. 70 .2 -. yu g &uru iu. ;
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u, ; h % h se n 4e:9- readse 4 rip 2.s aulamahaatl y 6k,elud be kw PA ( Paae, bya Aleafem mg m+ael.eE) and is aulwaliolly echsl#NJ deve. +be. ?-9 refpunt. 1 Safety Injection Inout from ESF l If a reactor trip has not already been generated by the reactor protective l instrumentation, the ESF automatic actuation logic channels will initiate a reactor trip upon any signal which initiates a safety injection. The ESF instrumentation channels which initiate a safety injection signal are shown in Table 3.3-3. I N t.7, .1 ' q ":::t:r T:" -+ " :. m . T m . . .. . T. . - e Reactor Coolant Pump Breaker Position Trips are anticipatory trips which p reactor core protection against DNB. The open/close position trips assure a r trip signal is generated before the low flow trip fsetpointisreached. dit was taken in the accident analyses f eration of these trips. Their func . capability at the open/close ion settings 1 i is required to enhance the overa liability of the Rea rotection l System. Above P-7 (a power level of ximately 1 cent of RATED THERMAL I oximately 10 percent of l POWER or a turbine impulse chamber pressur full power equivalent) an automatic r1 ill occur if more than one h reactor coolant pump breaker i imately b occur if one reac+ 30 percent of ,
.ERMAL ed. Above P-8 POWER) an automa!.ic ower level of approx-ctor trip will
)
% olant pump breaker is opened. On de sing power ;
between P-8 -7 an automatic reactor trip will occur if mor
- an one ;
reac o ant pump breaker is opened and below P-7 the trip funct is atically blocked. I ! PSTS B 2-8 SEP 151C81 l
DUKE POWER COMPANY Fcrm 001S4 (G 81) i l; Dev./ Station Unit File No. f Subject By Date I
. , Sheet No. _of Problem No. Checked By Date '
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, The engineered safety feature actuation system is designed to mitigate h I
; the consequences of accidents, primarily loss of coolant / pressure accidents ,
i ji and steam /feedline break accidents. As such those parameters which would ! tj j i be affected by these type accidents are chosen to provide actuating signals. l 4 l Steam pressure is used to initiate safety injection for steamline break type ; I accidents. Pressurizer pressure is used to initiate safety injection for ' l LOCA and steamline break accidents. Containment pressure can initiate safety l
'l injection for any break inside containment.
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i LIMITING SAFETY SYSTEM SETTINGS BASES g.j .s itsuroe.7bP/EMMELEO SWETYFO74M Acu47/M SfS7CA MTC^ttack.s
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. The Reactor Trip System Interlocks perform the following functions:
On increasing power P-6 allows the manual block of the Source Range
$4 }. ggl P-6reactor trip and de-energizing of the high voltage to the detectors.
l j J& On decreasing power, Source Range level trips are automatically 3J reactivated and high voltage restored. C~ ( On increasing power P-7 automatically enables reactor trips on low dgg { P-7 coolant flow in more than one primary coolant loop, more thn one reactor pump breaker open, reactor coolant pump bus undervoltage and _o3!g 45 underfrequency, turbine trip, pressurizer low pressure and 3g,e pressurizer high level. On decreasing power the above listed trips 4 g =_ are automatically blocked. 2 .bJ
$ C. P-8 On increasing power P-8 automatically enables reactor trips on low
_.t J,s.Q flow in one or more primary coolant loops, and one or more reactor e # coolant pump breakers open. On decreasing power the P-8 automat:cally V blocks the above listed trips. 32I.9)+g l E- On increasing power P-10 allows the manual block of the Intermediate f*e.kP-1*~ Range reactor trip and the flow setpoint Power Range reactor trip; and automatically blocks the Source Range reactor trip and de-energizes the Source Range high voltage power. On decreasing power the Inter-T mediate Range reactor trip and the low setpoint Power Range reactor F- trip are automatically reactivated. Provides input to P-7. P-13 Provides input to P-7. The Engineered Safety Feature Actuation System interlocks perform the following functions: P-4 Reactor tripped - Actuates turbine trip, closes main feedwater valves on T 3yg below setpoint, prevents the opening of the main feedwater l valves which were closed by a safety injection or high steam generator water level signal, allows safety injection block so that components can be reset or tripped. Reactor not tripped prevents manual block of safety injection. 1 P-11 On increasing pressure P-11 automatically reinstates safety injection actuation on low pressurizer pressure and low steamline pressure and automatically blocks steamline isolation on negative steamline pres-sure rate. On decreasing pressure P-11 allows the manual block of safety injection on low pressurizer pressure and low steamline pressure and allows steamline isolation on negative steamline pressure rate to j become active upon manually blocking steamline low pressure safety injection. SEP 151981 W-STS B 2-9
SECTIONS 3.0 AND 4.0 LIMITING CONDITIONS FOR OPERATION AND SURVEILLANCE REQUIREMENTS b
l l 'I 3/4 LIMITING CONDITIONS FOR OPERATION AND SURVEILLANCE REQUIREMENTS 3/4.0 APPLICABILITY
\
LIMITING CONDITION FOR OPERATION - 3.0.1 Compliance with the Limiting Conditions for Operation contained in the i succeeding Specifications is required during the OPERATIONAL MODES or other conditions specified therein; except that upon failure to meet the Limiting Conditions for Operation, the associated ACTION requirements shall be met. l 3.0.2 Noncompliance with a Specification shall exist when the requirements of the Limiting Condition for Operation and associated ACTION requirements are not met within the specified time intervals. If the Limiting Condition for Operation is restored prior to expiration of the specified time intervals, completion of the Action requirements is not required. 3.0.3 When a Limiting Condition for Operation is not met, except as provided in the associated ACTION requirements, within one hour action shall be initiated to place the unit in a MODE in which the Specification does not apply by placing it, as applicable, in:
- 1. At least HOT STANDBY within the next 6 hours,
- 2. At least HOT SHUTDOWN within the following 6 hours, and
- 3. At least COLD SHUTDOWN within the subsequent 24 hours.
Where corrective measures are completed that permit operation under the ACTION requirements, the ACTION may be taken in accordance with the specified time I limits as measured from the time of failure to meet the Limiting Condition for Operation. Exceptions to these requirements are stated in the individual Specifications. This Specification is not applicable in MODES 5 or 6. 3.0.4 Entry into an OPERATIONAL MODE or other specified condition shall not be made unless the conditions for the Limiting Condition for Operation are met without reliance on provisions contained in the ACTION requirements. This provision shall not prevent passage through or to OPERATIONAL MODES as required to comply with ACTION requirements. Exceptions to these requirements are stated in the individual Specifications.
-W-STS 3/4 0-1 JUL 2 71981 l
APPLICA8ILITY SURVEILLANCE REQUIREMENTS 4.0.1 Surveillance Requirements shall be met during the OPERATIONAL MODES or other conditions specified for individual Limiting Conditions for Operation unless otherwise stated in an individual Surveillance Requirement. I 4.0.2 Each Surveillance Requirement shall be performed within the specified time interval with:
- a. A maximum allowable extension not to exceed 25% of the surveillance interval, but i b. The combined time interval for any 3 consecutive surveillance intervals shall not exceed 3.25 times the specified surveillance interval.
4.0.3 Failure to perform a Surveillance Requirement within the specified time interval shall constitute a failure to meet the OPERABILITY requirements for a Limiting Condition for Operation. Exceptions to these requirements are stated in the individual Specifications. Surveillance Requirements do not have to be performed on inoperable equipment. 4.0.4 Entry into an OPERATIONAL MODE or other specified condition shall not be made unless the Surveillance Requirement (s) associated with the Limiting Condition for Operation have been performed within the stated surveillance interval or as otherwise specified. 4.0.5 Surveillance Requirements for inservice inspection and testing of ASME Code Class 1, 2, and 3 components shall be applicable as follows:
- a. Inservice inspection of ASME Code Class 1, 2, and 3 components and inservice testing of ASME Code Class 1, 2, and 3 pumps and valves shall be performed in accordance with Section XI of the ASME Boiler and Pressure Vessel Code and applicable Addenda as required by 10 CFR 50, Section 50.55a(g), except where specific written relief "
has been granted by the Commission pursuant to 10 CFR 50, Section 50.55a(g)(6)(i). . l W-STS 3/4 0-2 JUL 2 31980
i l l APPLICABILITY SURVEILLANCE RE0VIREMENTS (Continued) 4.0.5 (Continued)
- b. Surveillance intervals specified in Section XI of the ASME Boiler and Pressure Vessel Code and applicable Addenda for the inservice inspection and testing activities required by the ASME Boiler and Pressure Vessel Code and applicable Addenda shall be applicable as follows in these Technical Specifications:
ASME Boiler and Pressure Vessel Required frequencies for Code and applicable Addenda performing inservice terminology for inservice inspection and testing insoection and testing activities activities Weekly At least once per 7 days Monthly At least once per 31 days Quarterly or every 3 months At least once per 92 days Semiannually or every 6 months At le,ast once per 184 days Every 9 months At least once per 276 days Yearly or annually At least once per 366 days
- c. The provisions of Specification 4.0.2 are applicable to the above required frequencies for performing inservice inspection and testing activities.
- d. Performance of the above inservice inspection and testing activities shall be in addition to other specified Surveillance Requirements.
- e. Nothing in the ASME Boiler and Pressure Vessel Code shall be construed to supersede the requirements of any Technical Specification.
l i l l l W-STS 3/4 0-3 'NOV 2 61980
3/4.1 REACTIVITY CONTROL SYSTEMS 3/4.1.1 BORATION CONTROL SHUTDOWN MARGIN - T >200*F LIMITING CONDITION FOR OPERATION _
/. 3%
3.1.1.1 The SHUTDOWN MARGIN shall be greater than or equal to (-'.Z/ delta k/k for.JW/ loop operation. APPLICABI ITY: MODES \ 2 3, and 4. ACTION. j 13'4 ' With the SHUTDOWN MARGIN less than 'i.07 delta k/k, immediately initiate and continue boration at greater than or equal to 30 gpm of a solution containing greater than or equal to Vooo ppm baron or equivalent until the required SHUTDOWN MARGIN is restored. SURVEILLANCE REOUIREMENTS 4.1.1.1.1 The SHUTDOWN MARGIN shall be determined to be greater than or equal to ./e4v62rJ delta k/k: 132o A n one hour after detection of an inoperable control rod at lea er 12 hours thereafter while the r . noperable. If the inoperab 1 rod is immov rippable, the above required SHUTDOWN MARGIN 1fied acceptable with an increased allowance rawn worth of t e ntrippable o rod (s). A wnen in muuc ; .. " " 9 with Kg , greater +h= a" aa"=1 ta 'a '+ least once per " 5 . uy verifying ol bank withdrawal is whimits of Specification 3.1.3.6. A. Es When in MODE 2 with K,ff less than 1.0, within 4 hours prior to achieving reactor criticality by verifying that the predicted critical control rod position is within the limits of Specification 3.1.3.6. i h% Prior to initial operation above 5% RATED THERMAL POWER after each fuel loading, by consideration of the factors of below, with the l control banks at the maximum insertion limit of Specification 3.1.3.6. C
*See Special Test Exception 3.10.1.
# key leu iden 1. 0.
W-STS 3/4 1-1 NOV 2 01980
REACTIVITY CONTROL SYSTEMS SURVEILLANCE REQUIREMENTS (Continued) d /. When in MODES 3 or 4, at least once per 24 hours by consideration of the following factors:
- 1. Reactor coolant system boron concentration,
- 2. Control rod position,
- 3. Reactor coolant system average temperature,
- 4. Fuel burnup based on gross thermal energy generation,
- 5. Xenon concentration, and
- 6. Samarium concentration.
. 4.1.1.1.2 The overall core reactivity balance shall be compared to predicted values to demonstrate agreement within 1% delta k/k at least once per 31 Effective Full Power Days (EFPD). This comparison shall consider at least those factors stated in Specification (4.1.1.1.1. ), above. The predicted reactivity values shall be adjusted (normalized) to correspond to the actual core conditions prior to exceeding a fuel burnup of 60 Effective Full Power Days after each fuel loading. c.
l l l W-STS 3/4 1-2
REACTIVITY CONTROL SYSTEMS SHUTDOWN MARGIN - T,yg 5 200*F LIMITING CONDITION FOR OPERATION 3.1.1.2 The SHUTDOWN MARGIN shall be greater than or equal to 1.0% delta k/k. APPLICABILITY: MODE 5. ACTION: With the SHUTDOWN MARGIN less than 1.0% delta k/k, immediately initiate and continue boration at greater than or equal to JLD gpm of a solution containing greater than or equal to74pc ppm boron or equivalent until the required SHUTDOWN MARGIN is restored. SURVEILLANCE REOUIREMENTS 4.1.1.2 The SHUTDOWN MARGIN shall be determined to be greater than or equal to 1.0% delta k/k:
- a. Within one hour after detection of an inoperable control rod (s) and at least once per 12 hours thereafter while the rod (s) is inoperable.
If the inoperable control rod is immovable or untrippable, the SHUTDOWN MARGIN shall be verified acceptable with an increased allowance for the withdrawn worth of the immovable or untrippable control rod (s).
- b. At least once per 24 hours by consideration of the following factors:e i
- 1. Reactor coolant system boron concentration, l
- 2. Control rod position,
- 3. Reactor coolant system average temperature, l
- 4. Fuel burnup based on gross thermal energy generation,
- 5. Xenon concentration, and i
- 6. Samarium concentration.
i I W-STS 3/4 1-3 NOV 2 0 880
REACTIVITY CONTROL SYSTEMS MODERATOR TEMPERATURE COEFFICIENT LIMITING CONDITION FOR OPERATION 3.1.1.3 The moderator temperature coefficient (MTC) <!aall be:
- a. Less positive than (0) delta k/k/*F for the all rods withdrawn, beginning of cycle life (BOL), hot zero THERMAL POWER condition.
- 3. ?
- b. Less negative than -43c9P x 10 ~4 delta k/k/*F for the all rods withdrawn, end of cycle life (EOL), RATED THERMAL POWER condition.
APPLICABILITY: Specification 3.1.1.3.a - MODES 1 and 2* only#. Specification 3.1.1.3.b - MODES 1, 2, and 3 only#. ACTION:
- a. With the MTC more positive than the limit of 3.1.1.3.a above, opera-tion in MODES 1 and 2 may proceed provided:
- 1. Control rod withdrawal limits are established and maintained sufficient to restore the MTC to less positive than 0 delta k/k/*F within 24 hours or be in HOT STANDBY within the next 6 hours. These withdrawal limits shall be in addition to the insertion limits of Specification 3.1.3.6.
- 2. The control rods are maintained within the withdrawal limits established above until a subsequent calculation verifies that the MTC has been restored to within its limit for the all rods withdrawn condition.
- 3. In lieu of any other report required by Specification 6.9.1, a Special Report is prepared and submitted to the Commission l pursuant to Specification 6.9.2 within 10 days, describing the l value of the measured MTC, the interim control rod withdrawal limits, and the predicted average core burnup necessary for restoring the positive MTC to within its limit for the all rods withdrawn condition.
- b. With the MTC more negative than the limit of 3.1.1.3.b above, be in HOT SHUTOOWN within 12 hours.
1 1
*With K,ff greater than or equal to 1.0.
#See Special Test Exception 3.10.3.
W-STS 3/4 1-4 MAY 15 ic80
REACTIVITY CONTROL SYSTEMS SURVEILLANCE REQUIREMENTS 4.1.1.3 The MTC shall be determined to be within its limits during each fuel cycle as follows:
- a. The MTC shall be measured and compared to the BOL limit of Specifi-cation 3.1.1.3.a. above, prior to initial operation above 5% of RATED THERMAL POWER, after each fuel loading.
- b. The MTC shal f2. O x 10 } bedelta measured at rods k/k/*F (all any withdrawn, THERMALRATEDPOWER and compared THERMAL POWER to J* condition) within 7 EFPD after reaching an equilibrium boron concen-tration of 300 ppa. Intheevent_piscomparisonindicatestheMTC is more negative than delta k/k/*F, the MTC shall be remeasured,andcompared}Ox10 o the EOL MTC limit of specification 3.1.1.3.b, at least once per 14 EFPD during the remainder of the fuel cycle.
-20 l
l l { i W-STS 3/4 1-5 AUG 2 3 73 l
REACTIVITt CONTROL SYSTEMS MINIMUM TEMPERATURE FOR CRITICALITY LIMITING CONDITION FOR OPERATION 3.1.1.4 The Reactor Coolant System lowest operating loop temperature (T**9) shall be greater than or equal to 45497'F. APPLICABILITY: MODES 1 and 2 . ACTION: less than With a Reactor Coolantto System withinoperating its limit loop temperature within (T* N)be in HOT 15 minutes S.51 45'D"F, STANDBY restore T*Mxt 15 minutes. within the SURVEILLANCE REQUIREMENTS 4.1.1.4 The Reactor Coolant System temperature (T""9) shall be determined to be greater than or equal to.6544t*F: SCI
- a. Within 15 minutes prior to achieving reactor criticality, and
- b. At least once per 30 minutes when the reactor is critical and the Reactor Coolant System T is less than 45stf'F with the Tavg-Tref DeviationAlarmnotreseU9 56/
t
#With K greater than or equal to 1.0. *
*SeeSpINalTestException3.10.3.
t NOV 151979 W-STS 3/4 1-6
l REACTIVITY CONTROL SYSTEMS 3/4.1.2 B0 RATION SYSTEMS FLOW PATH - SHUTDOWN LIMITING CONDITION FOR OPERATION 3.1.2.1 As a minir,um, one of the following boron injection flow paths shall be OPERABLE and capable of being powered from an OPERABLE emergency power source. c
- a. A flow path from 4he boric acid tankt via either a boric acid transfer pump ^ r - r"ity feed cr-- rtie and a charging pump to the Reactor Coolant System if the boric acid storage tank in Specification (3.1.2.5a) is OPERABLE, or
- b. The flow path from the refueling water storage tank via a charging pump to the Reactor Coolant System if the refueling water storage tank in Specification (3.1.2.5b) is OPERABLE.
APPLICABILITY: MODES 5 and 6. ACTION: With none of the above flow paths OPERABLE or capable of being powered from an ! OPERABLE emergency power source, suspend all operations involving CORE l ALTERATIONS or positive reactivity changes. SURVEILLANCE REQUIREMENTS i 4.1.2.1 At least one of tne above required flow paths shall be demonstrated OPERABLE: i
- a. At least once per 7 days by verifying that the temperature of the kedal N portion of the flow path is greater than or equal to (65)*F when a flow path from the boric acid tanks is used.
- b. At least once per 31 days by verifying that each valve (manual, power operated, or automatic) in the flow path that is not locked, sealed, or otherwise secured in position, is in its correct position.
W-STS 3/4 1-7 JUL 2 71961
i REACTIVITY CONTROL SYSTEMS FLOW PATHS - OPERATING LIMITING CONDITION FOR OPERATION 3.1. 2. 2 At least two of the following three boron injection flow paths shall be OPERA 8LE:
- a. The flow path from the boric acid tanks via a boric acid transfer 1 pump and a charging pump to the Reactor Coolant System.
- b. Two flow paths from the refueling water storage tank via charging pumps to the Reactor Coolant System. -
APPLICABILI : MODES 1, 2, 3, and 4#. ACTION: With only one of the above required boron injection flow paths to the Reactor Coolant System OPERABLE, restore at least two boron injection flow paths to the Reactor Coolant System to OPERABLE status within 72 hours or be in at least HOT STANDBY and borated to a SHUTDOWN MARGIN equivalent to at least 1% delta k/k at 200*F within the next 6 hours; restore at least two flow paths to OPERABLE status within the next 7 days or be in COLD SHUTDOWN within the next 30 hours. SURVEILLANCE REQUIREMENTS 4.1.2.2 At least two of the above required flow paths shall be demonstrated OPERABLE:
- a. At least once per 7 days by verifying that the temperature of the hedel ht tr:;;d portion of the flow path from the boric acid tanks is greater than or equal to (65)*F when it is a required water source.
- b. At least once per 31 days by verifying that each valve (manual, power operated, or automatic) in the flow path that is not locked, sealed, or otherwise secured in position, is in its correct position.
- c. At least once per 18 months during shutdown by verifying that each automatic valve in the flow path actuates to its correct position on h j @s _ a ] test signal.
igk8" d. At least once per 18 months by verifying that the flow path required by Specification 3.1.2.2.a delivers at least M gpm to the Reactor Coolant System. 0nly one boron injection flow path is required to be OPERA 8LE whenever the temperature of one or more of the RCS cold legs is less than or equal to ti A IC F. 300 E-STS 3/4 1-8 gy , t g
\
REACTIVITY CONTROL SYSTEMS CHARGING PUMP - SHUTDOWN , l LIMITING CONDITION FOR OPERATION 3.1.2.3 One charging pump in the boron injection flow path required by Specification (3.1.2.1) shall be OPERABLE and capable of being powered from an OPERABLE emergency power source. APPLICABILITY: MODES 5 and 6. ACTION: With no charging pump OPERABLE or capable of being powered from an OPERABLE emergency power source, suspend all operations involving CORE ALTERATIONS or positive s%.ks. reactivity changes 3 unt;[ ,ne ch.ging pump r, resb/ b cPcMst.s SURVEILLANCE RE0VIREMENTS ona. guar 4rdt ksk
- 4.1.2.3.1 The above required charging pump shall be demonstrated OPERABLE by
^- -- # ' " ' d verifying, ' - - the pump develops a discharge pressure of greater than or equal to 2400 psig. *. r tect;d purru rt t: Ce d t ' e r.
N 3t kW 4.1.2.3.2 Allchargingpumps,excludingtheabovehequiredOPERABLEpump, y shall be demonstrated inoperable at least once per .2 h: r:, except when the reactor vessel head is removed, by verifying that the motor circuit breakers c e l .! - 5:= b::r c;... .md T.v., U .m . . m M .-::;; p;;;r appi, ..w:;.3, orb 1 v er'&^ Ot lisebsegd c(ca'N b5 hf.Ch irolafed, dem de Meacfe r deo and Iyf " l lf % .; ta.a no us Iah.n taas unk L p.wa,. emnet L m vala sc-yt ope-w1 t* l W-STS 3/4 1-9 JUL 2 71981
REACTIVITY CONTROL SYSTEMS CHARGING PUMPS - OPERATING LIMITING CONDITION FOR OPERATION 3.1.2.4 At least two charging pumps shall be OPERABLE. APPLICABILITY: MODES 1, 2, 3 and 4# . ACTION: With only one charging pump OPERABLE, restore at least two charging pumps to OPERABLE status within 72 hours or be in at least HOT STANDBY and barated to a SHUTDOWN MARGIN equivalent to at least 1% delta k/k at 200*F within the next 6 hours; restore at least two charging pumps to OPERABLE status within the next 7 days or be in COLD SHUTOOWN within the next 30 hours. SURVEILLANCE REOUIREMENTS m . paderly hans 4.1.2.4.1 At least two charging pumps shall be demonstrated OPERABLEgby verifying c ._ ... each pump develops a discharge pressure of greater than or equal to 2400 psig."her t;;ted p r;;;r.t t: Sp::i'ie:tLs N M Aays 300 4.1.2.4.2 All charging pumps, except the e required OPERA E pump, shall be demonstrated inoperable at least once per .2 h;ur; whenever the temperature I of one or more of the RCS cold legs is less than or equal to ~
, F by verifying
! that the motor circuit breakers br/c b;;.. c;;;.ed 'r;;- thei cl::tri 21 p c'. c r
- ;;1y :" Lit: oc by verifying 4bd jf,, ducharge of eacA ka3 b**'che ing"I'"fJb NO W ^ i O
- h % m % t a c.l v Ccn l cre mus)in he agen Vut," ito %. VaVes u1Ik %< fowes- fram "e VulV<. mob
- g e re. .
A maximum of are centrifugal charging pump shall be OPERABLE whenever the l temperature of one or more of the RCS cold legs is less than or equal to l L3FsY'F. i 3oc i l l W-STS 3/4 1-10 MAY l 5 7978 l
REACTIVITY CONTROL SYSTEMS BORATED WATER SOURCE - SHUTDOWN LIMITING CONDITION FOR OPERATION 3.1.2.5 As a minimum, one of the following borated water sources shall be OPERABLE:
- a. A boric acid storage system and at least one associated heat tracing system with:
- 1. A minimum contained borated water volume of Sloo gallons, oco ??co
- 2. Between (2},0007 andM ppm of boron, and to5
- 3. A minimum solution temperature of JWJ)*F.
- b. The refueling water storage tank with:
- 1. A minimum contained borated water volume of N 080 gallons,
- 2. A minimum boron concentration of (2000) ppm, and
- 3. A minimum solution temperature of F.
APPLICABILITY: MODES 5 and 6. ACTION: ' With no borated water source OPERABLE, suspend all operations involving CORE ALTERATIONS or positive reactivity changes. I SURVEILLANCE REQUIREMENTS 4.1.2.5 The above required borated water source shall be demonstrated OPERABLE:
- a. At least once per 7 days by:
- 1. Verifying the boron concentration of the water,
- 2. Verifying the contained borated water volume, and
- 3. Verifying the boric acid storage tank solution temperature when it is the source of borated water.
F
- b. At least once per 24 hours by verifying the (WST temperature when it is the source of borated water and the (outside) air temperature is less than (35)*F.
W-STS 3/4 1-11 'NOV 2 01980 l
REACTIVITY CONTROL SYSTEMS BORATED WATER SOURCES - OPERATING LIMITING CONDITION FOR OPERATION 3.1.2.6 As a minimum, the following borated water source (s) shall be OPERABLE as required by Specification 3.1.2.2:
- a. A boric acid storage system and at least one associated heat tracing l system with:
- 1. A minimum contained borated water volume ofITJ88 gallons, 7 ace Moo
- 2. Between (2,00G and (22,0007 ppe of boron, and 65
- 3. A minimum solution temperature of frWrj*F.
- b. The refueling water storage tank with:
tust yester han oe egul le 90 Mf 'r U'A . , j,.
- 1. A contained borated waterg;:Tu ; ,,T :,eL--.. a.d ;
p ??:=^
- 2. Between (2000) and (2100) ppa of boron, and 70
- 3. A minimum solution temperature of 4357 F.
APPLICABILITY: MODES 1, 2, 3 and 4. ACTION:
- a. With the boric acid storage system inoperable and being used as one of the above required borated water sources, restore the storage system to OPERABLE status within 72 hours or be in at least HOT STANOBY within the next 6 hours and borated to a SHUTDOWN MARGIN equivalent to at least 1% delta k/k at 200*F; restore the boric acid storage system to OPERABLE status within the next 7 days or be in COLD SHUTDOWN within the next 30 hours.
- b. With the refueling water storage tank inoperable, restore the tank to OPERABLE status within one hour or be in at least HOT STANDBY within the next 6 hours and in COLD SHUTDOWN within the following 30 hours.
l l l PSTS 3/4 1-12
.N04 2 01980
REACTIVITY CONTROL SYSTEMS , 1 SURVEILLANCE REQUIREMENTS l l 4.1.2.6 Each borated water source shall be demonstrated OPERABLE:
- a. At least once per 7 days by:
- 1. Verifying the boron concentration in the water,
- 2. Verifying the contained borated water volume of the water source, and ,
- 3. Verifying the boric acid storage system solution temperature when it is the source of borated water.
F
- b. At least once per 24 hours by verifying the AWST temperature when the (outside) air temperature is less than (35)*F.
/
i l l W-STS 3/4 1-13 NOV 2 0 G80
F REACTIVITY CONTROL SYSTEMS 3/4.1.3 MOVABLE CONTROL ASSEMBLIES GROUP HEIGHT LIMITING CONDITION FOR OPERATION 3.1.3.1
^
All f. ' '.. ... (..... ._.. _c._ :_ ^- ') rods,,- J . ' ;1:1 ': ,^2. .: :
..__._:2 '
-, shall be OPERA 8LE and positioned within 12 steps (indicated position) of their group step counter demand position.
APPLICABILITY: MODES 1* and 2". ACTION:
- a. With one or more f. ' :....... rods inoperable due to being immovable as a result of excessive friction or mechanical interference or known to be untrippable, determine that the SHUTDOWN MARGIN require-
! ment of Specification 3.1.1.1 is satisfied within 1 hour and be in l HOT STAN08Y within 6 hours.
- b. With more than one f; ' .. ro. . ... ... rod inoperable or misaligned from the group step counter demand position by more than t 12 steps (indicated position), be in HOT STAND 8Y within 6 hours.
- c. With one 4, : o. ,_ . 1;-,'..'. rod trippable but inoperable due to causes other than addressed by ACTION a, above, or misaligned from its group step counter demand height by more than 12 steps (indicated position), POWER OPERATION may continue provided that within one hour either:
- 1. The rod is restored to OPERABLE status within the above alignment requirements, or
- 2. The rod is declared inoperable and the remainder of the rods in the group with the inoperable rod are aligned to within t 12 steps of the inoperable rod while maintaining the rod sequence and insertion limits of Figuref (3.1-1) :: '-?L The THERMAL POWER level shall be restricted pursuant to Specification (3.1.3.6) during subsequent operation, or
- 3. The rod is declared inoperable and the SHUTDOWN MARGIN requirement of Specification 3.1.1.1 is satisfied. POWER OPERATION may then continue provided that:
a) A reevaluation of each accident analysis of Table 3.1-1 is performed within 5 days; this reevaluation shall confirm that the previously analyzed results of these accidents remain valid for the duration of operation under these conditions. b) The SHUTDOWN MARGIN requirement of Specification 3.1.1.1 is determined at least once per 12 hours.
"See Special Test Exceptions 3.10.2 and 3.10.3.
W-STS 3/4 1-14 'NOV 2 1981 1 I
REACTIVITY CONTROL SYSTEMS ACTION (Continued) c) Apowerdistributionmapisobtagnedfromthemovable incore detectors and F (Z) and F a within their limits wikhin 72 ho$s.re verified to be d) The THERMAL POWER level is reduced to less than or equal to 75% of RATED THERMAL POWER within the next hour and within the following 4 hours the high neutron flux trip setpoint is reduced to less than or equal to 85% of RATED THERMAL POWER. SURVEILLANCE REQUIREMENTS 4.1.3.1.1 The position of each t' - " 7-7 ';. 7' rod shall be determined to be within the group demand limit by verifying the individual rod positions at least once per 12 hours except during time intervals when the Rod Position Deviation Monitor is inoperable, then verify the group positions at least once per 4 hours. 4.1.3.1.2 Each f ' _ C' rod not fully inserted :-f -- ' ;;.' ...,_..
--d N in the core shall be determined to be OPERABLE by movement of at least 10 steps in any one direction at least once per 31 days.
3/4 1-15 40V 2 8 PSTS
TABLE 3.1-1 ACCIDENT ANALYSES REQUIRING REEVALUATION IN THE EVENT OF AN INOPERA8LE 44mre45## MiNeEn Roo Rod Cluster Control Assembly Insertion Characteristics Rod Cluster Control Assembly Misalignment Loss Of Reactor Coolant From Small Ruptured Pipes Or From Cracks In Large Pipes Which Actuates The Emergency Core Cooling System Single Rod Cluster Control Assembly Withdrawal At Full Power Major Reactor Coolant System Pipe Ruptures (Loss Of Coolant Accident) Major Secondary System Pipe Rupture Rupture of a Control Rod Drive Mechanism Housing (Rod Cluster Control Assembly Ejection) W-STS 3/4 1-16 OCT 1 1976
REACTIVITY CONTROL SYSTEMS POSITION INDICATION SYSTEMS-OPERATING LIMITING CONDITION FOR OPERATION 3.1.3.2 The i tf: .- ;:-t. .: ...J p.-t ' ; :x tn' rod position indication system and the demand, position indication system shall be OPERABLE and capable of determining the eeMoo+ rod positions within 12 steps. APPLICABILITY: MODES 1 and 2. ACTION:
- a. With a maximum of one rod position indicator per bank inoperable either:
- 1. Determine the position of the non-indicating rod (s) indirectly by the movable incore detectors at least once per 8 hours and immediately after any motion of the non-indicating rod which exceeds 24 steps in one direction since the last detemination cf the rod's position, or
- 2. Reduce THERMAL POWER yo less than 50% of RATED Tl!ERMAL POWER within 8 hours.
- b. With a maximum of one demand position indicator per bank inoperable either:
- 1. Verify that all rod position indicators for the affected bank are OPERABLE and that the most withdrawn rod and the least withdrawn rod of the bank are within a maximura of 12 steps of each other at least once per 8 hours, or
- 2. Reduca THERMAL POWER to less than 50% of RATED THERMAL POWER within 8 hours.
SURVEILLANCE REOUIREMENTS 4.1.3.2 Each rod position indicator shall be determined to be OPERABLE by verifying that the demand position indication system and the rod position indication system agree within 12 steps at least once per 12 hours except during time intervals when the Rod Position Deviation Monitor is inoperable, then compare the demand position indication system and the rod position indica-tion system at least once per 4 hours. W-STS 3/4 1-17 JUL 151979
REACTIVITY CONTROL SYSTEMS POSITION INDICATION SYSTEM-SHUT 00WN LIMITING CONDITION FOR OPERATION 3.1.3.3 One rod position indicator (excluding demand position indication) shall be OPERABLE and capable of determining the W rod position within 12 steps for each ' . ---'- ' -. ; " '
- f. rod not fully inserted.
APPLICABILITY: MODES 3*#, 4*# and 5*#. ACTION: With less than the above required position indicator (s) OPERABLE, immediately open the reactor trip system breakers. SURVEILLANCE REOUIREMENTS 4.1.3.3 Each of the above required rod position indicator (s) shall be determined to be OPERABLE by performance of : ::. .. .~v n a n ;.,o m TEST at least once per 18 months. A gg gggggg I
"With the reactor trip system breakers in the closed position.
i #See Special Test Exception 3.10.5. 1 l W-STS 3/4 1-18 NOV 2 01980
REACTIVITY CONTROL SYSTEMS ROD DROP TIME LIMITING CONDITION FOR OPERATION l 3.3 3.1. 3. 4 The individual fr ';.. ... ';:. 12: ... ;; . .tr:' ' thefullywithdrawnpositionshallbelessthanorequalto(roddroptimefrom 44"ET' seconds from beginning of decay of stationary gripper coil voltage to dashpot entry with: sSI
- a. T,yg greater than or equal to 43441*F, and
- b. All reactor coolant pumps operating.
APPLICABILITY: MODES 1 and 2. ACTION:
- e. With the drop time of any ' ': ;t' rod determined to exceed the above limit, restore the rod drop time to within the above limit prior to proceeding to MODE 1 or 2.
. 'tn the rod drop tires within limits but determined w' . i reactor coo s operating, operation may proceed ed THERMAL POWER is res to:
- 1. Less than or equal to
- RATED THERMAL POWER when the reactor coolant + valves in u operating loop are open, of
- 2. than or equal to (76)% of RATED THERMAL POW n the reactor coolant stop valves in the nonoperating loop a osed.
SURVEILLANCE REOUIREMENTS 4.1.3.4 The rod drop time ^# ' '... .. -d-shall be demonstrated through measurement prior to reactor criticality:
- a. For all rods following each removal of the reactor vessel head,
- b. For specifically affected individual rods following any maintenance on or modification to the guedumph rod drive system which could affect the drop time of those specific rods, and
- c. At least once per 18 months.
~W-STS 3/4 1-19 OCT 1 ggyg
.. . _ _ ~ . __ _ _ . _ . . . _.
REACTIVITY CONTROL SYSTEMS SHUT 00WN R00 INSERTION LIMIT LIMITING CONDITION FOR OPERATION 3.1.3.5 All shutdown rods shall be fully withdrawn. APPLICABILITY: MODES la and 2*#. ACTION: With a maximum of'one shutdown rod not fully withdrawn, except for surveillance
- testing pursuant to Specification (4.1.3.1.2), within 1 hour either:
- a. Fully withdraw the rod, or
- b. Declare the rod to be inoperable and apply Specification (3.1.3.1).
SURVEILLANCE REQUIREMENTS 4.1.3.5 Fach shutdown rod shall be determined to be fully withdrawn:
- a. Within 15 minutes prior to withdrawal of any rods in control banks A, B, C or D during an approach to reactor criticality, and
- b. At least once per 12 hours thereafter.
"See Special Test Exceptions 3.10.2 and 3.10.3. #With K,ff greater than or equal to 1.0.
W-STS 3/4 1-20 iNOV 2 01980
l REACTIVITY CONTROL SYSTEMS MNK CONTROLa#9D INSERTION LIMITS LIMITING CONDITION FOR OPEPATION 3.1.3.6 The control banks shall be limited in physical insertion as shown in Figuret (3.1-1).... ' 3. ', 2 h ! APPLICABILITY: MODES 1* and 2*.d. ACTION: With the control banks inserted beyond the above insertion limits, except for surveillance testing pursuant to Specification (4.1.3.1.2), either:
- a. Restore the control banks to within the limits within 2 hours, or
- b. Reduce THERMAL POWER within 2 hours to less than or equal to that fraction of RATED THERMAL POWER which is allowed by the m position using the above figures, or O
! c. Be in at least HOT STANDBY within 6 hours. SURVEILLANCE REQUIREMENTS l 4.1.3.6 The position of each control bank shall be determined to be within the insertion limits at least once per 12 hours except during time intervals when the Rod Insertion Limit Monitor is inoperable, then verify the individual rod positions at least once per 4 hours. l .
*See Special Test Exceptions 3.10.2 and 3.10.3.
With K,ff greater than or equal to 1.0. W-STS 3/4 1-21 NOV 2 01Sc0
, , , _ , , , - , , - - . - + - - .w.--,--~e - ~ '
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- c. THIS FIG E FOR ILL TlON ONLY W 'l DO N Ts USE FOR ERATION .
g ~ [ o
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0 I/ I I i ! ! I i I \ i 0.0 0.2 0.4 0.6 0.8 (FULL INSERTED) FRACTION OF RATED THERMAL POWER FIGURE 3.1-1 RO GROUP INSERTION LIMITS VERSUS THERMAL POWER THREE LOOP OPERATION 3-575 3/4 1-22 007 1 1973
(Fully withdrawn) 4 228 _. _ r.._.t.r . _.. ,e e < __........_f. _ . . . _ , _ - f. . . . ___...i_..
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_ _ _ . . 4_ f 1 _ .. 4 .+ Z _. 4_ , f - _: ---a O _ . . _ . , . - __ _._. , f . n - * - --~-
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1 1 t_ 1__ _."._. , y) _. __.+. > j ' ' f- ) I I M 1 F 1 a r 1 1 - g, 1
._. 4 f .
X - Y . . u,; i
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._. f -- f y . . . __ -
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= ; [ THIS FIGURE FOR ILLUSTRATION ONLY W"-
--- M- -
- - - + - * - ~
# DO NOT USE FOR OPERATION r i)
._...,M_
i M - I.
+ .-
y 100 ,
, - ,f , ,
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f a - 50 - -
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._ 1 . .
_ - -.- - _._ . .. m.
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f, ._.. _ _
,. m . ._. ._ _ . _ . ._ _ _ .. ,
- r. _ ...._t._.=._. ..
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l Q 0.0 0.2 0.4 0.6 0.8 1.0 l (Fully inserted) l FRACTION OF RATED THERMAL POWER Figure 3.1- ROD GROUP INSERTION LIMITS VERSUS THERMAL POWER FOUR LOOP OPERATION , E-STS 3/4 1-23 007 1 tgyg 1 1 l l l
TIVITY CONTROL SYSTEMS PART H R00 INSERTION LIMITS (OPTIONAL) l LIMITING CO ITION FOR OPERATION s , 3.1. 3. 7 The par length control rod bank shall be:
- a. Limited i hysical insertion as shown on Figur (3.1-3), and
- b. Limited from cove ng any axial segment of the fu assemblies for a period in excess of 18) out of any 30 Equivale Full Power Days.
APPLICABILITY: MODES 1* an 2*. ACTION:
- a. With the part length co rol rod b k inserted beyond the insertion limit of Figure (3.1-3), ither:
- 1. Withdraw the part lengt ontrol rod bank to within the limit within 2 hours, or
- 2. Reduce THERMAL POWER ithin hours to less than or equal to that fraction of R ED THERMA POWER which is allowed by the bank position usi the above gure, or
- 3. Be in at least T STAND 8Y within hours.
- b. With the neutron bsorber section of the art length control rod bank covering a axial segment of the fue assemblies for a period exceeding 18 o of any 30 consecutive EFPD eriod, either:
- 1. Reposi on the part length control rod gr p to satisfy the above imit within 2 hours, or
- 2. Be n at least HOT STANDBY within the next 6 urs.
SURVEILLANCE R UIREMENTS
, 1 4.1.3.7 Th position of the part length control rod bank shall be o termined at least ce per"12 hours.
"See ecial Test Exceptions 3.10.2 and 3.10.3.
l l l W-STS 3/4 1-24 .NOV 2 01980 1
AC11VITY CONTROL SYSTEMS PART L GTH ROD INSERTION LIMITS (if required by DNB considerations) LIMITING C0 ITION FOR OPERATION
~ 1 3.1.3.7 All part ngth rods shall be fully withdrawn.
APPLICABILITY: MODES
- and 2*.
ACTION: With a maximum of one part 1 gth rod not ful withdrawn, within 1 hour either:
- a. Fully withdraw the rod, r
- b. Be in at least HOT STANDBY ithin the next 6 hours.
SURVEILLANCE REQUIREMENTS 4.1.3.7 Each part 1 gth rod shall be determined t be fully withdrawn by:
- a. Verifyi the position of the part length to rior to increasing THER PGWER above 5% of RATED THERMAL POWER, nd
- b. Ve fying, at least once per 31 days, that electr power has been sconnected from its drive mechanism by physical r oval of a l reaker from the circuit.
ee Special Test Exceptions 3.10.2. and 3.10 3. W-STS 3/4 1-25 NOV 2 01980
PART LENGT OD UP INSERTION LIMIT VERS ERFAL POWER F RE 3. -3 W-STS 3/4 1-26
g, t $$ See cort average acemidad buenap $ f= Soto MUDfftTYL . 7
- 6. +3 % -12.% for car
- average acWd'd W *b h WMM.
3/4.2 POWER DISTRIBUTION LIMITS 3/4.2.1 AXIAL FLUX DIFFERENCE LIMITING CONDITION FOR OPERATION 3.2.1 The indicated AXIAL FLUX DIFFERENCE (AFD) shall be maintained withinAm mal!l.a"d 4409% target band (flux difference units) about the target flux difference;
==>
APPLICABILITY: MODE 1 above 50% of RATED THERMAL POWER *. ACTION:
- a. With the indicated AXIAL FLUX DIFFERENCEabsr outside of theA*(4@
target band about the target flux difference and with THERMAL POWER:
- 1. Above 90% of RATED THERMAL POWER, within 15 minutes either:
a) Restore the indicated AFD to within the target band limits, or b) Reduce THERMAL POWER to less than 90% of RATED THERMAL POWER.
- 2. Between 50% and 90% of RATED THERMAL POWER:
a) POWER OPERATION may continue provided: Me equired
- 1) The indicated AFD has not been outside of thej 6 target band for more than 1 hour penalty deviation cumulative during the previous 24 hours, and
- 2) The indicated AFD is within the limits shown on Figure (3.2-1). Otherwise, reduce THERMAL POWER to less than 50% of RATED THERMAL POWER within 30 minutes and reduce the Power Range Neutron Flux-High Trip Setpoints to less than or equal to 55% of RATED THERMAL POWER within the next 4 hours.
b) Surveillance testing of the Power Range Neutron Flux Channels may be performed pursuant to Specification (4.3.1.1) provided tt.a indicated AFD is maintained within the limits of Figure 3.2-1. A total of 16 hours operation may be accumulated with the AFD outside of the target band during this testing without penalty deviation.
- b. THERMAL POWER shall not be increased above 90% of RATED THERMAL POWER unless the indicated AFD is within the e@996 target band and ACTION a.2.a) 1), above has been satisfied. d,g regu;c,2 "See Special Test Exception 3.10.2.
1 W-STS 3/4 2-1 NOV 2 01930 l 1 - - - -
r
\
POWER DISTRIBUTION LIMITS ACTTON (Continued)
- c. THERMAL POWER shall not be increased above 50% of RATED THERMAL POWER unless the indicated AFD has not been outside of the 46spobe repM target band for more than 1 hour penalty deviation cumulative during the previous 24 hours.
Power increases above 50% of RATED THERMAL POWER do not require being within the target band provided the accumulative penalty deviation is not violated. SURVEILLANCE REOUIREMENTS 4.2.1.1 The indicated AXIAL FLUX DIFFERENCE shall be determined to be within its limits during POWER OPERATION above 15% of RATED THERMAL POWER by:
- a. Monitoring the indicated AFD for each OPERABLE excore channel:
l 1. At least once per 7 days when the AFD Monitor Alarm is OPERA 8LE, and
- 2. At least once per hour for the first 24 hours after restoring l
1 the AFD Monitor Alarm to OPERABLE status. j b. Monitoring and logging the indicated AXIAL FLUX DIFFERENCE for each OPERABLE excore channel at least once per hour for the first 24 hours and at least once per 30 minutes thereafter, when the AXIAL FLUX DIFFERENCE Monitor Alarm is inoperable. The logged values of the indicated AXIAL FLUX DIFFERENCE shall be assumed to exist during the interval preceding each logging. al los+ hf f er 2.d3 O e d eve re 4.2.1.2 The indicated AFD shall be considered outside g of it; C"'target gned l band when 6 em-mose OPERABLE excore channels are indicating the AFD to be I outside the target band. Penalty deviation outside of the e4615 target band shall be accumulated on a time basis of: M rep / reef
- a. One minute penalty deviation for each 1 minute of POWER OPERATION outside of the target band at THERMAL POWER levels equal to or above 50% of RATED THERMAL POWER, and
- b. One-half minute penalty deviation for each 1 minute of POWER OPERATION outside of the target band at THERMAL POWER levels between 15% and 50% of RATED THERMAL POWER.
4.2.1.3 The target flux difference of each CPERABLE excore channel shall be i determined by measurement at least once per 92 Effective Full Power Days. wee m . ,. ; : 4 .'. ::..t: C :f: ( it:. . m The provisions of Specification 4.0.4 are not applicable. 4.2.1.4 The target flux difference shall be updated at least once per 31 Effective Full Power Days by either determining the target flux difference pursuant to 4.2.1.3 above or by linear interpolation between the most recently measured value and 0 percent at the end of the cycle life. The provisions of Specification 4.0.4 are not applicable. W-STS 3/4 2-2 NOV 101980
1 l l l l l 1 l i I Esc
- ua
- 3 O!!2
. #EE.J 4::
c JE:c g:555. 0 100 UNACCEPTABLEB(-11,90) (11.,90)5 UNACCEPTABLE OPERATION ,. ... OP,ERATION ,
/
80 / \
/
/ \
g f5EhCCEPTABLE-iOPERhTION"; I ( 31,50) _ _ (31,50) 40 THIS FIGURE FOR ILLUSTRATION ONLY l DO NOT USE FOR OPERATION 20 l 1 0 50 -40 -30 -20 -10 0 10 20 30 40 50 FLUX DIFFERENCE (Al) % FIGURE 3.2-1 AXIAL FLUX DIFFERENCE LIMITS AS A FUNCTION OF RATED THERM AL POWER M-STS 3/4 2-3 JUL 1 5 7979
POWER DISTRIBUTION LIMITS 3/4.2.2 HEATFLUXHOTCHANNELFACTOR-Fg LIMITING CONDITION FOR OPERATION 3.2.2 Fq (Z) shall be limited by the following relationships: FA (Z) 5 [2.32] [K(Z)] for P > 0.5 P
, Fq (Z) 5 [(4.64)] [K(Z)] for P 5 0.5 '
where P = THERMAL POWER RATED THERMAL POWER and K(Z) is the function obtained from Figure (3.2-2) for a given core height location. APPLICABILITY: MODE 1 ACTION: l With Fq (Z) exceeding its limit:
- a. ^-';' ' i + " -i' *^- ' ": ':' : ' ; " 0T:: 'T : . .
l
\ Reduce THERMAL POWER at least 1% for each 1% F (Z) exceeds the limitwithin15minutesandsimiliarlyreducekhePowerRange Neutron Flux-High Trip Setpoints within the next 4 hours; POWER OPERATION may proceed for up to a total of 72 hours; subsequent POWER OPERATION may proceed provided the Overpower delta T Trip Setpoints have been reduced at least 1% for each 1% F (Z) exceeds the limit. . : C...,~--. i L ' ' '; :';^i0+ ~_l-,.~
. . _ . _ . . . - p m . . .,mu - . . . . _ . - _ _ _ _ _ . : ?. ;t ::T STnnuoA n;;m 'ucouai onuco ,, no,..u2,., +- r++' ,
, , , , ; :g -4 _
Tm..... P O nsina the APOMS wi+" : ':' :* # ~~ 0 :; "d t; _ =u 2. Wuro p . 4n u v...,,-
- b. Identify and correct the cause of the out of limit condition prior i
' to increasing THERMAL POWER above the reduced limit required by a, above; THERMAL POWER may then be increased provided F (Z) is demon-strated through incore mapping to be within its limitq l l W-STS 3/4 2-A SEP 151979
POWER DISTRIBUTION LIMITS SURVEILLANCE REOUIREMENTS 4.2.2.1 The provisions of Specification 4.0.4 are not applicable. 4.2.2.2 F xy shall be evaluated to determine if Fq (Z) is within its limit by:
- a. Using the movable incore detectors to obtain a power distribution map at any THERMAL POWER greater than 5% of RATED THERMAL POWER.
. b. Increasing the measured F component of the power distribution map by 3% to account for manuNcturing tolerances and further increasing the value by 5% to account for measurement uncertainties.
- c. Comparing the F xy computed (F ) obtained in b, above to:
- 1. The F limits for RATED THERMAL POWER (FRTP) for the appropriate xy measured core planes given in e and f below, and
- 2. The relationship: g F
x
=F xRTP[1+0./(1-P)]
l where F*Y is the limit for fractional THERMAL POWER operation RTP xy and P is the fraction of RATED expressed as a function of F THERMAL POWER at which F was measured.
- d. Remeasuring F according to the following schedule:
TP
- 1. When F isgreaterthantheFfy limit for the appropriate measured core plane but less than the F*Y relationship, additional RTP power distribution maps shall be taken and F xyC compared to F xy and F :
a) Either within 24 hours after exceeding by 20% of RATED THERMAL POWER or greater, the THERMAL POWER at which F was last determined, or l l b) At least once per 31 EFPD, whichever occurs first. I l ' W-STS 3/4 2-5 MAY 151976
I 1 POWER DISTRIBUTION LIMITS SURVEILLANCE REQUIREMENTS (Continued) C RTP xy is less than or equal to the Fxy
- 2. When the F limit for the appropriate measured core plane, additional power distribution maps shall be taken and F RTP x compared to F x and F l at least xy once per 31 EFPD.
- e. The F xy limits for RATED THERMAL POWERx(FRTP) shall be provided for all core planes containing bank "0" control rods and all unrodded core planes in a Radial Peaking Factor Limit Report per Specifica-tion 6.9.1.M.
14
- f. The F limits of e, above, are not applicable in the following core planeIYregions as measured in percent of core height from the bottom of the fuel:
- 1. Lower core region from 0 to 15%, inclusive.
- 2. Upper core region from 85 to 100%, inclusive.
- 3. Grid plane regions at 17.8 2%, 32.1 2%, 46.4 2%, 60.6 2%
and 74.9 2%, inclusive (17 x 17 fuel elements).
- 4. Core plane regions within 2% of core height ( 2.88 inches) about the bank demand position of the bank "0" : ;-* ': ;;th control rods.
l
- g. With Fx exceeding Fxy p t 'i I (Z; -it .. :1 h r: t: - ou .ou. ~ iv , eacii ii. r m ecus F xy' """ "' F " ~ " ?I' I QE ) '22; Ih" ' " ' ' "
.., ?,T Z )-
A The effects of F xy on Fq (Z) shall be evaluated to determine if Fq (Z) is within its limits. 4.2.2.3 When F (Z) is measured for other than F determinations, an overall measuredF(Z)hhallbeobtainedfromapowerdilEributionmapandincreased by3%toa9countformanufacturingtolerancesandfurtherincreasedby5%to account for measurement uncertainty. W-STS 3/4 2-6 NOV2 tes;
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= (z)% aliznVWBON -(z)>l W-STS 3/4 2-7 MAY 151975
POWER DISTRIBUTION LIMITS 3/4.2.3 RCS FLOW RATE AND NUCLEAR ENTHALY RISE HOT CHANNEL FACTOR LIMITING CONDITION FOR OPERATION 3.2.3 The combination of indicated Reactor Coolant System (RCS) total flow rate and R R shall be maintained within the region of allowable operation shownonFlg,ur$3.2-3for4loopoperation. Where: a. R) = 1.49 [1.0 + 0.3 (1.0 - P)] ' R) b. R2 * [1-R8P(80)] '
, THERMAL POWER ,
p , RATED THERMAL POWER N
- d. F =MeasuredvaluesofFhobtainedbyusingthemovableincore detectors to obtain a power distribution map. The measured N
values of F shall be used to calculate R since Figure 3.2-3 includes measurement uncertainties of 3.5% for flow and 4% for N incore measurement of F , and
- e. RBP (BU) = Rod Bow Penalty as a function of region average burnup as shown in Figure 3.2-4, where a region is defined as those assemblies with the same loading date (reloads) or enrichment (first core).
APPLICABILITY: MODE 1. ACTION: With the combination of RCS total flow rate and R), R 2 utside the region of acceptable operation shown on Figure 3.2-3:
- a. Within 2 hours either:
- 1. Restore the combination of RCS total flow rate and R),
R to within the above limits, or 2
- 2. Reduce THERMAL POWER to less than 50% of RATED THERMAL POWER and reduce the Power Range Neutron Flux - High trip setpoint to less than or equal to 55% of RATED THERMAL POWER within the next 4 hours.
W-STS 3/4 2-8 NOV 2 01980
POWER DISTRIBUTION LIMITS ACTION: (Continued)
- b. Within 24 hours of initially being outside the above limits, verify through incore flux mapping and RCS total flow rate comparison that the combination of R 3
, R and RCS total flow rate are restored to within the above limits,2or reduce THERMAL POWER to less than 5% of RATED THERMAL POWER within the next 2 hours.
- c. Identify and correct the cause of the out-of-limit condition prior to increasing THERMAL POWER above the reduced THERMAL POWER limit required by ACTION items a.2. and/or b. above; subsequent POWER OPERATION may proceed provided that the combination of R3 , R, and indicated RCS total flow rate are demonstrated, through incore flux mapping and RCS total flow rate comparison, to be within the region of acceptable operation shown on Figure 3.2-3 prior to exceeding the following THERMAL POWER levels:
- 1. A nominal 50% of RATED THERMAL POWER,
- 2. A nominal 75% of RATED THERMAL POWER, and
- 3. Within 24 hours of attaining greater than or equal to 95% of RATED THERMAL POWER.
SURVEILLANCE REOUIRE'MENTS 4.2.3.1 The provisions of Specification 4.0.4 are not applicable. 4.2.3.2 The combination of indicated RCS total flow rate and R 3
, R, shall be determined to be within the region of acceptable operation of Figurt 3.2-3:
l a. Prior to operation above 75% of RATED THERMAL POWER after each fuel l loading, and
- b. At least once per 31 Effective Full Pcwer Days.
4.2.3.3 The indicated RCS total flow rate shall be verified to be within the region of acceptable operation of Figure 3.2-3 at least once per 12 hours when the most recently obtained values of R y and R2
, btained per Specification 4.2.3.2, are assumed to exist.
4.2.3.4 The RCS total flow rate indicators shall be subjected to a CHANNEL CALIBRATION at least once per 18 months. 4.2.3.5 The RCS total flow rate shall be determined by measurement at least once per 18 months. 1 4-STS -3/4-2-5 JUL 151979
l l l l l l l
. ]: j' l ; li T 1; : - ' .il l .i l
! MEASUREMENT T- I' r i UNCERTAINTIES -' 4-- - -u ,- . .1--
i
.i
' I ;
OF 3.5% FOR FLOW .1. l
- j iAND 4% FOR INCOREi. i j ,
46 9 MEASUREMENT OF i~*j~~ ~~
'T -
'FN ARE INCLUDED
! 3H ACCEPTABLE j r IN THIS FIGURE. i OPERATION '- J REGION FOR i R: ONLY 44 5 i. j IHIS FIGURE FOR ILLUSTRATION ONLY g DO NOT USE FOR OPERATION C b
- ACCEPTABLE .
EG ON R ER e R, AND R: ; [ REGION g -_.7 O l N t
- ! (1.038, 39.8)
< 40 F-l C ti 4-- ' -
U i x l l 38 - ' - t + f i l - i (1., 38.3) l ' 36 - t 34 I I I l 0.90 0.95 1.00 1.05 1.10 1.15 R, = F3 y/1.49 [1.0 + 0.If1.0 - p)] R = Ril[1 - RBP(BU)) FIGURE 3.2-3 RCS TOTAL FLOWRATE VERSUS R - FOUR LOOPS IN OPERATION W-STS 3/4 2-10 NOV 151979
. -- _-~ .-. _ - .
N E OR ERA N l HIHlfEl'IX lillii ll .I [I nlWHH$ lll!IllEllliiIWilllllIIlllikpiElH Wllllllllh h OIIHlilIpInn
% ~03 liniql In unannilia ma Hu H
8 Wil IW llWIlill llWiIllilllillHlHilillllll s a ll!"ll' IllWIWW IWillIfil
,,L Wi!W !!a acalli ll l l lu!lnaanna!niWOli!a!!II!!
ilWill!H lll'WWWill!!OlWWW OlllWWilIlli h !!Ianinn lll
!Wll liWIWil!O!IlWIW W lE HilO! lill WWlillWilEll
! Hill!IWlille !Ill! Will!lWWilW I!W I lHHlllllllWWI WliH llllllllll1Hll!llllll!I 1lIll!Wil!IlllO IWll lil!W lWlIlO 0 ! - - 8 REGION AVERAGE SURNUP, MWD /MTU x 10-8 FIGURE 3.24 ROD BOW PENALTY VERSUS REGION AVERAGE BURNUP i
I I POWER DISTRIBUTION LIMITS 3/4.2.4 QUADRANT POWER TILT RATIO LIMITING CONDITION FOR OPERATION
~
3.2.4 The QUADRANT POWER TILT RATIO shall not exceed 1.02. APPLICABILITY: MODE 1 above 50% of RATED THERMAL POWER *. ACTION:
- a. With the QUADRANT POWER TILT RATIO determined to exceed 1.02 but .
less than or equal to 1.09:
- 1. Calculate the QUARANT POWER TILT RATIO at least once per hour until either:
a) The QUADRANT POWER TILT RATIO is reduced to within its limit, or b) THERMAL POWER is reduced to less than 50% of RATED THERMAL POWER.
- 2. Within 2 hours either:
a) Reduce the QUADRANT POWER TILT RATIO to within its I limit, or b) Reduce THERMAL POWER at least 3% from RATED THERMAL POWER for each 1% of indicated QUADRANT POWER TILT RATIO in excess of I G g and similarly reduce the Power Range Neutron Flux-High Trip Setpoints within the next 4 hours. i
- 3. Verify that the QUADRANT POWER TILT RATIO is within its limit within 24 hours after exceeding the limit or reduce THERMAL POWER to less than 50% of RATED THERMAL POWER within the next 2 hours and reduce the Power Range Neutron Flux-High Trip setpoints to less than or equal to 55% of RATED THERMAL POWER within the next 4 hours.
- 4. Identify and correct the cause of the out of limit condition prior to increasing THERMAL POWER; subsequent POWER OPERATION above 50% of RATED THERMAL power may proceed provided that the QUADRANT POWER TILT RATIO is verified within its limit at least once per hour for 12 hours or until verified acceptable at 95%
or greater RATED THERMAL POWER.
"See Special Test Exception 3.10.2.
W-STS 3/4 2-12 NOV 2 01080
i PCWER DISTRIBUTION LIMITS l ACTION: (Continued) i l
- b. With the QUADRANT POWER TILT RATIO determined to exceed 1.09 due to misalignment of eneher a _..____. ,:- ^ :' -. ;;. ' ': ;th rod:
- 1. Calculate the QUADRANT POWER TILT RATIO at least once per hour until either:
a) The QUADRANT POWER TILT RATIO is reduced to within its limit, or b) THERMAL POWER is reduced to less than 50% of RATED THERMAL POWER.
- 2. Reduce THERMAL POWER at least 3% from RATED THERMAL POWER for each 1% of indicated QUADRANT POWER TILT RATIO in excess of 1.0, within 30 minutes.
- 3. Verify that the QUADRANT POWER TILT RATIO is within its limit within 2 hours after exceeding the limit or reduce THERMAL POWER to less than 50% of RATED THERMAL POWER within the next 2 hours and reduce the Power Range Neutron Flux-High trip Setpoints to less than or equal to 55% of RATED THERMAL POWER within the next 4 hours.
- 4. Identify and correct the cause of the out of limit condition prior to increasing THERMAL POWER; subseouent POWER OPERATION above 50% of RATED THERMAL POWER may proceed provided that the QUADRANT POWER TILT RATIO is verified within its limit at least once per hour for 12 hours or until verified acceptable at 95%
or greater RATED THERMAL POWER. l
- c. With the QUADRANT POWER TILT RATIO determined to exceed 1.09 due to causes other than the misalignment of eeMeer a L _.. n ' -
;;. ; 1..,5s rod:
- 1. Calculate the QUADRANT POWER TILT RATIO at least once per hour until either:
a) The QUADRANT POWER TILT RATIO is reduced to within its limit, or b) THERMAL POWER is reduced to less than 50% of RATED THERMAL POWER. W-STS 3/4 2-13 'Nov 2 0 '980
POWER DISTRIBUTION LIMITS ACTION: (Continued)
- 2. Reduce THERMAL POWER to less than 50% of RATED THERMAL POWER l within 2 hours and reduce the Power Range Neutron Flux-High l
Trip Setpoints to less than or equal to 55% of RATED THERMAL POWER within the next 4 hours.
- 3. Identify and correct the cause of the out of limit condition prior to increasing THERMAL POWER; subsequent POWER OPERATION above 50% of RATED THERMAL POWER may proceed provided that the QUADRANT POWER TILT RATIO is verified within its limit at least once per hour for 12 hours or until verified at 95% or greater RATED THERMAL POWER.
- d. The provisions of Specification 3.0.4 are not applicable.
SURVEILLANCE REQUIREMENTS I 4.2.4.1 The QUADRANT POWER TILT RATIO shall be determined to be within the - limit above 50% of RATED THERMAL POWER by: l l
- a. Calculating the ratio at least once per 7 days when the alarm is OPERABLE.
- b. Calculating the ratio at least once per 12 hours during steady state operation when the alarm is inoperable.
4.2.4.2 The QUADRANT POWER TILT RATIO shSil be determined to be within the i limit when above 75 percent of RATED THERMAL POWER with one Power Range Channel inoperable by using the movable incore detectors to confirm that the normalized symmetric power distribution, obtained from the 4 pairs of symmetric thimble locations, is consistent with the indicated QUADRANT POWER TILT RATIO at least I once per 2 hours. or a b core. kg g 1 l l W-STS 3/4 2-14 SEP 101980 l l l
POWER DISTRIBUTION LIMITS 3/4.2.5 DN8 PARAMETERS 1 LIMITING CONDITION FOR OPERATION 3.2.5 The following DN8 related parameters shall be maintained within the limits shown on Table 3.2-1: a. Reactor Coolant System T,yg.
- b. Pressurizer Pressure.
APPLICABILITY: MODE 1. ACTION: With any of the above parameters exceeding its limit, restore the parameter to within its limit within 2 hours or reduce THERMAL POWER to less than 5% of RATED THERMAL POWER within the next 4 hours. SURVEILLANCE REQUIREMENTS 4.2.5 Each of the parameters of Table 3.2-1 shall be verified to be within their limits at least once per 12 hours. l i l l l l l l l l l W-STS 3/4 2-15 NOV 2 01980
TABLE 3.2-1 oc E DNB PARAMETERS Dj LIMITS il N- . oops In Op a- N-1 to s In era-N* Loops In tio Loop S op tion & . cop top PARAMETER Operation Va es 0 n Valve osed S9S' Reactor Coolant System T 1 LS&t7 F 5 (56 F 1( F avg Pressurizer Pressure > (2'7 ; ,~;o' > 220) ia* > (2220) sia i z.tosesigt R
+
7 e i l l h
==
**
- Limit not applicable during either a TilERMAL POWER ramp in excess of (5%) of RATED TilERMAL POWER per minute or a TilERMAL POWER step in excess of (10)% of RATED TilERMAL POWER.
N u, l l
1 3/4.3 INSTRUMENTATION I l 3/4.3.1 REACTOR TRIP SYSTEM INSTRUMENTATION I LIMITING CONDITION FOR OPERATION l 3.3.1 As a minimum, the reactor trip system instrumentation channels end int;rle -. of Table 3.3-1 shall be OPERABLE with RESPONSE TIMES as shown in Table 3.3-2. APPLICABILITY: As shown in Table 3.3-1. ACTION: As shown in Table 3.3-1. SURVEILLANCE REQUIREMENTS 4.3.1.1 Each reactor trip system instrumentation channel ;nd ir.t;rl;;k and the automatic trip logic shall be demonstrated OPERABLE by the performance of the reactor trip system instrumentation surveillance requirements specified in Table 4.3-1. 4.3.1.2 The REACTOR TRIP SYSTEM RESPONSE TIME of each reactor trip function shall be demonstrated to be within its limit at least once per 18 months. Each test shall include at least one train such that both trains are tested at least once per 36 months and one channel per function such that all channels are tested at least once every N times 18 months where N is the total number of redundant channels in a specific reactor trip function as shown in the
" Total No. of Channels" column of Table 3.3-1.
l l W-STS
- 3/4 3-1 SEP 15 G61
TABLE 3.3-1
'T y REACTOR TRIP SYSTEM INSTRUMENTATION MINIMUM TOTAL NO. CHANNELS CHANNELS APPLICABLE FUNCTIONAL UNIT OF CHANNELS TO TRIP OPERABLE MODES ACTION
- 1. Manual Reactor Trip 2 1 2 1 2 1 2 1 2 ,
3f4*T5*4 A W 7
- 2. Power Range, Neutron Flux - High 4 2 3 1, 2 2 Setpoint ggy y Low 4 2 3 1 ,2 2 Setpoint
- 3. Power Range, Neutron Flux 4 2 3 1, 2 2 High Positive Rate R 4. Power Range, Neutron Flux, 4 2 3 1, 2 .
2 w High Negative Rate lad 'a E 5. Intermediate Range, Neutron Flux 2 1 2 , 2 w4 3
- 6. Source Range, Neutron Flux gy A. Startup 2 1 2 2 4 B. Shutdown 2 1 2 3*, 4*, 5* W 9 C. Shutdown 2 0 1 3, 4, and 5 5
- 7. Overtemperature AT A. Four Loop Plant y Four Loop Operation e 4 2 3 1, 2 6 T' r:: L;;; "p;.mti;;- 4 W -.3 ar 2.- +
2 n- - i nnn n;;,,;
$ lhT:0 Levi. Ope,oli^2 M b 4 %
j he Luvy Opo, oi. un 3- W 2- % 4
l i TABLE 3.3-1(Continuedl y REACTOR TRIP SYSTEM INSTRUMENTATION l MINIMUM TOTAL NO. CilANNELS CilANNELS APPLICABLE FUNCTIONAL UNIT OF CilANNELS TO TRIP OPERABLE MODES ACTION
- 8. Overpower AT .
A. Four Loop Plant y Four Loop Operation 4 2 3 1, 2 6 I;. cc tuup Gy . o i. l .. + 48* . 3' M "
. iiii ce Lee,, P l . i. -
!;.. m a L . . ,, 0 ,. c ; t h r. - 4- G-. -t-- -? , 2 /
l L. uuup 6pei ".h . 4- 7 -e- % (
- 9. Pressurizer Pressure-Low y A. Four Loop Plant 4 2 3 1 t'
s
. Tiii . Lc,e,. "h..t 4-- G- -4 4 [6
'i' 10. Pressurizer Pressure--liigh g A. Four Loop Plant 4 2 3 1, 2 L iin uc L.e,. 71... - + -2 4 1, 2 [6
- 11. Pressurizer Water Level--High 3 2 2 1 7 l
- 12. Loss of Flow g A. Single Loop (Above P-8) 3/ loop 2/ loop in 2/ loop in 1 7 any oper- each oper-ating loop ating loop B. Two Loops (Above P-7 and 3/ loop 2/ loop in 2/ loop 1 7 below P-8) two oper- each oper-ating loops ating loop tJ1
( s'
- Iq TABLE 3.3-1 (Continued)
; "4 REACTOR TRIP SYSTEM INSTRUMENTATION m
1 HINIMUM i TOTAL NO. CilANNELS CHANNELS APPLICABLE j FUNCTIONAL UNIT OF CHANNELS z TO TRIP OPERABLE MODES ACTION w c Ila r s i 13. Steam Generator Water -3/" = can -2/:ts. ;,= f/sta. e i;;. . 1, 2 %y 6 j Level--Low-Low e// lug in any oper- each oper-j ating A ating 64ah gest- toof gem lNf. i M Et::-- c^ _r:L r !?_1.. 0;;..f.d ..t !?it;.1 / mm.ui o u,r le tm. 0 a lev co' - tm. ge stm. ge . 1 el an M [ f ui.;tc. T L., "i:::ich 2 sta ed- ciden ith 2 m/g d-flow is ch 1 stm. ed- flo mi match in ach sim. flow ism ch in s stm.
- n. in ame stm. gen. o 2 stm.
E
# n. gen. 1 and 1 st 'fe -
T
- flo misma h in ame ste 9 .
3 J Y. Undervoltage-Reactor Coolant Pumps A. Four Loop Plant y n 4-1/ bus 2 3 1 6, S. r _ ter; Dia-t F ' !!"/r -e - + - A" is Jff. Underfrequency-Reactor Coolant Pumps = A. Four Loop Plant 4-1/ bus 2 . 3 1 6 ,,
- u. . m um . . , , . . . . + ' /i n: 'P -2 4 7 m
Q lb M. Turbine Trip
- A. im; r!d i e!' "r n ure .& 4 2 f3 1 7,
- c. B. 4 d i an <tep-t'c h : C6:=e 4 4 4 1 7#
is.
l 4 i TABLE 3.3-1 (Continued) (( REACTOR IRIP SYSTEM INSTRllMENTATION MINIMUM
, TOTAL NO. CllANNELS CilANNELS APPLICABLE FUNCTIONAL UNIl 0F CHANNELS TO TRIP OPERABLE MODES ACTION i
\'t Jer. Safety Injection Input from ESF 2 1 2 1, 2 JHP 9 Reactor Coolant Pump Br j o Trip
' A. Abo r 1 break B ove P-7 and beTow t-e. i r ;g i er 11 pe o r-i ing 1 p Reactor Trip System Interloc , R' Intermediate Range ; '
- Neutron Flux, P-6 pg s
l 1 < 2 i ; Yo' B. Low wer R or Trips , P-7 P-10 Input 4 2 l 1 or i 3 Input 2 1 . 'l f C. Power Range Neutron Flux, P-8 4 2 2 I
, i 1
w Of
TABLE 3.3-1 (Continued) [-4 REACTOR TRIP SYSTEM INSTRUMENTATION HINIMUM TOTAL NO. CilANNELS CilANNELS APPLICABLE FUNCTIONAL UNIT OF CilANNELS TO TRIP OPERABLE MODES ACTION
. Low Setpoint Power Neutro x, P-10 -+ -t- +;-e- -1r E. T e Impu amber ressure, P-13 -r- -t- -e- +- t IB)f. Reactor Trip Breakers 2 1 2 1 2 1 &
2 1 2 3 A, 4*, 5* 1 9 892 (. Automatic Trip Logic 2 1 2 1, 2 1 8
, 2 1 2 3*, 4*, 5* 1 9 3
Y, a X; . o w l E
TABLE 3.3-1 (Continued) TABLE NOTATION
=
With the reactor trip system breakers in the closed position, the control rod drive system capable of rod withdrawal.
"Th; ;t:--1(a ma ::td Htk +k furr+4: ; d; +;;d '- +'t
- erv m. F.;;:tr- "::12 t L;[e ~r+--+
.m;; 4..u. f._;;d *- +h- +=4aa-d The provisions of Specification 3.0.4 are not applicable.
Below the P-6 (Intermediate Range Neutron Flux Interlock) setpoint. Below the P-10 (Low Setpoint Power Range Neutron Flux Interlock) Setpoint. ACTION STATEMENTS ACTION 1 - With the number of OPERABLE channels one less than the Minimum Channels OPERABLE requirement, restore the inoperable channel to OPERABLE status within 48 hours or be in HOT STANDBY within the next 6 hours. ACTION 2 - With the number of OPERABLE channels one less than the Total Number of Channels, STARTUP and/or POWER OPERATION may proceed provided the following conditions are satisfied:
- a. The inoperable channel is placed in the tripped condition within 1 hour.
- b. The Minimum Channels OPERABLE requirement is met; however, the inoperable channel may be bypassed for up to 2 hours for surveillance testing of other channels per Specification 4.3.1.1. .
- c. Either, THERMAL POWER is restricted to less than or equal to 75% of RATED THERMAL POWER and the Power Range Neutron Flux trip setpoint is reduced to less than or equal to (85)% of RATED THERMAL POWER within 4 hours; or, the QUADRANT POWER TILT RATIO is monitored at least once per 12 hours per Specification 4.2.4.2.
W-STS 3/4 3-7 SEP 151o81
TABLE 3.3-1 (Continued) ACTION STATEMENTS (Continued) ACTION 3 - With the number of channels OPERABLE one less than the Minimum Channels OPERABLE requirement and with the THERMAL POWER level:
- a. Below the P-6 (Intermediate Range Neutron Flux Interlock) setpoint, restore the inoperable channel to OPERABLE status prior to increasing THERMAL POWER above the P-6 Setpoint.
- b. Above the P-6 (Intermediate Range Neutron Flux Interlock) setpoint but below 10 percent of RATED THERMAL POWER, restore the inoperable channel to OPERABLE status prior to increasing THERMAL POWER above 10 percent of RATED THERMAL POWER.
ACTION 4 - With the number of OPERABLE channels one less than the Minimum Channels OPERABLE requirement suspend all operations involving positive reactivity changes. ACTION 5 - With the number of OPERABLE channels one less than the Minimum Channels OPERABLE requirement, verify compliance with the SHUTDOWN MARGIN requirements of Specification 3.1.1.1 or 3.1.1.2, as applicable, within 1 hour and at least once per 12 hours thereafter. ACTION 6 - With the number of OPERABLE channels one less than the Total Number of Channels, STARTUP ad/or POWER OPERATION may proceed provided the following conditions are satisfied:
- a. The inoperable channel is placed in the tripped condition within 1 hour.
I
- b. The Minimum Channels OPERABLE requirement is met; however, the inoperable channel may be bypassed for up to 2 hours for surveillance testing of other channels per Specification 4.3.1.1.
l ACTION 7 - With the number of OPERABLE channels one less than the Total Number of Channels, STARTUP and/or POWER OPERATION may proceed until performance of the next required OPERATIONAL TEST provided the inoperable channel is placed in the tripped condition within 1 hour. I ACT:^h ^ W . :.m : ;; thr t% u4a4-"= Nnmhar of c"- ;: e n.; ACE , w i eo M - c ~ Lee, wo es . ..o u m y m~ m . .o e n o a th: :::::f..su peanas,,a.
~
ani.w ow . a evi winuww(sj c4 3d c ens ' - t : 4 ^ b 4e 4" i t; i squ a r cu a t L
<r tL c a my gione wou....., cc :;r ? c ~ 4*4"+#:- 2. ^ . : . -
l l W-STS 3/4 3-8 SEP 151981
TABLE 3.3-1 (Continued) ACTION STATEMENTS (Continued) 4th a channel associated with an operating loop inooevahla_ reso o etable channel to " . within 2 hours or be in at leas ' i in the next 6 hours. One l channe ed with an oper may be bypassed for
. 2 hours for surveillance testing per '
on 4.3.1.1.
'+
he number of OPERABLE Channels one less than th Channe s s . ent, resto e channel to OPERABLE status withi duce THERMAL POWER to below the P-8 ange Neutron Flux setpoint wit ext 2 hours. Operation below the P-8 may
. ntinue pursuant to ACTION 11.
'+
number of OPERABLE Channels one les Channels . o y continue provided the ino e is placed in w . n I hour. l 8 l ACTION JC - With the number of OPERABLE channels one less than the Minimum Channels OPERABLE requirement, be in at least HOT STANDBY l within 6 hours; however, one channel may be bypassed for up to l 2 hours for surveillance testing per Specification 4.3.1.1, provided the other channel is OPERABLE. 9 ACTION 36 - With the number of 0FERABLE channels one less than the Minimum Channels OPERABLE requirement, restore the inoperable channel to OPEARABLE status within 48 hours or open the reactor trip breakers within the next hour. W-STS
- 3/4 3-9 SEP 151961
TABLE 3.3-2
'T "I
a REACTOR TRIP SYSTEM INSTRUMENTATION RESPONSE TIMES i FUNCTIONAL UNIT RESPONSE TINE
- 1. Manual Reactor Trip Not Applicable
- 2. Power Range, Neutron Flux 5 (0.5) seconds *
- 3. Power Range, Heutron Flux, liigh Positive Rate Not Applicable
- 4. Power Range, Neutron Flux, liigh Negative Rate 5 (0.5) seconds *
- 5. Intermediate Range, Neutron Flux Not Applicable R 6. SctM Range, Neutron Flux Not Applicable
+
- 7. Overtemperature AT $ (4.0) seconds
- 4
- 8. Overpower AT ": _ ^7 7 u u -- i(,.D se<onM
- 9. Pressurizer Pressure--Low $ (2.0) seconds
- 10. Pressurizer Pressure--liigh 5 (2.0) seconds
- 11. Pressurizer Water Level--lii0h Not Applicable u>
- m Neutron detectors are exempt from response time testing. Response time of the neutron flux signal portion of the channel shall be measured from detector output or input of first electronic component in channel.
[ 'l'h pr -;i: c'_ 2;p!!_'u ^ *^ Cn': i:!n' d st ar .lammarv 1. 1978. <- " ;;' L. , u <'- ! .113,
.~ . u ,w e .
g .
...m E .
TABLE 3.3-2 (Continued) Il, REACTOR TRIP SYSTEM INSTRUMENTATION RESPONSE TIMES u - FUNCTIONAL UNIT RESPONSE TIME
- 12. Loss of Flow A. Single Loop (Above P-8) < (1.0) seconds B. Two Loops (Above P-7 and below P-8) 3(1.0) seconds l
- 13. Steam Generator Water Level--Low-Low < (2.0) seconds 1^. St ; ^m..m.;i 7 U;t :
l Levei L., C:fr.:!d;nt _ith- l Simse/TesJ_.tcr r!rr "8---tch ": t '77 ' i " ? 2. l W Jd'. Undervoltage-Reactor Coolant Pumps < (1.5) seconds s
#' '5 }&. Underfrequency-Reactor Coolant Pumps < (0.6) seconds T '
LI l6;HP. Turbine Trip A. L;. "!;!d 0!! " :::gr;- Not Applicable B. T u r i i n ; S t e,. '.' 1 . ;- Not Applicable
\7 387 Safety Injection Input from ESF Not Applicable l
I ^. "::r' ^" Crr! 2nt "' 7 ",r :hcr .";; . t .ui. Ti ry " t .".pp'!;;i?0 o l l
'^ o . ;comt:r '-!; Cy:t:: 1-*--1a-'e . ":t App' 'r :'2! -
18)HF. Reactor 1 rip Breakers Not Applicable us 19 )RC Automatic Trip Logic Not Applicable l rn 1 13 l
- 1 en l
t5 ' i l 1 s
TABLE 4.3-1
'T
] REACTOR TRIP SYSTEM INSTRUHFNTATION SURVEILLANCE REQUIREMENTS TRIP ANALOG ACTUATING M00ES FOR CilANNEL DEVICE WHICH CllANNEL CilANNEL OPERATIONAL OPERATIONAL ACTUATION SURVEILLANCE FUNC110NAL UNIT CHECK CALIBRATION TEST TEST LOGIC TEST IS REQUIRED
- 1. Manual Reactor Trip N.A. N.A. N.A. R N.A. 1, 2, 3*, 4*, 5*
- 2. Power Range, Neutron Flux 6 Iligh Setpoint S(d) D(2, 4), M N.A. N.A. 1, 2 M(3,4),
Q(4,6), 6 R(4,5) Low Setpoint S(A) R(4) N N.A. N.A. 1,,,, 2 t' 3.. Power Range, Heutron Flux, N.A. R(4) M N.A. N.A. 1, 2
** High Positive Rate
't M 4. Power Range, Neutron Flux, N.A. R(4) M N.A. N.A. 1, 2 liigh Negative Rate
- 5. Intermediate Range, S( ) R(4, 5) S/U(1),M N.A. ###
N.A. 1 ,2 Neutron Flux
- 6. Source Range, Neutron Flux S(d) R(4,5) S/U(1),M( ) N.A. ##
N.A. 2 , 3, 4, 5
- 7. Overtemperature AT S R M N.A. N.A. 1, 2
- 8. Overpower AT S R H N.A. N.A. 1, 2
- 9. Pressurizer Pressure--Low S R H N.A. N.A. 1
, 10. Pressurizer Pressure--liioh S R M N.A. N.A. 1, 2 rn
- 11. Pressurizer Water Level--High S R N N.A. N.A. 1 Y. 12. Loss Of Flow S R H N.A. N.A. 1
'e
TABLE 4.3-1 (Continued) l t* Ji REACIOR TRIP SYSTEM INS 1RUMENTAIl0N SURVEILLANCE REQUIREMENTS
-4
<n TRIP ANALOG ACTUATING MODES FOR CllANNEL DEVICE WillCil l CllANNEL CllANNEL OPERATIONAL OPERATIONAL ACTUATION SURVEILLANCE l l
FUNCTIONAL UNIT CllECK CALIBRATION TEST TEST 10GIC IEST IS REQUIRfD
- 13. Steam Generator Water Level-- S R H N.A. N.A. 1, 2 Low-Low
;L asea. C .. ...,.. . 6e, n.e ; - 8 /* At Mdt. JHt? -h-Y
;.v,. Co..iuiuci6 w i 6.i amo /
Tmmm.;u ":1 "' .;;;;. If E Undervoltage - Reactor Coolant N.A. R N.A. M N.A. 1 Pumps w l ) isJs. Ilnderfrequency - Reactor N.A. -R N.A. M N.A. I w Coolant Pumps s V
" 16 W Turbine Trip 9 A. '.., T ' ;' d ' "- ; n ur: N.A. N.A. N.A. S/U(1, Jff N.A. 1 B. T... : ':: St:i. '!.;.e N.A. N.A. N.A. S/U(1,M) ) N.A. I
{?rr r I? )s. Safety Injection Input from N.A. N.A. N.A. R N.A. 1, 2 ESF
;^. nuocour couio.. T .,, "v . m . L . M. W h 4 M A l Tus.... T.- ir
-20. -- T,couus I..',. 0, ic_ !... .;o,_L; M A. ii.sc _;d a t " ...;;
N Nu u s . ... T'ua, T 0- 4h4. Af+)- .E., -N-** .-46-#. [
$ si. ._ v " x;. ";;:t:r.
n T. .e. Gium, E ;- *-A. ,p(4 ." (c) - -te-a. -*-*. A-l e _ u. ruwei no..uc . - - - . . - Fiua, r;a- -ft-*- 244.) 4; (0) era. -ft-*- ,7 l
TABLE 4.3-1 (Continued)
'T y REACTOR TRIP SYSTEM INSTRUMENTATION SURVEILLANCE REQUIREMENTS TRIP ANALOG ACTUATING MODES FOR CllANNEL DEVICE WHICil CHANNEL CllANNEL OPERATIONAL OPERATIONAL ACTUATION SURVEILLANCE FUNCTIONAL UNIT CllECK CALIBRATION TEST TEST LOGIC TEST IS REQUIRE 0 hm A .,.;h ; ." . . :,_;.;;
Mr. t r .. G oo , P 10 4t-h - -ftt+) W h *19tA--- M C. Turik ,.;h: 0 . A.- P . - . . , P 12- N-A. -R- M '0) -ft-A-- 4:*--- 4 O,lo) IB yf. Reactor Trip Breaker N.A. N.A. H.A. M 477 N.A. 1, 2, 3* , 48, S* 19)f. Automatic Trip Logic N.A. N.A. N.A. N.A. M (7) 1, 2, 3*, 4*, S* Y Z i t o I w
TABLE 4.3-1 (Continued) TABLE NOTATION With the reactor trip system breakers closed and the control rod drive system capable of rod withdrawal. M - Below P-6 (Intermediate Range Neutron Flux Interlock) setpoint.
#M -
Below P-10 (Low Setpoint Power Range Neutron Flux Interlock) setpoint. (1) - If not performed in previous 7 days. (2) - Heat balance only, above 15% of RATED THERMAL POWER. Adjust channel if absolute difference greater than 2 percent. (3) - Compare incore to excore axial flux difference above 15% of RATED THERMAL POWER. Recalibrate if the absolute difference is greater than or equal to (3) percent. (4) - Neutron detectors may be excluded from CHANNEL CALIBRATION. ande,rp.u M an. M o w (5) - Detectorplateaucurvesshallbeobtained,endevaluatehForthe Intermediate Range and Power Range Neutron Flux Channels the provisions of Specification 4.0.4 are not applicable for entry into MODE 2 or 1. (6) - Incore - Excore Calibration alwe75'/, JRMco7WpMLNG.Nfnv4/ess d spec;6c.fi.a 4<.e.v ar 4.pf t ..W /.e ,4,y is, etabt z e e 1. (7) - Each train shall be tested at least every 62 days on a STAGGERED TEST BASIS. R aiun m m. 3..;t:r th:n ;r .,.1 - on. ..... iu u ser.ponn. n. . w.-:r;d CTa ivML 4th saiaII w..a ! L v 7 . . i f,7 !..y that th ...Orl:Ch i; '7 - th ;., :.mu s uo u. o., :i::r;'n;; th: ; :--i ;; i . ; .. .. ... .;. i ;te . -i r. i _ .-- l 8 (wh he re de.--{rie Weake.s sd) l (/) - Monthly Surveillance in MODES 3*, 4* and 5*xshall also include I. verification that permissives P-6 and P-10 are in their required of the permissive state for existing plant conditions byshall observatiobcaHon of ihr Baron bilulien annunciator window.Modkly sue <*illance include veri 9 Alarm setraini oflan4an ce epal lo live fie,er lack ground. (MI) - Setpoint verification is not applicable. Q o) - A+ \eosi once (<r is unas etnd following nin4 anance oe adfus+~J of-fhe haefee Tr;y issakees , he TRIP Mtu4 ring bateC oftwria#t. 7DT sfa//inelude indered*4 verihe<fian c{ 1he Underveltage aml 5%r/ foyr. i W-STS 3/4 3-15 Ngy r 19s1
INSTRUMENTATION 3/4.3.2 ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION LIMITING CONDITION FOR OPERATION l 3.3.2 The Engineered Safety Feature Actuation System (ESFAS) instrumentation channels and. i.neop4eeine shown in Table 3.3-3 shall be OPERABLE '" t':'- t--i; , Mp., i c.t ; :: t - . . . : . '; . . :. - . .. . : .. . .'. ~ ; h; .c ' . .. .. ' ' ; ": t; : ? . t c.,' ..... . l T;il; 2.2
- x d with RESPONSE TIMES as shown in Table 3.3-X.
'{
APPLICABILITY: *As shown in Table 3.3-3. . ACTION: As 36n en Tde 11-3
, m. m __ eee,e . ~ m_--_, ,
_2
.. , - 4, g .:
4
^ " ' :M:II- . I 1 ; ; ; : : _,-. :._m,
_ . . ; t, '_
,- ,; ; " :a__,-_
" ' ' ^ ""_.u.
"^ " -s
"^"", n no" i innno.ex,- - ; --- ,-
th; l
'#*^-^"+
r$+b.,,f..h
-^
"# *^ 2 2 2 J I' "^ "" S 1
- :f t: ^ ^ " ' ' " " ' . " :'"' 'i+h +h* +4" ~~'- '
t-s-U
,..,.,4,. + m 4 + i, +,,o r ,. 4 , co+, 4-+ . - ' - l
' . .. . o n ---^- :............... :':-- '
'.tr'_ d 1. m . _;e, t;M-_
. . . . K Kn suvwn in ieoie ; . ; : .-
SURVEILLANCE REOUIREMENTS 4.3.2.1 Each ESFAS instrumentation channel ' M 4ata '^ d and the automatic actuation logic and relays shall be demonstrated OPERABLE by the performance of the engineered safety feature actuation system instrumentation surveillance requirements specified in Table 4.3-2. 4.3.2.2 The ENGINEERED SAFETY FEATURES RESPONSE TIME of each ESFAS function shall be demonstrated to be within the limit at least once per 18 months. Each test shall include at least one train such that both trains are tested at least once per 36 months and one channel per function such that all channels are tested at least once per N times 18 months where N is the total number of redundant channels in a specific ESFAS function as shown in the " Total No. of Channels" Column of Table 3.3-3. W-STS 3/4 3-16 SEP 151081
TABLE 3.3-3 y ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION MINIMUM TOTAL NO. CilANNELS CHANNELS APPLICABLE FUNCTIONAL UNIT OF CllANNELS TO TRIP OPERABLE MODES ACTION
- 1. SAFETY INJECTION, REACTOR TRIP, FEEDWATER ISOLATION, 7 ,,y,,g g 4GNNtetHNNH499Wttfelt, START g DIESEL GENERATORS, 49NWWNME W 400ETN94AltS AND E99EftMM.#nm4A SERVICE WATER.
- a. Manual Initiation 2 1 2 1,2,3,4 4T I A.
- b. Automatic Actuation 2 1 2 1,2,3,4 +t 4 R
Logic and Actuation Relays T d c. Containment 3 2 2 1, 2, 3 W ts* Pressure-liigh
- d. Pressurizer 4 2 3 1,2,3 # # 17 Pressure - Low
- e. .G M 4er r i':? 1, 2, 3 "r = =r: "r * := r Steam Liney k :henure Law i) Four Loop Plant Four Loops 3/ steam line 2/ steam line 2/ steam line AB* td Operating in any steam line
" r= '.::;: ?/r;- st' ; t ':t:x /:;: :t'r.; #
~ 0;;r t!.m atu ! l..s n: 22y 3L ? !..e "" ^^^ : i , m c i:= n 3
l TABLE 3.3-3 (Continued)
] ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION MINIMUM TOTAL NO. CilANNELS CllANNELS APPLICABLE FUNCTIONAL UNIT OF CilANNELS TO TRIP OPERABLE MODES ACTION Y INJECTION, REACTOR TRIP, FEEDW ISOLATION CONTROL ROOM ISOLATION, RT DIESEL GENERATORS CONTAINMENT C0 G FANS AND ESSENTIAL SERVICE R (Continued)
- 11) Three Loop nt Three Loops steam line 2/ steam line 2/ steam 1 15*
Operating twice and 1/3 y steam lines Y Two Loops 3/ operating 2 ###/steam / operating 16 M Operating steam line twic steam line in e ope i am line
- f. Steam Flow in Two ##
1, 2, 3 Steam Lines-liigh i) Four Loop Plant Four Loops 2/ steam line 1/ steam line 1/ steam line 15* Operatin any 2 steam lines h I ee Loops 2/ operating l ###/any 14perating 16
- perating steam line operating steam line ci
' steam line L _ _ _ _ _ _ _ _ - -
TABLE 3.3-3 (Continued) y ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION l l MINIMUM TOTAL NO. CHANNELS CHANNELS APPLICABLE FkTIONALUNIT OF CHANNELS TO TRIP OPERABLE MODES ACTION SAFETY CTION, REACTOR TRIP, FEEDWATER I TION, CONTROL ROOM ISOLATION, STA IESEL GENERATORS CONTAINMENT C00LI ANS AND ESSENTIAL SERVICE WATER (Contin
- 11) Three Loop Pla Three Loops team line 1/ steam line 1/ steam line 15*
Operating any 2 steam g lines T Two Loops 2/ operating ###/any 1/oper g 16 0 Operating steam line o ating ste ine stea ine Coincident With Either 1, 2, 3 0 T,yg--Low-Low i) Four Loop Plant Four Loops p 15* 1Tavg/l 1 T,yg any 1 T,yg any Operating 2 loops 3 loops
### 16 Ti Loops 1 T,yg/ 1 T,yg in 1 T,yg in any m Perating operating any operating two operating m loop loop loops (19 (D.
TABLE 3.3-3 (Continued) ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION
]
MINIMUM TOTAL NO. CllANNELS CilANNELS APPLICABLE l FUNCTIONAL UNIT OF CilANNELS TO TRIP OPERABLE MODES ACTION ETY INJECTION, REACTOR TRIP, FEE TER ISOLATION, CONTROL ROOM ISOLAT START DIESEL GENERATORS CONTAINME 00 LING FANS AND ESSENTIAL SER E WATER (Continued)
- 11) Thre oop Plant Three Loops 1 T,yg/ loop 1 T,yg any 1 T,yg any W Operating 2 loops 2 loops
[ Two Loops 1 T,y 1 T,yg in 1T nav M ! o Operating operating op any operating erating loop loop Or, Coincident With Steam Line Pressure-Low 1, 2, 3 0 i) Four Loop Plant Four Loops 1 pressure / 1 pressure 1 press 15* Operatint loop any 2 loops any 3 loop T e Loops 1 pressure / 1 pressure 1 pressure 16 perating operating in any oper- in any 2 m loop ating loop operating loops R$9
TABLE 3.3-3 (Continued) ENGINEERED SAFETY FEATURE AC10ATION SYSTEM INSTRllMENTATION (( MINIMUM TOTAL NO. CilANNELS CllANNELS APPLICABLE FUNCTIONAL UNIT OF CilANNELS TO TRIP OPERABLE MODES ACTION SAF ECTION, REACTOR TRIP, FEEDWATER ON, CONTROL ROOM ISOLATION, START ENERATORS CONIAINMENT COOLING FANS ESSENTIAL SERVICE WATER (Continu ii) Three Loop Plant Three Loops 1 press pressure ressure 1S* Operating any 2 loops any s ops 1 pressure / 1### pressure 1 pressure 16 T Operating loop in any oper- any operating D' ating loop loop
- 2. CONTAINHENT SPRAY
- a. Manual 2 1 wrtte 2 1,2,3,4 )8' if,,
4? ::!ncider.t switd,ua-
- b. Automatic Actuation 2 1 2 1,2,3,4 J4' u logic and Actuation Relays
- c. Containment Pressure-- 4 2 3 1,2,3 X 19 liigh-High u>
43 3. CONTAINMENT ISOLATION l; a. Phase "A" Isolation as 1) Manual , 2 1 2 1,2,3,4 JMf l4 m~~
- 2) Safety Injection See 1 above for all Safety Injection initiating functions and requirements
TABLE 3.3-3 (Continued) y ENGINEERED SAFETY FFATURE ACTUATION SYSTEM INSTRUMENTATION MINIMUM TOTAL NO. CilANNELS CllANNELS ' APPLICABLE FUNCTIONAL UNIT OF CilANNELS TO TRIP OPERABLE MODES ACTION i CONTAINMENT ISOLATION (continued)
- 3) Automatic Actuation 2 1 2 1,2,3,4 M ll Logic and Actuation Relays
- b. Phase "B" Isolation
- 1) Manual 2 I w+th 2 1,2,3,4 ,M 14 2 c e . n.. a . t g 5 itcL.e
- 2) Automatic Actuation 2 1 2 1,2,3,4 34' It Y logic and Actuation N Relays
- 3) Containment 4 2 1,2,3 Pressure--liigh-liigh 3 E 11
- c. Purge and Exhaust Isolation
~
- 1) Automatic Actuation 2 1 2 1,2,3,4 38 IE glogic and Actuation Relays 2)$ [a6f,
+ + t 1, 2, 3, 4 W is'
,,m........, ....
m 3) Safety injection See 1 above for all Safety Injection initiating functions and Q requirements LT,
TABLE 3.3-3 (Continued) y ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENIATION MINIMUM TOTAL NO. CllANNELS CllANNELS APPLICABLE FUNCTIONAL UNIT OF CilANNELS TO TRIP OPERABLE MODES ACTION
- 4. STEAM LINE ISOLATION L sysfem Level 2- 1 'Z. I,2.3 0 1
- a. Manual z. L Jag. h l 1/ steam line 1/ steam line 1/ operating 1, 2, 3 3+ Zo steam line
- b. Automatic Actuation 2 1 2 1, 2, 3 Pe is Logic and Actuation Relays
- c. Containment Pressure-- 4 2 3 1,2,3 tP IY
- liigh-liigh
$ d. L F L., i '.:- Me d* hae Gae ' , 2. 3 e,,
L . '_i;;; ll ;,5.
- Pr*g*< 82*I* - Ihab ro i) Four Loop Plant Four Loops //steamline / steam line // steam line 3 Y 99* #2#
Operating A any X steam 1ines It. _ L;;;; Uvi.m . . . : ..; # ;..3
, / - '/:p:r;ti c.; Mr Op;c .i!. ;; ;t;;; -: g : :t* ; :t:: '*--
;t;:: '*^^
ri, I;.. - l _,. i i on s. Three Loop eam line 1/ steam line 1/ steam line W M Operating 2 steam
" lin c
Two Loops I /any 1/operatin 16 g Operat steam line operating steam line steam line
TABLE 3.3-3 (Continued) [NGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION
]
MINIMUM TOTAL NO. CilANNELS CilANNELS APPLICABLE FUNCTIONAL UNIT OF CilANNELS TO TRIP OPERABLE MODES ACTION j I S LINE ISOLATION (Continued) Coinc With Either T -- dow 1, 2, .3 avg i) Four Loop t Four Loops / loop 1 T,yg any 1 T,yg an 15* Operating 2 loops 31 . w y '
) Three Loops 1 T,yg/oper- 1 T y 1 T,yg in any 16 Operating Y ating loop any ing two operating Z p loops li) Three Loop Plant Three Loops avg / loop 1T avy any 1T avg any 15*
Operating 2 loops 2 loops Two
# 16 is 1 T,yg/oper- 1 T,yg 1 T,yg in any ating loop in any oper- operating loop ating loop i $=
t l - u.
l l i l l
# 4-2
_ 2 ~ ( 6 N / _ 1 $ O
#F f W # 7 TM I
T C M. 1 i A E L BS # ~ AE 3 3 f CD , 3 , , V. IO 5 3 LM 2 2 2 N P 7 2 O P , , , I A 1 1 1 l
/
T . A n g T N E M : a
- ; s i n -
re- ;.p M ; 7 : . g ep mt a p . o. U R SE MLL
,s e r;. ::: -:: m :
o: ro uo e ur se a e.a c 1 o ;. t T si
. h3 h4 S UEB - s sp c 2 N MNA
;2 - - ; ec eo t- ag 3 3 I INR $ ,. - r. r r p
- en NAE ,
. 7 , py pyo i 7.tc.f )
M I lip T . i. no /nt E MCO i.1 2 I o 1 al 2ia d T - e S u Y e n S - - r- . c . " r ; ur - ; a ; i e; sep r r- e g .p t N . n O L - _. ~ 7: r- spo o I S - : u- eoo ; p ..
~ r o t .t C
( T A U LP EI NR m ed
^
a y r ; 2 s s' e? py ng l 6 e.;y;sng 1 a z-3 NT M:'; r R an T t .
- C A s p , R i I
' an 3 A l iO y
. t p'= R nt ; i 3
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. s si c T
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- c. ,
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- 4 A O s -
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S TF / e ; po / D O 3 4 ! p
- I To '
iol Y/ E R E ) w o a E N d e L
- h t.. W,,,,&
I u e g r
. nn 'g G n r u : oo ^
N E i t n o t u s s e I 5 g s pg - 7 g T i u i Ug : g N r o ii tt aa uu 's*
'c a+
t C i r U on r_ i
. v un n O t - tt
( N P e U L Lt oi a :
^
i m ti ea c at
- 't a
I T A a-rl ee cc AA '"s s O t n I rr ; . o er 8
&L nvh cd e t
I - i U ue r- _
. re o O eeg in P
- L op h p .
np PS GLi t a T T A L ' f, m U 5 FO !" 7 iO T w% II R mr-i l a mcy r I O : a TR aeh oiao N S - e E et g t gl e (,. U I
- t S
J ; ET NA t ai SWl i uoemd ALR L A E " N 4 IW BD aa N O I , . RE UE we or I T L r M O d TF a b ays C A cs N E ' U T . F S S 4
*4m w5 w r* o ug n
w;nE l l1I.l i l lj-l l' l ll ll il
TABLE 3.3-3 (Continued) y ENGINEERED SAFETY FEATURE ACTUATION SYS1EM INS 1RUMENTATION MINIMUM TOTAL NO. CilANNELS CilANNELS APPLICABLE FUNCTIONAL UNIT OF CilANNELS TO TRIP OPERABLE MODES ACTION 7/. AUXILIARY FEEDWATER
- a. Manual Initiation 2 1 2 1, 2, 3 E-3 17
- b. Automatic Actuation Logic 2 1 2 1,2,3 fe /d and Actuation Relays
- c. Stm. Gen. Water Level-Low-Low .
w D 1. Start Motor- 8/ J d w Driven Pumps //sta. gen. 2/stm. gen. //sta. gen. 1, 2, 3 .M*- b r0 in any opera- i.. :::S
- ting sta gen. enar=*iag et;. g:n.
- 11. Start Turbine- '/ 3 Driven Pump //stm. gen. 2/sta. gen. //sta. gen 1, 2, 3 W @S-in any in :: h 2 operating spe. eti r g-stm. gen. -sta. ;;;;
sit $ci vu l Lcan u nbb J Ld I' L B uu p a ssu l l Or';er D"=p 4/ bus _ 4 + 2- .20* m M g. Safety Injection 9 Start Motor-Driven Pumps
- -'T"+: ._ ".
J....."-.-- See 1 above for all Safety Injection initiating functions and m requirements m E 8.f Station Blackout Start Motor-Driven Pumps 1[b"5 t[h8 /2 and Turbine-Driven Pump Yk3M pub f 1,2,3 19'
-(. Lihary -[vdade Sufion '9 e,_ t.m 5-1/$f s/r* 2/rV ' 2. 3
TABLE 3.3-3 (Continued) h ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION MINIMUM TOTAL NO. CilANNELS CllANNELS APPLICABLE , FUNCTIONAL UNIT OF CilANNELS TO TRIP OPERABLE MODES ACTION l l AUXILIARY FEEDWATER (continued) l
- g. Trip of Main Feedwater Pumps Start Motor-Driven Pumps W
, T ri h;-Cr . .. Fu,,,p 2/ pump 1/ pump 1/ pump 1, 2 8 11 l l 81 -ABT&'ATIC SWITC ;0C" T0 - to s CONI.dNMENT SUMP 'VN.sWL4f/ del to a. RWST Level - Low 4 2 3 1, 2, 3A E It to
" ^ uim. ie,,t Wi th fonteh: .t Srp.
-;.E. e l l igh 4-- - --
, ^ ^, , " , -t+-
+nti-W e+" hj :tiea S:: 1 -t : :- '- ' '- t; ' . .j . ". : .. . f - I t " -' 8 2 '"-" E . .. a nu
, ,, : n -tr-
- b. Automatic Actuation 2 1 2 1,2,3,4 -4+- ll Logic and Actuation Relays m
Q 9 h. LOSS OF POWER w % ete-ene Wetry tYetrs- 4,' . . -; , I , , , " Ae*' g cu.= ui vo; . g 3 L 4
- b. Grid Degraded Voltage // Bus 2/ Bus // Bus 1, 2, 3, 4 e gz
5 TABLE 3.3-3 (Continued)
'T u, ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION i.
MINIMUM i TOTAL NO. CilANNELS CilANNELS APPLICABLE
- FUNCTIONAL UNIT OF CilANNELS 10 TRIP OPERABLE MODES ACTION LNGi.mLKE0 SATET. iiniLKE nLiuA110N SY5itM INILHLUCKS
- a. Pressui.u r "raccu e 3 2 2 1, 2, 3 P-ll ,
- b. Low-Low Tava, P-12 4 e 3 1, 2, 3 21 c M eactor Trip, P-4 2 2 2 , , 23 R
+
i un Co m u w 09 (O
TABLE 3.3-3 (Continuedl TABLE NOTATION
# I Trip function may be blocked in this MODE below the P-ll (Pressurizer Pressure Interlock) setpoint.
## r._ , - , . . _ _ . , _ _ _ _ - m. mv - - - - '_, - --
U .Al . '. ?' : Tri kncIw a Yab5I 5[*UAJ5A 7-It aE $lE y L.NNo$w d b b when w 7-l.Tofdy Tajeckm a k ska, pseure te no{ bkked.
$ Nrm: m---
,m ,-.ss.s.u
^
- : : n , - <. .-e , - : _ , . _ e m --. .%
ww. wi as... . S.... .,vw e an w -wwr ... I' vs ylv .. . .I._ ' #^- I ~ 1
*The provisions of Specification 3.0.4 are not applicable.
ACTION STATEMENTS ACTION )( With the number of OPERABLE channels one less than the Minimum I: Channels OPERABLE requirement, be in at least HOT STANDBY within 6 hours and in COLD SHUTDOWN within the following 30 hours; however, one channel may be bypassed for up to 2 hours for surveillance testing per Specification 4.3.2.1, provided ( the other channel is OPERABLE. { ACTION 38 With the number of OPERABLE channels one less than the Total l ( 2. Number of Channels, operation may proceed until performance of l ' the next required OPERATIONAL TEST provided the inoperable channel is placed in the tripped condition within 1 hour. ACTION g With a channel associated with an operating loop inoperable, g restore the inoperable channel to OPERABLE status within 2 hours or be in at least HOT STANDBY within the next 6 hours and in at least HOT SHUTDOWN within the following 6 hours. One channel associated with an operating loop may be bypassed for up to 2 hours for surveillance testing per Specification 4.3.2.1. ACTION ,W With the number of OPERABLE channels one less than the Total g Number of Channels, operation may proceed provided the inoperable channel is placed in the bypassed condition and the Minimum Channels OPERABLE requirement is met. One additional channel may be bypassed for up to 2 hours for surveillance testing per Specification 4.3.2.1. ACTION W - With.less than the Minimum Channels OPERABLE requirement, g operation may continue provided the containment purge supply and exhaust valves are maintained closed. W-STS 3/4 3-29 SEP 15198k
TABLE 3.3-3 (Continued) ACTION STATEMENTS (Continued) Ik ACTION 18*- With the number of OPERABLE channels one less than the Minimum Channels OPERABLE requirement, restore the inuperable channel to OPERABLE status within 48 hours or be in at least HOT STANDBY within the next 6 hours and in COLD SHUTDOWN within che following 30 hours. li ACTION 26 - With the number of OPERABLE channels one less than the Total Number of Channels, STARTUP and/or POWER OPERATION may proceed provided the following conditions are satisfied:
- a. The inoperable channel is placed in the tripped condition within 1 hour.
- d. The Minimum Channels OPERABLE requirements is met; however, one additional channel may be bypassed for up to 2 hours for surveillance testing of other channels per Specification 4.3.2.1.
~ :: 21 - Wi th le ., then th; t..:..~.. L../..
Ch;nn;1: C":Z" 2 , "i+"'- cT.e .~.me......... L :t:: - *4^- a' +** ~ ~-4'+ad aa #;i; em o.. ..t;n # Gd.-(;) th2' *h" # " ' - 1 ; . ., . . ~ it. ;;ii?Od .
- t;t 1. ... e 1,.in; pi;nt ;;nditi:n, 1;ia :; ;i'i:;t# 02 4=%). ,
ACTION 3E'- With the number of OPERABLE Channels one less than the Minimum j \6 Channels OPERABLE requirement, be in at least HOT STANDBY l within 6 hours and in at least HOT SHUTDOWN within the following 6 hours; however, one channel may be bypassed for up to 2 hours for surveillance testing per Specification 4.3.2.1 provided the other channel is OPERABLE. ACTION JMT With the number of OPERABLE channels one less than the Total 19 Number of Channels, restore the inoperable channel to OPERABLE status within 48 hours or be in at least HOT STANDBY within 6 hours and in at least HOT SHUTDOWN within the following 6 hours. ACTIONJk( With the number of OPERABLE channels one less than the Total
%0 Number of Channels, restore the inoperable channel to OPERABLE status within 48 hours or declare the associated valve inoperable and take the ACTION required by Specification (3.7.1.5).
SEP 151981 W-STS 3/4 3-30
TABLE 3.3-4 y ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION TRIP SETPOINTS FUNCTIONA TRIP SETP0lNT ALLOWAB VALUES
- 1. SAFETY INJE ON, REAC10R TRIP, FEEDWATER ISO ON, CONTROL ROOM ISOLATION, START DIESEL GENE RS, CONTANMENT COOLING FANS AND ESSENTIAL S CE WATER.
- a. Manual Initiation Not Appilcable Not Applicable
- b. Automatic Actuation Logic Not Applicable Not Applicable and Actuation Relays
- c. Containment Pressure--High < 5 psig < 5.5 psig
- d. Pressurizer Pressure--Low 11 p ig 1 1755 psig w e. Differential Pressure ~< 60 psi < 112 psi g Between Steam Lines--High
~
- f. Steam Flow in Two Steam Lines-- < A function det ed as < A function defined as liigh To110ws: A Ap corr - Toilows: A Ap corresponding i sponding to 40% of fu to 44% of full steam flow steam flow between 0% an between 0% and 20% load and 20% load and then a Ap in- then a Ap increasing linearly creasing linearly to a Ap o a Ap corresponding to corresponding to 110% of 1 5% of full steam flow at full steam flow at full ful oad load Coincident i h Either h 1. T g
--Low-Low, or 2 (541)*F 1 (539)"F
[ 2. Steam Line Pressure--Low 2 (600) psig 1 (580) psig
1 TABLE 3.3-4 (Continued) 3 ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION TRIP SETPOINIS FUNCTIONAL UNIT TRIP SETPOINT ALLOWABLE VALUES ! 2. CONTAINMENT
- a. Manual Initiation Not Applicable N Applicable
- b. Automatic Actuation Logic Not Applicable Not Applicable and Actuation Relays
- c. Containment Pressure--liigh-liigh _ (20) psig 1 (22) psig
- 3. CONTAINMENT ISOLA 110N y a. Phase "A" Isolation
+
y 1. Manual Not licable Not Applicable
- 2. Safety Injection e 1 above for all Safety ' ction Trip Setpoints/
Allowable Values i
- 3. Automatic Actuation Logic Not Applicable Not App cable and Actuation Relays
- b. Phase "B" Isolation
- 1. Manual Not Applicable Not Applicable
- 2. Automatic Ac tion Logic Not Applicable Not Applicable and Actuat' Relays y 3. Contai nt Pressure--liigh-liigh 5 (20) psig 5 (22) psig e-tJS
TABLE 3.3-4 (Continued) y ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSlRUMENTATION TRIP SETPOINTS FUNCTIONAL UNIT - TRIP SETPOINT ALLOWABLE VALUES CONTAINMENT I . TION (continued) y
- c. Purge and Ex t Isolation
- 1. Automatic Actuat Logic Not Applicable Applicable and Actuation Relays l 2. Containment Radioactivity--Hi ($ 2 x background) ($ 2 x background)
- 3. Safety Injection Se 1 above for 1 Safety Injection Trip Setpoints/
- Allow e Va s l
R a
- 4. STEAM LINE ISOLATION
- a. Manual Applicable Not Applicable
- b. Automatic Actuation Logic Not Applicable Not Applicable and Actuation Relays l c. Containment Pressure-- gh-liigh $ (20) psig _ (22) psig
- d. Steam Flow in Steam Lines-- < A function defined as <A liigh ction defined as Tollows: A op correspond- Tollows: A op corresponding i
ing to 40% of full steam to 44% of I steam flow be-flow between 0% and 20% tween 0% and load and load and then a Ap increas- then a op incre ing linearly ing 1inearly to a Ap corre- to a 6p corresponding to sponding to 110% of full 111.5% of full steam flow at m steam flow at full load full load o' ? *-* < en i j
TABLE 3.3-4 (Continued) y ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION TRIP SETPOINTS FUNCTIONAL UNIT TRIP SETPOINT ALLOWABLE VALUES STEAM LINE ISO - continued) Coincident With Eit
- 1. T,yg--Low-Low, or 1 (541)*F 1 (539)*F
- 2. Steam Line Pressure--Low 1 600) psig 1( psig
- 5. TURBINE TRIP AND FEED WATER ISOLATION
- a. Steam Generator Water level-- < (6 % f narrow ran < (68)% of narrow range High-High Tnstrunei span ea steam Tnstrument span each steam y generator generator
+
w b. Automatic Actuation Logic Not Applic e Not Applicable g and Actuation Relays
- 6. AUXILIARY FEE 0 WATER
- a. Manual Not Applicable Not Applicable
- b. Automatic Actuation Logic Not Applicable N Applicable and Actuation Relays
- c. Steam Generator > (10)% of narrow range > (9)% o narrow range Water Level-Low-L Instrument span each Tnstrument pan each steam generator steam genera r h d. Underv age - RCP 1 (70)% RCP bus voltage 1 (69)% RCP bus altage C e. Safety Injection See 1 above for all Safety Injection Trip Setpoin g Allowable Values 9
) TABLE 3.3-4(Continued}
- 19 ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION TRIP SETPOINTS
}
FUNCTIONAL TRIP SETPOINT ALLOWABlEVA) DES i AUXILIARY FEEDWATL (continued)
- f. Station Blacko 3 ( )% Transfer Bus Voltage 2( Transfer Bus Voltage i g. Trip of Main Feedwate Not Applicable et App 1fcable Pumps
- 7. AUTOMATIC SWITCl10VER TO CONTAINMENT SUMP
- a. RWST Level - Low \(130")fr base > (126") from tank base Coincident With Containment Sump Level - High 1 (3,0") ove elev. (680') 5 (32.5") above elev. (680')
T and Safety Injection f 1 above for 1 Safety injection Trip Setpoints/
/ Allowable Values)
- b. Automatic Actuation Logic Not Applicable Not Applicable and Actuation Relays
- 8. LOSS OF POWER p/
- a. 4.16 kV Emergencf Bus Undervoltage ( 1 ) volts with a ( 1 ) volts with a (Loss of Voltage) ( 1 ) second time delay ( i second time delay
- b. 4.16 kV J t ergency Bus Undervoltage ( i ) volts with a ( i ) vo ts with a y, (Degrad6d Voltage) ( 1 ) second time delay ( i ) seco time delay tre s
i 6 TABLE 3.3-4 (Continued) {j ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION TRIP SETPOINTS FUNCTIONAL UNIT TRIP SETPOINT ALLOWABLE VALUES-
- 9. ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INTERLOCKS
- a. Pfh urizer Pressure, P-ll 5 (2000) psig < (2010) psig
- b. (543)"F l.ow-Low T,yg, P-12 > (541)*F a _ 5)*F
- c. Reactor Trip, P- Not Applicable Not Applicable R
+
(a Mu v.* OO
V TABLE 3.3-4 j ENGINEERED SAFETY FEATURES RESPONSE TIMES INITIATING SIGNAL AND FUNCTION RESPONSE TIME IN SECONDS
- l. Manual
- a. Safety Injection (ECCS) Not Applicable 6 b. Containment Spray Not Applicable
) c. Containment Isolation [ Phase "A" Isolation Not Applicable t Phase "B" Isolation Not Applicble Purge and Exhaust Isolation Not Applicable
- d. Steam Line Isolation Not Applicable
- e. Feedwater Isolation Not Applicable
- f. Auxiliary Feedwater Not Applicable
- g. E1Y.l;lServiceWater Not Applicable c
P h 'vpnea4
...t 9 C.,1g
-t C .. pa4eI ... 3 .., Not Applicable
. Ge M Msel,n;ae,rahc3
- 1. w...... .. ...._m Not Applicable
- 1. TeacAse Tc;p (bm SI) e/of Ay O.,W
- 2. Containment Pressure-High
- a. Safety Injection (ECCS) $ (27.0)(1) g
- b. Reactor Trip (from SI) < (2.0)
- c. Feedwater Isolation ~
(7.0) N/ of 8
- d. Conthinment Isolation-Phasq
- 5
" " @+ ~(lf.0)(z)/(2T.0)(k)
- e. Containment # eve.endPurgegsoation 5 {-05. ^'(1)/GG. 6)m p.4 -
- f. Auxiliary Feedwater ".;p < '50. 0) M 4-
#adu, ^ g. 1::sti n Service Water Cy:'^_ $(N.0)(N,/(N.0)(p-)
- h. E$E :bf 1 - fe..; < %g( (p.0)f) 1.
. . Y::hYa @ bt ^~"*' 8 N s tt .5 1
4 g W-STS 3/4 3-37 SEP 151981 s 1 _ _ _ _ _ _ _ _ _ _ _ _ _ _ - _ _ _ _ _ _ _ _ _ _
^
1 l 4 TABLE 3.3-jl(Continued) ENGINEERED SAFETY FEATURES RESPONSE TIMES INITIATING SIGNAL AND FUNCTION RESPONSE TIME IN SECONOS
- 3. Pressurizer Pressure-Low J
- a. Safety Injection (ECCS) 1 (27.0)(1)(12.0)d)
- b. Reactor Trip (from SI) < (2.0) !
- c. Feedwater Isolation (7.0 b g i
- d. Containment Isolation-Phase "A"( 1(lf.0)O)/(21.0)O) !
- e. Containment '!;ct --d. Purge Isolation ' '"
" 10 . ' ,' M 4-
- f. Auxiliary Feedwater Sumps '
Sw. :' v. A . M
, 3 Akcke P E::: ti.' Service ater System < (M.0)(1)/( M.0)(o 'y '
I h.
-Y SJan WL Am!*ha; . _;. ;
f
~_M.0)(1)f(g.0)(#)* l
- 1. . . . . . . . . . . . . . . . . . _ _ . _ .
m stee L.ne -W 331 0 q
- 4. m. . . ...._1 Pressure 2:' --- c'---
:: "'f. g 3 2.
- a. Safety Injection (ECCS) 1 (22.0) )/(L2.0) )
- b. Reactor Trip (from SI) 1 (2.0)
- c. Feedwater Isolation < (7.0) N.? 4 i
- d. ContainmentIsolation-Phase"A"b (1f.0)(I)/(2.0)O)
- e. Containment ": ' --d Purge Isolation 1 ' ^ . C'(1) l . G(2)N.4.
l
- f. Auxiliary Feedwater eumpe
< ':: . " ' 7. W 0 Act,4e@Essentee+ Service Water System - (N. 0)n)/('f.0)(
G.~poned f. elm ,Uaier, 6 !
- h. __...c - . _ ___ <(55.0)(g/(Ha40.0)(f)
. Sort bicyl,Mj. .;ry.__ .- _ .... ~ rq
- 1. . . . . . . . . .. o.
.y,...__.-
g,11.
. 0
% - L.W. -L tab 1
r- . - __ e.___ , _ ,,m - '--#"- ' f7o
h 7
"U l _,__.:__
,..u_.L._ <
- I4 I I-w. m..,r.,- e-s
, _ , , _, _.s ~~
. - , _ w .us ,
m \ . _ __
-~r...,
- 1 .__ ,..,m
- 11
\ a,,
s./.
- ~ l
. v. -.......... ,.2o.
,. X. . [..
. . . _ c 1[,...,(21
.,(1),, .__
, ~ . . ,
-,(IT
- /M
. . . . . . . iau.o.- s ,.e, , m .vj
, . , .. . . . V. . . . . _ , . g t
_ . . . . . , .v;
. . /:. \. . . _. . ., . _s
")
i
! 73 (2) . m .u,- l
_ . . . . . . .y . . . ,. . . . .
'" [
. ^ [- ' ,' . _\ j
~
, [ ,s(1 . m
/.. ,
- c. a r m_. ,__, _, ,
E-STS 3/4 3-38 SEP 15IcM
V TABLE 3.3-if (Continued) ENGINEERED SAFETY FEATURES RESPONSE TIMES INITIATING SIGNAL AND FUNCTION RESPONSE TIME IN SFCONDS L ._.... m .;. m ..J *:'--'f--+ '+' Ng"- ". : _ { T m--.. w __..,u uv
'*^ "'
- EA. T-4 p+(nn (pffq) ^
'^^ ^^
%.s.v) /\LL.U)
-, ._ r, ---
-- as vu. ... 7 s . . om oi; ; r.
- c. .ucuwater nation s s,.v, g e. ... -
. ,. , ( 2 ) ,__ _.(1)
..... Asue on-t' nase -a ; s...., , w,.us -
ras re%
- E*
- t ' -
c.. . . . . ven. caa l'q 1sclation 5 (Zb.0)' '/(.LU.U)'
- 1. A " # ' # 1 '^,^ ' '... . .. .vmpa 1 (ou.vj foi .(1) 9__ E.. ..wana actvawc evo wc a aystem N $ (32.U);,/(*i.vj
- '.. u .ie isonar. ion
\ $ (9.0)'~'
~
r.n
" : . . .. . . .. n u vooiing rans
- K .0) "'/(40.0)'
i j " " -J. . . '. .^ v em - aviewion Not A g acie 5 i. Containment Pressure--Hich-High
- a. Containment Spray 1 (45.0) N/ ' 7.0) N
- b. Containment Isolation-Phase "B" i '""' ."'! MA-
- c. Steam Line Isolation iM N 6 ?. o bk. Steam Generator Water Level--Hich-High
- a. Turbine Trip 1 M -iH) N A .
- b. Feedwater Isolation 1 ((.0 .,
? }. Steam Generator Water Level - Low-Low _
- a. Motor-driven Auxiliary
. Feedwater Pumps 1 (60.0)
- b. Turbine-driven Auxiliary
- Feedwater Pumps 1 (60.0) g - . , . . . . , , . .
_ s .. ,- - (13,s, , .. . .-, ,4f) __m em..._, , , ,--
- 8. _Aleqdve., Tb L*ne. Pressure O. Nhk
, v-
- c. 5 % L;ae h ledio a n 7'O 9.SbA Peenr 5;Ve
- a. con w o - + feossee Ga-bl y S b d-Io. Tem na.k n
- c. (,of /4, ed fressure Gnh,( S y s b dA W-STS 3/4 3-39 SEP 151981 :
T/ILE3.3-/l(Continued) ENGINEERED SAFETY FEATURES RESPONSE TIMES INITIATING SIGNAL AND FUNCTION RESPONSE TIME IN SECONOS
- 11. WWST Leve l- Low t _ . . .. . .... . .. C.. . . c ' '- ;
L . '. ' . s.. .. .: 2 - , I . . a m m e . m,
- a. Automatic Switchover to 4eew4 ament. GO.0 6 amp Eccircala b a $ 0:0}7g/( 3 }gy)
Amluy %khe .Ge hoo (nuar e - %
- 12. N
- a. liembsne deemos Auxiliary Feedwater Pumps (Lc.Wa 59jL 1-(CC.0} 13.0 A i =
- b fe al; p m a n
- 13. Station Blackout Whie*E*^ a. A Auxiliary Feedwater Pumpt 5 (60.0)
%. & M** L%y FeedusterQs g, fc,o
- 14. Trip of Main Feedwater Pumos
- a. A Auxiliary Feedwater Pumps t'"'-:
1%e twee 4 60 U
- 15. Loss of Power
. . , u ; (10}
N '. .m' =,u'.J/ o3s w 4 :... . ( L- '- L '.. 3.} O. / 4 E kV Emergency Bus Undervoltage (Degraded 1M y,o l Voltage) W-STS 3/4 3-40 SEP 151981
l
-4 TABLE 3.3[(Continued)
TABLE NOTATION (1) generator starting and sequence loading delays include (2) Diesel genera tarting and sequence loadin not included. Offsite power avai (3) Air operated valves (4) Diesel generator ing and sequence ing delay included. RHR pumps not i ed. (5) el generator starting and sequence loading delays included. RHR pumps not included. (1) Diesel generator starting and sequence loading delays included. Response time limit includes opening of valves to establish SI path and attainment of discharge pressure for centrifugal charging pumps, SI and RHR pumps. S (#) Valves 1KC305B and 1KC3158 are exceptions to the response times listed in the table. The following response times in seconds are the required values for these valves for the initiating signal an function indicated: 3-
- 2. d < 30.0(9/40.0C) 3.d 7 30.0( .h 4 M.d 330. /40.0 N)
($) Diesel generator starting and sequence loading delays not included. Offsite power available. Response time limit includes opening of valves to establish SI path and attainment of discharge pressure for centrifugal charging pumps. (/) Diesel generator starting and sequence loading delays included. Response time limit includes opening of valves to establish SI path and attainment of discharge pressure for centrifugal charging pumps. LY 'Regase {ime. &e euke br ven aw%y bedwebys e a ({ Sa& k'gdm S;go is 64 k less 4kan or 9*=l le lo sew,Js. fespas lict UM4-includes oping el vatas 4o esMUsk Safeh hjeekn f ad akinmut of- bse.korge pressu.re .(or m;f;ny Qw&,- ,, W-STS 3/4 3-41 15 E l
TABLE 4.3-2 nc ENGINEERED SAFETY FEATURE AC10ATION SYSTEM INSTRUMENTATION J. SURVETITANCInfET)IITIEMENTS d TRIP
) ANALOG ACTUATING MODES CilANNEL DEVICE MASTER SLAVE FOR WilICil CllANNEL CllANNEL OPERATIONAL OPERATIONAL ACTUATION RELAY RELAY SURVEILLANCE FUNCTIONAL UNIT CilECK CALIBRATION TEST TEST LOGIC TEST TEST TEST IS REQUIRED
- 1. SAFETY INJECTION, REACTOR TRIP, FEEDWATER ISOLATION, 60NNtek&caffoMd(NT tooud UArc4 M04 469h*T4GN START DIESEL GENERATORS , 4GN3A4NHHH -800t+N8-fen 9 AND &&&ENI.&AL SERVICE WATER A etc4.E4t.
- a. Manual Initiation N.A. N.A. N.A. R N.A. N.A. N.A. 1, 2, 3, 4
- b. Automatic Actuation N.A. N.A. N.A. N.A. M(1) M(1) Q 1, 2, 3, 4
, Logic and Actuation Relays D c. Containment Pressure- S R H N.A. N.A. N.A. N.A. 1, 2, 3 y liigh e d. Pressurizer Pressure- S R H N.A. N.A. N.A. N.A. 1, 2, 3 Low
- e. N "rn.t :;; '. m. - S R H N.A. N.A. N.A. N.A. 1, 2, 3 L.--.71_ L . :r --
%g8,. s4ea s Lim Paune -Lou e"
. -S- t M- # *- #-A. #=*. ft.1r:- ! , 2, 2 L . . .s . ::L,h 2c!~ L'rt kion G u. .
- 1. I gg La--Lo , r d_ W -M #-*. -M-A. #.'A . 4 A. 2, 2, ^
- c. m u mn o m- -G 4- # .kA- .LA, #:*- .48 A. 2, 2, 2 l 'c.... -L..
- 2. CONTAINMENT SPRAY l
l Mu a. Manual Initiation N.A. N.A. N.A. R N.A. N.A. N.A. 1, 2, 3, 4
. b. Automatic Actuation N.A. N.A. N.A. N.A. M(1) M(1) Q 1, 2, 3, 4
- o. Logic and Actuation ro- Relays
- c. Containment. Pressure-- S R 14 N.A. N.A. N.A. N.A. 1, 2, S 81igirlllgh
TABLE 4.3-2 (Continued) li: ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION {g SURVETEEKNCE REQUIREMENTS TRIP ANALOG ACTUATING MODES CHANNEL DEVICE MASTER SLAVE FOR WHICll CilANNEL CllANNEL OPERATIONAL OPERATIONAL ACTUATION RELAY RELAY SURVEILLANCE FUNCTIONAL UNIT CllECK CALIBRATION TEST TEST LOGIC 1EST TEST TEST IS REQUIRED
- 3. CONTAINHENT ISOLATION
- a. Phase "A" Isolation ,
j I) Manual N.A. N.A. N.A. R N.A. N.A. N.A. 1, 2, 3, 4 l
- 2) Safety Injection See 1 above for all Safety Injection Surveillance Requirements
- 3) Automatic Actuation N.A N.A. N.A. N.A. M(1) M(1) Q 1, 2, 3, 4 u, Logic and Actuation l ]s Relays
- un l jL b. Phase "B" Isolation i ua
- 1) Manual N.A. N.A. N.A. R N.A. N.A. N.A. 1,2,3,4
- 2) Automatic Actuation N.A. N.A. N.A. N.A. M(1) M(1) Q 1, 2, 3, 4 Logic and Actuation Relays
- 3) Containment S R H N.A. N.A. N.A. N.A. 1, 2, 3 Pressure--liigh-liigh c.
D anw( PurNeandExhaustIsolation p.A. At A. p. A. S P. A - A A. J'.A . t, 2. 1, Y 2 4) Automatic Actuation N.A. N.A. N.A. N.A. M(1) M(1) Q 1,2,3,4 lQ Logic and Actuation
') Relays
"' C ^ ,,, m .. .i ""- 4 4- *- 46cA. * *. 4MF M. ; , ^ , 2, "
3 mus'di ...m.
- 3) Safety Injection See 1 above for all Injection Surveillance Requirements.
TABLE 4.3-2 (Continued) er FNGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION h MMVe Maam U" SURVEILLANCE REQIIIRTRENTS fre=< fok - N;04 TRIP ANALOG ACTUATING MODES l CllANNEL DEVICE MASTER SLAVE FOR WilICll CilANNEL CilANNEL OPERATIONAL OPERATIONAL ACTUATION RELAY RELAY SURVEILLANCE FUNCTIONAL UNIT CllECK CALIBRATION TEST TEST LOGIC TEST TEST TEST IS REQUIRED
- 4. STEAM LINE ISOLATION
- a. Manual N.A. N.A. N.A. R N.A. N.A. N.A. 1, 2, 3
- b. Automatic Actuation N.A. N.A. N.A. N.A. M(1) M(1) Q 1, 2, 3
{ Logic and Actuation - Relays .
- c. Containment Pressure-- S R H N.A. N.A. N.A. N.A. 1, 2, 3 liigh-lligh d.
g L . ." L . . . ! . L . S R H N.A. N.A. N.A. N.A. M3
....,,,...y...m.-...
1
.p
-1. I evg L. L__ r 4- 4n- 4t SHW M 4 H h- 4Hr- 1, ^ , T
- d. K Steam Line S R H N.A. N.A. N.A. N.A. 1,2,3 Pressure--Low
- 5. TURBINE TRIP AND FEEDWATER ISOLATION
- a. Steam Generator Water S R H N.A. N.A. N.A. N.A. 1, 2 Level--liigh-liigh
- b. isutomatic Actuation N.A. N.A. N.A. N.A. M(1) M(1) Q 1, 2 y logic and Actuation Relay r? ff. AUXILIARY FEEDWATER
- a. Manual N.A. N.A. N.A. R N.A. N.A. N.A. 1, 2, 3 5
- b. Automatic Actuation N.A. N.A. N.A. N.A. M(1) M(1) Q 1, 2, 3 Logic and Actuation Relays
- u. c. Steam Generator Water S R H N.A. N.A. N.A. N.A. 1,2,3 m Level--Low-Low m
[- - 6. dsdaiace<d bsare 6ahol I'y den a . A rt Per.nusere S f. g A).A. M.A. N. A. N.A. \> 2 *I * *l
- 6. Tan.nale g q_ g g ,,, _, N ,. , , ,
,, z,4 y
TABLE 4.3-2 (Continued) IT ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION
'Q , SURVEILLANCE REQUIREMENTS v.
TRIP 9,,,,,,, s , ANA DG AC NATING Amdllar/ PeeA*de, M m MOMS 3 CilANNEL DEVICE MASTER SLAVE FOR WilICil CilANNEL CilANNEL OPERATIONAL OPERATIONAL ACTUATION RELAY RELAY SURVEILLANCE FUNCTIONAkl UNIT CilECK CALIBRATION TEST TEST LOGIC TEST TEST TEST IS REQUIRED AUXILIARffEEDdATER(Continued) g
- d. --":- N.A. R h N.A. N.A. N.A.
R 1,2,5
- e. Safety Injection See 1 above for all Safety Injection Surveillance Requirements
- f. Station Blackout N.A. N.A. N.A. R N.A. N.A. N.A. 1,2,3
- g. Trip of Main Feedwater N.A. 'N.A. N.A R N.A. N.A. N.A. 1, 2 Pumps u
B.M S' CONTAINMENT SUMP ReciW4utcrao C,
- a. E(SWT Level - Low S R H N.A. N.A. N.A. N.A. I , 2, 3, 4 i
Swene$dentrei4h 3u,,y o . . ..m . . . , _ _ _ _ . - - + 4- -4t- 44-*- N-*-- -H-* - M ;, 2, , L
'52[ . ,,j-.-:a R. 1 ouu.c ivi oil ,oim, :..j; :r 5:- .; P ..c '";r, ::;..t;
- b. Automatic Actuation N.A. N.A. N.A. N.A. M(1) M(1) Q 1, 2, 3, 4 Logic and Actuation Relays X.9. LOSS OF POWER
- a. 4 JW kV Emergency Bus N.A. R N.A. R N.A. N.A. N.A. 1, 2, 3, 4 Undervoltage " __ _'
y n um; (6r:J Deyndel o v.t+.
;. .J.g2 ).m . u. . .., ^ N +
- . #.W" W 4H*. 4&4. 46
- c' m .u m . ~: ., '" ,._.:_:
s
, 2, 2, 4
. g
,o
..u ;
1
TABLE 4.3-2 (Continued) 'j[ ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION SURVEILLANCE REQUIREMENTS
-g TRIP ANALOG ACTUATING MODES CHANNEL DEVICE MASTER' SLAVE FOR WHICH CilANNEL CHANNEL OPERATIONAL OPERATIONAL ACTUATION RELAY RELAY SURVEILLANCE CHECK CALIBRATION TEST TEST LOGIC TEST TEST TEST IS REQUIRED FUNCTIONAL UNIT ig onaL12 "" AFETY FEATURE ACTUATION 5 CKS
^ ^ '
N.A. u. 2, 3
- a. Pressurizer Pressure, N.A. M N.A. N.A. 1, P-11
~
- b. Low, Low T P-12 .. . n . R H N.A. ~~ u A- N.A. N.A. 1, 2, 3 c N.A. N.A. N.A. R N.A 2, 3 e
u Y o c-US i
TABLE 4.3-2 (Continued) TABLE NOTATION (1) Each train shall be tested at least every 62 days on a STAGGERED TEST BASIS. W-STS 3/4 3-47 SEP 151981
l bTRUMENTATION 3/4 3 MONITORING INSTRUMENTATION RADIAT MONITORING INSTRUMENTATION LIMITING CON TION FOR OPERATION 3.3.3.1 The radiat n monitoring instrumentation channels own in Table 3.3-6 shall be OPERABLE wi their alarm / trip setpoints within .e specified limits. APPLICABILITY: As shown 'n Table 3.3-6. ACTION:
- a. With a radiation monit ing channe alarm / trip setpoint exceeding the value shown in Table .3-6, just the setpoint to within the limit within 4 hours or d lar the channel inoperable.
- b. With one or more radiatio o 'toring channels inoperable, take the ACTION shown in Table 3 -6. ~
- c. The provisions of S cifications 3. 3 and 3.0.4 are not applicable.
SURVEILLANCE R UIREMENTS 4.3.3.1 Efch radiation monitoring instrumentation channel shall be emonstrated OPERABLO by the performance of the CHANNEL CHECX, CHANNEL CALIBRATION d ANALOG, CHANNEL OPERATIONAL TEST operations for the MODES and at the fre ncies show in Table 4.3-3. W-STS 3/4 3-48 SEP 151981
ped INSTRUMENTATION 3/a.3.3 REACTOR PROTECTION / ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INTERLOCK $ LIMITING CONDITION FOR OPERATION 3.3.3.1 The reactor trip system and engineered safety feature actuation system interlocks shall be OPERABLE as shown in Table 3.3-5. APPLICABILITY: As shown in Table 3 3-5. ACTION: As shown in Table 3.3-5. SURVEILLANCE REQUIREMENTS 4.3.3.1 Each reactor trip system and engineered safety feature actuation system interlock and the automatic actuation logic shall be demonstrated OPERABLE by performance of the reactor trip / engineered safety feature actuation system interlock surveillance requirements specified in Table 4.3-3. I l l CATAWBA - UNIT 1 3/4 5 24
S TABLE 3.3-5 U E5 I REACTOR TRIP / ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INTERLOCKS E MINIMUM i T 4 TOTAL NO. CilANNELS CHANNELS APPLICABLE
- FUNCTIONAL UNIT OF CllANNELS 40tNHis TD TN OPERABLE MODE ACTION
- 1. Reactor Trip System Interlocks A. Intermediate Range Neutron Flux, P-6 2 1 2 2# 20 B. Low Power Reactor Trips Block, P-7 m P-10 Input 4 2 3 1 20
% or
[. P-13 Input 2 1 2 1 20
$ C. Power Range Neutron Flux, P-8 4 2 3 1 20 D. Power Range Neutron Flux, P-9 4 2 3 1 20 l E. Iow Setpoint Power Range Neutron Flux, P-10 4 2 3 1, 2 20 F. Turbine impulse t'hamber Pressure, P-13 2 1 2 1 20
- 2. ENGINEERLD SAFETY FEATURE ACIUA110N SYSTEM INTERLOCKS A. Pressurizer Pressure, 3 2 2 1,2,3 20
%' P-il
~ B. Reactor Trip, P-4 4-2/ train 2/ train 2/ train 1, 2, 3 21
- 3. Automatic 1 rip Logic 2 1 2 1,2,3 21
[ TABLE 3.3-5 (Continued) TABLE NOTATION
# Below the P-6 (Intermediate Range Neutron Flux Interlock) Setpoint c
ACTION STATEMENTS Action 20 - With less than the Minimum Number of Channels OPERABLE, within one hour determine by observation of the associated permissive annunciator window (s) that the interlock is in its required state for the existing plant condition, or apply Specification 3.0.3. . Action 21 - With the number of OPERABLE channels one less tnan the Total Number of Channels, restore the inoperable channel to OPERABLE status within 48 hours or be in at least HOT STANDBY within 6 hours and in at least HOT SHUTDOWN witnin the following 6 hours; however, one channel may be bypassed for up to 2 hours for surveillance testing per Specification 4.3.3.1, provided the other channel is OPERABLE. a CATAWBA - UNIT 1 3/4 3-31
kN TABLE 4.3-3 REACTOP,. TRIP / ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INTERLOCKS } h \ E g SURVEILLANCE REQUIREMENTS TRIP hz ANALOG ACTUATING MODES FOR
-8 CHANNEL DEVICE WHICH
~ CilANNEL CHANNEL OPERATIONAL OPERATIONAL ACTUATION SURVEILLANCE FUNCTIONAL UNIT CHECK CALIBRATION TEST TEST LOGIC TEST IS REQUIRED
- 1. Reactor Trip System Interlocks A. Intermediate Ran0e Neutron Flux, P-6 N.A. R(3) H N.A. N.A. 2#
m B. Low Power Reactor Trips Block, P-7 N.A. R(3) M(2) N.A. N.A. 1 3 Y C. Power Range Neutron U Flux, P-8 N.A. R(M M(2) N.A. N.A. 1 D. Power Range Neutron Flux, P-9 N.A. R(3h M(2) N.A. N.A. 1 E. Low Setpoint Power Range Neutron Flux, P-10 N.A. R(5) M(2) N.A. N.A. 1, 2 F. Turbine Impulse Chamber Pressure, P-13 N.A. R M(2) N.A. N.A. 1
- 2. ENGINEERED SAFETY FEATURE ACllm110N SYSTEM IN1ERLOCKS
. A. Pressurizer Pressure, g P-ll N.A. R H N.A. N.A. 1, 2, 3
- B. Reactor Trip, P-4 N.A. N.A. N.A. R N.A. 1, 2, 3
- 3. Automatic Trip Logic N.A. N.A. N.A. N.A. M(1) 1, 2, 3 i
h5 TABLE 4.3-3 (Continued) TABLE NOTATION
# Below the P-6 (Intermediate Range Neutron Flux Interlock) Setpoint.
(1) Each train shall be tested at least every 62 days on a staggered test basis. (2) With power greater than or equal to the interlock setpoint the required OPERATIONAL TEST shall consist of verifying that the interlock is in the required state by observing the permissive annunciator window. (3) Neutron Detectors may be excluded from CHANNEL CALIBRATION. CATAWBA - UNIT 1 3/4 3-33
. TRUMENTATION RAD ON MONITORING INSTRUMENTATION LIMITING C0 ITION FOR OPERATION x 1 3.3.3.2 The radi ion monitoring instrumentation nnels shown in Table 3.3-6 shall be OPERA E with their alarm / trip setp nts within the specified limits.
APPLICABILITY: As shown 1 Table 3.3-6. ACTION:
- a. With a radiation monito 'ng .annel alarm / trip setpoint exceeding the value shown in Table -6, adjust the setpoint to within the limit within 4 hours or are the channel inoperable.
- b. With one or more radi ion mon'toring channels inoperable, take the ACTION shown in bl. 3.3-5.
- c. The provisions of apecifications 3. 3 and 3.0.4 are not applicable.
SURVEILLANCE REOU EMENTS 4.3.3.2 Ea radiation monitoring instrumentation channel hall be demonstrated OPERABLE by ohe performance of the CHANNEL CHECK, CHANNEL CAL. RATION and ANALOG CH NEL OPERATIONAL TEST operations during the modes an at the frequenc' s shown in Table 4.3-4. CATAWBA - UNIT 1 3/4 3-34
4.3-2 (Continued TAB (1) Each train shall ested at least every days on a STAGGERED TEST BASIS. f W-STS 3/4 3-47 SEP 151981
INSTRUMENTATION 3/4.3.3 MONITORING INSTRUMENTATION RADIATION MONITORING INSTRUMENTATION LIMITING CONDITION FOR OPERATION s &gNTA' 3.3.3.7 The radiation monitoring instrumentation channels 4shown in Table 3.3-6 shall be OPERABLE with their alarm / trip setpoints within the specified limits. APPLICA8ILITY: As shown in Table 3.3-6. ACTION:
- a. With a radiation monitoring channel alarm / trip setpoint exceeding the value shown in Table 3.3-6, adjust the setpoint to within the limit within 4 hours or declare the channel inoperable.
- b. With one or more radiation monitoring channels inoperable, take the ACTION shown in Table 3.3-6.
i
- c. The provisions of Specifications 3.0.3 and 3.0.4 are not applicable.
I SURVEILLANCE REQUIREMENTS y .Q,eq\adqud%: 4.3.3.7 Each radiation monitoring instrumentation channel 4shall be demonstrated OPERABLE by the performance of the CHANNEL CHECK, CHANNEL CALIBRATION and ANALOG CHANNEL OPERATIONAL TEST operations for the MODES and at the frequencies l shown in Table 4.3-3. I 4 l 1 l W-STS 3/4 3-48 SEP 15193I
er TABLE 3.3-6 1 l U zn RADIATION HONITORING INSTRUMENTATION MINIMUM CllANNELS APPLICABLE ALARM / TRIP MEASUREMENT INSTRUMENT OPERABLE MODES SETPOINT RANGE ACTION l
- 1. AREA HONITORS ,, l l
- a. Fuel Storage Pool Area
- 4
_ i. CrJticality Monitor (1) < 15 mR/hr (10'I - 10 ) mR/hr &!r '2.8 (A elBrdg ,W "__
"fi^. : :.a". : .. 5,:':- l 5
(E&-20, ur.a.s) 4984eWeft O ***
-(; 2 i :1. 3 ..J) G ? O ) '7- 43= l l L.
^ " *
^
.. . _ 2 -..f
^
ftt' t' 'i 2 L;;1 3. ...l) '; ;[) y, r se
..,.....wo.....,..
. C: .^.. o; avo ' . o ! . . .. . f+t- -*M-H99E6- -(; 2 . i L,. ..J) ';^,'I ; ^* !:" 49 s
[. .'. ' ' . . . . . - . . . ". . a -4.- 1, 2, 2
- 0
) 7:d/'- 1 - ,8 . J ,', 40
$ 2. PROCESS HONITORS
- a. 7 Fuel Stora9e
.. .n.
Pool Area -. to- to (1) ** (< 2 x background) i"g p p q q _4AAaseous T 7:r!:i: Activity
" . ; , ; i.y 44+- *
(T 2 S :d,. ..e (! - ?"5}) cpm :- X 3D 4W-r y c Jr. Containment
- 1. Gaseous s . Activity .
. rm
, ma y 5
- 4. uJb .a u r. . .%. 4 J U' 4 .,; ". : ..
f44 9- t '*'::';:_-.O
'; 12 5
;=
Q){CSLeakageDetection(1) Eau -:!vn 1, 2, 3 & 4 4WW g/A G ?0 jo_got ) cp'm M 27 m rn 11. Particulate Activity O of . w. ys ,. m,,..,....
- -h:: ti: 444- 6.- - P ' - 5:d;. x7.d) G ; 19-o' A K) RCS Leakage Detection (1) 1, 2, 3 & 4 N/A il - !b, c,p,a m M L9 rd (EM-38) ,o_ iJ S l
" With fuel in the storage pool or building
** With irradiated fuel in the storage pool L b, ( drol femm dJs;.14 )/,- 6 2 F b '.Lgrouocl to-lo7 <-Pm 2.7-z_ ALL modes 74 ke,4.sm r A<.h yy -
kni:la4n hsien, %kon (Eet F -V3) j
TABLE 3.3-6 (C i "I RA01ATION HORING INSTRUMENTATION HINIMUM
/.,' x\
CllANNELS ALARHb HEASUREMENT I INSTRUMENT OPERAQLf'/ N00ESAPPLICABLE SETPOINT RANGE ACTION PR S HONITORS (Continued) } c. Noble Effluent Monitors
- i. Radwaste But i Exhaust System 1, 2, 3 & 4 N.A. 1-102 uC 30
- 11. Auxiliary Building l Exhaust System 1 1, , 4 N.A. 1-103 uC1/cc 30 iii. Steam Safety Valve t'
+
Discharge 1/ valve 1, 2, 3 & 4 1-103 uCi/cc 30 T iv. Atmospheric Steam 8 Dump Valve
- 3 Discharge 1/ valve ,3&4 N.A. 1- uCi/cc 30
- v. Shield Building Exhaust System 1, 2, 3 & 4 N.A. 1-104 uC1/c 30 vi. Containment P &
Exhaust S m 1 1, 2, 3 & 4 N.A. 1-100 uCi/cc 30 vil. Con ser Exhaust
- stem 1 1, 2, 3 & 4 N.A. 1-100 uCl/cc 30 Na OB
l. TABLE 3.3-6 (Continued) J. - .1 :-^ 7 :;;;;T: Tesw N0747tah! N 25 - With the number of OPERABLE channels less than the Mi AC um Channels OPERABLE requirement, perform area surveys the monitored area with portable monitoring instrume tion at east once per 24 hours. ACTION 26 - Wit he number of OPERABLE channels less an the Minimum Channe OPERABLE requirement, comply w the ACTION requirene of Specification (3.4.6. . ACTION 27 - With the number OPERABLE chan s less than the Minimum Channels OPERABLE irement omply with the ACTION require-ments of Specification .9 ). ACTION 28 - With the number of OPE. LE - nels less than the Minimum Channels OPERABLE re rement, ly with the ACTION require-ments of Specifica on (3.9.9). ACTION 29 - With the numb of OPERABLE channels less an the Minimum Channels OP LE requirement, within 1 hour
- itiate and maintain eration of the control room emerge ventilation system the recirculation mode of operation.
l ACTION 30 - Wi the number of OPERABLE Channels less than the Min ! nnels OPERABLE requirement, restore the inoperable Channel (s) to OPERABLE status within 7 d ys, or be in at le t HOT STANOBY within the next 6 hours, in at least HOT SHUTDOWN within the following 6 hours and in COLD SHUTDOWN within the subsequent 24 hours. 4 v;4( L[ in 4. -fuel .4,ge area er- M kudh. U wtk lerodiehl fund In %e bal shrage Ares or Su'I Y"$ ACTlon 5}TE.^1CNM yx,,a 29. . oaL w aae & orcasi.e ck ,,alz .na lau -th.,, Iha A,;~.,,. a==ls **s** re.yre 4, JA: L. k*.e asatain. 4* Onirei M Vo*Gl*/<M 5'y*fu.n *~f*M *ir inf*b s;a.k m+< ins L sao(areMe Ins %salnNon. Acrson 2.s -uiA % sse el DMM6wcl.anaal.t less da,, b pmm cIwands CWMGG rupieemaaC aferstna ensy canite.e -for af i n 30 y 6 s fruvided an agrege:a/n forfdio e*olinaeus men,/ee A s,s es~a Aar, sa+,.;a+ ;, pa r lat to 4 Lal pt area. Res% o 6 inayas ,,,,,,'f,,., f, Ms wiWin so A.gs er susynod ad efernhons involying Asl snweaa,,/ ,;, &Q wu.a m - m aisu. ario r.gi_,1 q.as 2.u.i. ACTroA) 30 - OIA k na,nu de Ofersnow ekennalc less #ar. 4/wM% Chsanels Wsensi,,e T*f *'"* eftra$ ton snar confinue pideal .jf, gj 4,,) yy gg5 _
" F ire m c4 utlic lun sl4 9.it aca om.-{,
PSTS 3/4 3-51 SEP 151981
TABLE 4.3-3 "I. v RADIATION HONITORING INSTRUMENTATION SURVEILLANCE REQUIREMENTS ANALOG CilANNEL H0 DES FOR WilICH CilANNEL CllANNEL OPERATIONAL SURVEILLANCE IS INSTRUMENf CllECK CALIBRATION TEST REQUIRED
- 1. AREA MONITORS
- a. Fuel Storage Pool Area
.g y3, _ e i.
z Criticality Honitor S R H l u_ani.:. c...... -
~
(Esf-2o 64r-2.b 3 ~~{iijiQ = ' ~~ p p g a b -- -
" ... L ' -
. -t h : ;..-n .& 45- & Ja.
C:.... o; "::: !'..'.,..
, -f .&. .R. M- "RTT"M00E6 -
D d - i_ .. _ .. f.. -dic & M '.?,21^- T
- 2. PROCESS HONITORS
,J a. Fuel Storage Pool Area - Ven-tilation System Isolat. ion Ak.=h4fy . Hip 1 3 C;;_; ; f.;i!;'*y S R H ^^
ggy qq J8 ......'.t f. i i t, -fr - -#~ 46- *
- b. Containment .
""' N"'T . . ~ . . . . . A. .M. (fm -393 - a d) LCS Leakage Detect. ion S R H 1, 2, 3, & 4
- 11. rIiculate Activity
, :'.g i Ei;_;t Low any h;,' .2 h.. =tir- L =4 l g et.tr) RCS Leakage Detection S R H 1, 2, 3, & 4 (c.rtF- 36) v.
rd ' With fuel in the storage pool or building. f'? **With irradiated fuel in the storage pool. I
TABLE 4.3-3 (Continued) y RADIATION MONITORING INSTRUMENTATION SURVEILLANCE REQUIREMENTS ANALOG CilANNEL MODES FOR WillCil CllANNEL CilANNEL OPERATIONAL SURVEILLANCE IS INSTRUMENT CllECK CALIBRA1 ION TEST REQUIRED PROCESS MONITORS (Continued) Noble Gas Effluent Monitors
- 1. Ra ullding '
Exhaust Sy S R H 1, 2, 3 ii. Auxiliary Building Exhaust System R M 1, 2, 3 & 4 R iii. Steam Safety Valve .
] Discharge S R M 1, 2, 3 & 4 h iv. Atmospheric Steam Dump Valve Discharge S R H 1, 2, 3 & 4
- v. Shield Building Exhaust System S R H 1, 2, 3 & 4 vi. Contairm urge &
Ex System 5 R M- , 3&4
*. Condenser Exhaust System S R M 1, 2, 3 &
L. G l- ( n % l Toem ogy L Ane W , .S L N Q ksa.u, A M;Iy % e\ &.a
'" Spb 'Islab (EhP -43}
A(6 E
INSTRUMENTATION MOVABLE INCORE DETECTORS LIMITING CONDITION FOR OPERATION 3 3.3.3.2 The movable incore detection system shall be OPERABLE with:
- a. At least 75% of the detector thimbles,
- b. A minimum of 2 detector thimbles per core quadrant, and
- c. Sufficient movable detectors, drive, and readout equipment to map these thimbles.
APPLICABILITY: When the movable incare detection system is used for:
- a. Recalibration of the excore neutron flux detection system,
- b. Monitoring the QUADRANT POWER TILT RATIO, or
- c. MeasurementofFh,F(Z)andF q xy ACTION:
With the movable incore detection system inoperable, do not use the system for the above applicable monitoring or calibration functions. The provisions of Specifications 3.0.3 and 3.0.4 are not applicable. SURVEILLANCE REQUIREMENTS 3
- 4.3.3.f The movable incore detection system shall be demonstrated OPERABLE at least once per 24 hours by normalizing each detector output when required for
- a. Recalibration of the excore neutron flux detection system, or
- b. Monitoring the QUADRANT POWER TILT RATIO, or
- c. MeasurementofFh,F(Z),andF q xy*
W-STS 3/4 3-54 SEP 151c81
l INSTRUMENTATION SEISMIC INSTRUMENTATION LIMITING CONDITION FOR OPERATION 3.3.3. The seismic monitoring instrumentation shown in Table 3.3-7 shall be OPERABLE. APPLICABILITY: At all times. ACTION:
- a. With one or more seismic monitoring instruments inoperable for more than 30 days, prepare and submit a Special Report to the Commission pursuant to Specification 6.9.2 within the next 10 days outlining the cause of the malfunction and the plans for restoring the instru-ment (s) to OPERABLE status.
- b. The provisions of Specifications 3.0.3 and 3.0.4 are not applicable.
SURVEILLANCE REQUIREMENTS 4.3.3. 1 Each of the above seismic monitoring instruments shall be demon-strated OPERABLE by the performance of the CHANNEL CHECK, CHANNEL CALIBRATION and ANALOG CHANNEL OPERATIONAL TEST operations at the frequencies shown in Table 44.3-{.Y 4.3.3.2.2 Each of the above seismic monitoring instruments actuated during a seismic event greater than or equal to (0.01) g shall be restored to OPERABLE status within 24 hours 2..d : S/.:,A unuG/ T: .1' ;;"-- " T '. : d:y; following the seisniic event. Data shall be retrieved from actuated instru-ments and analyzed to determine the magnitude of the vibratory ground motion. - A Special Report shall be prepared and submitted to the Commission pursuant to pecificationl.9.21within 10 days describing the magnitude, frequency spectrum and resultant ef_fect f upon facility features important to safety. O te+e:ue/ fr o,-Aa klasta( Sc htslery accAier, r gh shdisclude a es/ crenf cwwsc cassanw sf end w(;l,,./c ch.n immeJiately tw.c .W.,4 (k, Ad,.a J 4ke. ider 4 re~4g b . c4wg4. cAsem@ ska# he pr.4cd h ealia lsty e h e msect-a of Ac new rec.ed;,,genedia n 4 , % ,g 4; g - acce\eeegrapb recoeJec. N sh a cepy olhiseder, CS$we el ALdear Peocice Regulabbn, AHenNon: CbIt b
'S+ruc+ucal a,,d Geotectwicol Enyaecing &anel,, M.S. kc/ea, fept,for.y %, inion, tJashing fon,u zossz
}{-STS 3/4 3-55 SEP 51981
TABLE 3.3-7 SEISMIC MONITORING INSTRUMENTATION MINIMUM MEASUREMENT INSTRUMENTS INSTRUMENTS AND SENSOR LOCATIONS RANGE OPERABLE
- 1. Triaxial Time-History Accelerographs +
- a. iMac Se7e bt. Seos.c 0 -1.gi. 4 Lo 3 1 Coodst.~*+ tins
- Elek ~
- b. iMwr seio e eM G si -t ed. 4 L es I c.ew.mn+ Veues Esev. (,ss'3* * '
- c. -18uwr Soon (S+.rk. 6:4h '
a oesa.o.oss 1 G,rtei. At Sase K M
- 2. Triaxial Peak Accelerographs a.1Mnkr Sot o Coorlainaned 212<. ~ ~1.d. + 2.s 1 tfiev. 4st3' 8 9 /s(, *
- u h.\ dettgr sc2.0 dea 4atawd 314. -2s 4. V2.g '% l Ekv. 363' a vsa *
(, k iri Nr So3e /balltarv B i l,_" - D te+'4" %l Cler. 543'o* ' A K
\ \
- 3. Triaxial Seismic Switches
- a. f tt\MT Soco Cenknia.ned Lse Slab 0.01ss L c.zs, 1*
U W T x r
- 4. Triaxial Response-Spectrum Recorders a.1MIMT 5c% 64.;om? (ks, .5LL o-3844 G 2-154a 1*
% A*'
b.% d.ftIMT seso CoMainen44 6lM o-34, a 1-2.51la 1 g Elev. S74' 3 '/s." y d .h 4 MVtT Set o Aui llacy BlJs. o-34 4 2.-2C Ha 1 g, E kv. S77
- o y "With reactor control room indication W-STS 3/4 3-56 SEP i 51981
1 T9:2 h(ThA TMfr Mvsc.ar opeurmA1. T45T TABLE 4.3-f \ SEISMIC MONITORING INSTRUMENTATION SURVEILLANCE RE0VIREMENTS ANALOG CHANNEL CHANNEL CHANNEL OPERATIONAL f INSTRUMENTS AND SENSOR LOCATIONS CHECK CALIBRATION TEST
- 1. Triaxial Time-History Accclerographs
- a. 1 M Y fo7e b .f, Sens.,. A h M" R SA coetmeameo.+ Bue 56ak b.m.m rear aw, t,._, ai M, R SA g4 c es e.t ws,as a s sov s
- c. w,m seu ts4,a,, un: li M*M4 R SA NA g ceMmM 6ne Skb ge y y
- 2. Triaxial Peak Accelerographs t' a. $tilkT SDIo Ce6 tamed Bl4 NA R NA NA A Elev. 6t3 ' !!i' 9/,6* twt-
- A
- h. A iXIMT So2.o C 44-wed Eth" NA R NA NA 4 Elev. sq 2. Ys a g 4 g c.. % inmT re se h/;,,., S / 4 NA R NA AJA elev. sy s < o r, "
- 3. Triaxial Seismic Switches
- a. 'iniMT Soeo Goeki~.w4-&se 5/41 ** M R GA #4 54 A = +t- % 4A-
%, ** "If" .*- @t-A "*'
& e- &
- 4. Triaxial Response-Spectrum Recorders
- a. MsNT s' o ve dA;J&se Sid ** M R SA NA
%, de e -6A- .
b , i , i M M T S 4ala m c 4 B lJ ,. NA R SA gA h, Elev. S'M ' 3 h" 4W R 64= C. A 4MIMT 5c6,o A u=ilta, v Sl4 . NA R SA gA e.% Elev. S'7.;r. ' o << .NA .e- 9t-
"Except seismic trigger l
**With reactor control room indications. i
/ ' tf W-STS 3/4 3-57 SEP 15 G81
INSTRUMENTATION j l METEOROLOGICAL INSTRUMENTATION LIMITING CONDITION FOR OPERATION 5 3.3.3.# The meteorological monitoring instrumentation channels shown in Table 3.3-8 shall be OPERA 8LE. APPLICABILITY: At all times. ACTION:
- a. With one or more required meteorological monitoring channels inoperable for more than 7 days, prepare and submit a Special Report to the Commission pursuant to Specification 6.9.2 within the next 10 days outlining the cause of the malfunction and the plans for restoring the channel (s) to OPERABLE status,
- b. The provisions of Specifications 3.0.3 and 3.0.4 are not applicable.
SURVEILLANCE REQUIREMENTS S 4.3.3./ Each of the above meteorological monitoring instrumentation channel's shall be demonstrated OPERABLE by the performance of the CHANNEL CHECK and CHANNEL CALIBRATION operations at the frequencies shown in Table 4.3-F.
/,
W-STS 3/4 3-58 SEP i 51981
TABLE 3.3-8 METEOR 0'.0GICAL MONITORING INSTRUMENTATION MINIMUM INSTRUMENT LOCATION OPERABLE
- 1. WIND SPEED
- a. %,,1;J Mekarni
, Nominal Elev. 66I'.so" 1 NW,.t y, I
- b. h,. , Nominal Elev. W o' e " 1
- 2. WIND DIRECTION Ask.
- a. h e% teal ,
Nominal Elev. Mi ole ,, 1 A4<~.t. 3,td
- b. -C ,
Nominal Elev. W o,o f, 1
- 3. AIR TEMPERATURE - DELTA T Ackeorel* ped
- a. -7o" we r , Nominal Elev.76o#- 44 / 'to ^ 1 A , 3:= 5 1 O r.. --A-P W-STS 3/4 3-59 SEP 151981
TABLE 4.3-f METEOROLOGICAL MONITORING INSTRUMENTATION SURVEILLANCE REQUIREMENTS CHANNEL CHANNEL INSTRUMENT CHECK CALIBRATION
- 1. WIND SPEED
- a. Nominal Elev. 6'I ' lo " O SA
- b. Nominal Elev. 'Mo' o #' 0 SA I
- 2. WIND DIRECTION
- a. Nominal Elev. 6GI ' 'O ' 0 SA
- b. Nominal Elev. Wo O SA
- 3. AIR TEMPERATURE - DELTA T
- a. Nominal Elev. D' M*" O SA
- 4. .t. .i ..el Eb. . _
&- Sk l
1 l l l l SEP 151981 W-STS 3/4 3-60
1 l 1 INSTRUMENTATION REMOTE SHUTDOWN INSTRUMENTATION LIMITING CONDITION FOR OPERATION 3.3.3. The remote shutdown monitoring instrumentation channels shown in Table 3.3-9 Shall be OPERABLE with readouts displayed external to the control room. APPLICABILITY: MODES 1, 2, and 3. ACTION:
- a. With the number of OPERABLE remote shutdown monitoring channels less than required by Table 3.3-9, restore the inoperable channel (s) to OPERABLE status within 7 days, or be in HOT SHUTDOWN within the next 12 hours.
- b. The provisions of Specification 3.0.4 are not applicable.
SURVEILLANCE REQUIREMENTS b 4.3.3.s Each remote shutdown monitoring instrumentation channel shall be demonstrated OPERABLE by performance of tne CHANNEL CHECK and CHANNEL CALIBRATION operations at the frequencies shown in Table 4.3-F. 7 W-STS 3/4 3-61 SEP I 51981 l
TABLE 3.3-9
'T "i
us REMOTE SiluTDOWN MONITORING INSTRUMENTATION MINIMUM READ 0UT MEASUREMENT CilANNELS INSTRUMENT tOCATION RANGE OPERABLE o^ r "_n; ".;'_. '
+
- 2. " . . t . ,. J . i " : . m ""c'", rim. ;4 l
- a. S..... " .,_ "::'c +
l l . f. Reactor Trip Breaker Indication 'Reade Trip OPEN-CLOSE 1/ trip breaker
- t. o u o . " _ _ ' : n ' ' ;- -d "- ^ - 4-
- i. - . -u c l { L. Aouv. C,. '_ni "'_ T.... +
m T 1 /. Pressurizer Pressure M .9 544 5-n G 4 *l East 1700-2500 gri8 I
~
- 1. Jr. Pressurizer Level Ail % 5LLn 6 h,( bel o- f oo% I
'f. 7. Steam Generator Pressure Aullia Ve<J-fre Purip o- 1300 (sig 1/ steam generator
^*4=r Ncn4rel fanel
- 5. 16. Steam Generator Level 4;f;,, p ,,j 4 g 1/ steam generator
,, - , n ..__
Acke' Central $nst 1 - -
", .'.'. :. '_ ":- ';; "_ . . L "_ ' ' ' ' " "
. u'::
.-.-_.'E""'""'"
g nnn ri n 7.. 4 en S '2.
.u.n ! .,, . . t . . m + 6. 1(. , Auxiliary Feedwater Flow Rate duobg feejud.c O-loOO gfm I l@ fg Ahc 6dalland 7.TeabcG h,4LoopAA g gg;, sal,_,
M.ty T,.mpembe e.4h.I fc.o,(
,,L ,,.g g
- 8. B<ack Lo(.eV Leerh (S c.tk Leg %yerdww A u ~~
( ste
%I A*"n l',**
( fa,aaf 0- (*5
- F f vo I ,~..,<,./.1,,( oru u m <l..cens ecced..o 4,,,, % i, <LdJ. a paad-
?
TABLE 4.3-g
'T REMOTE SilUIDOWN HONIl0 RING INSlRUMENTATION SURVEILLANCE REQUIREMENIS CilANNEL CilANNEL INSTRUMENT CllECK CALIBRATION
.;: ": ;: "x:: x ; T .K .
4t- .q-
- 2. Pt;. ;Ihi: ";..f,; "r h:r "! = 44- Edir,
- 9. L.. mm
...3 nud mo. T; m 4t- 4M
- 1. /. Reactor Trip Breaker Indication M N.A.
*h ":::?:-
^.o;o... T, ,,- . o m.. ; *xr:;: 46 -R-C. ": :: t:, . "io... Tiu. som & -4 R
- 2. /. Pressurizer Pressure M R Y
$ 3. g. Pressurizer Level M R
- 4. jf. Steam Generator Pressure M R
.5~. Lif. Steam Generator Level M R
" "...;...' ;oo . . ; , ; o.,
^
U -; t . . :. . 46- 4
""" " ; ";;; 4 it-
-12. ;;;;^ Tcym .t . . 46- 4 m
m 4,. )#. Auxiliary Feedwater Flow Rate M R ' 7. %ci., Gelad L.Y A4L - ,g A R m Mhg Tempak 9 6. A .b cot.,4 A g At& "j 1 G'1 led E ,pec. L -e
- sp;0.in L o.s a u not afply.
INSTRUMENTATION ACCIDENT >ONITORING INSTRUMENTATION LIMITING CONDITION FOR OPERATION 3.3.3. The accident monitoring instrumentation channels shown in Table 3.3-10 l shall be OPERA 8LE. APPLICABILITY: MODES 1, 2, and 3. ACTION: - 4
- a. With the number of OPERABLE accident monitoring instrumentation channels less than the Required Number of Channels shown in Table 3.3-10, restore the inoperable channel (s) to OPERA 8LE status within 7 days, or be in at least HOT SHUTDOWN within the next 12 hours.
- b. With the number of OPERA 8LE accident monitoring instrumentation channels less than the MINIMUM CHANNELS OPERA 8LE requirements of Table 3.3-10, restore the inoperable channel (s) to OPERABLE status within 48 hours or be in at least HOT SHUT 00WN within the next 12 hours.
- c. The provisions of Specification 3.0.4 are not applicable.
SURVEILLANCE REQUIREMENTS T 4.3.3.d Each accident monitoring instrumentation channel shall be demonstrated OPERABLE by performance of the CHANNEL CHECK and CHANNEL CALIBRATION operations at the frequencies shown in Table 4.3-T. 8 W-STS _ 3/4 3-64 SEP 15lc81
e TABLE 3.3-10 h ACCIDENT MONITORING INSTRUMENTATION REQUIRED MINIMUM NO. OF CilANNELS INSTRUMENT '"' .. . :... ; 0..?,? CilANNELS OPERABLE
- 1. Containment Pressure 2 1
- 2. Reactor Coolant Outlet Temperature - Til0T ( ide Range) 2 1 1
- 3. Reactor Coolant Inlet Temperature - TCOLD ( ide Range) 2 1
- 4. Reactor Coolant Pressure - Wide Range 2 1 l S. Pressurizer Water Level 2 1
, 6. Steam Line Pressure 2/ steam generator 1/ steam generator s
[ 7. Steam Generator Water Level - Narrow Range 2. X/ steam generator 1/ steam generator i
$ -0 . St :: "--- ': '!:i: L: :!
ii ": .;:
. 0/ L_ ;::::_ L. ;/,L _ ;;.;r:*--
g, f. Refueling Water Storage Tank Water Level 2 1
- 46. L. lm ". 2 ' c '- R ; ; ... L . '.- 9- +
% )(. Auxiliary Feedater Flow Rate 2/ steam generator 1/ steam generator to.)(. Reactor Coolant System Subcooling Margin Monitor iX 1 s r.
)(. PORV Position Indicator 2/ Valve 1/ Valve
# 2. Jf. PORV Block Valve Pos'ition Indicator 2/ Valve 1/ Valve w
g 13.J (. Pros eit.u-3 Safety Valve Position Indicator 2/ Valve 1/ Valve [ li M*. Containment ater Level ( b Range) 2 1 $ 17 "--* 8----*
":t:r L..? O!'t "- ;:) 4- +
p.Jefr In Core Thermocouples 8A/ core quadrant 'lX/ core quadrant M 0FPl ic*Wt tlL amuM Lk wWe n in ne ek.) p,;g.a. u g,y gyllc<ble I(Jhe assocMed ytk. valve u in 4a ye) psbn and e. m ts n , nee d.
8 TABLE 4.3-A y ACCIDENT HONITORING INSTRUMENTATION SURVEILLANCE REQUIREMENTS CilANNEL CllANNEL INSTRUMENT (Illustrational Only) CilECK CALIBRATION
- 1. Containment Pressure H R
- 2. Reactor Coolant Outlet Temperature - Til0T (Wide Range) H R
- 3. Reactor Coolant Inlet Temperature - TCOLO (Wide Range) H R
- 4. Reactor Coolant Pressure - Wide Range H R S. Pressurizer Water Level M R
- 6. Steam Line Pressure H R R
w
- 7. Steam Generator Water Level - Harrow Range H R O. .s scarri deitur dtus usw. [.s u c 's vi s uu .S o . .u- O 8)f. Refueling Water Storage Tank Water Level M R Au. nu n e m.iu !...k Ex h tie - ' c 1 0 - .
44- 4
'l 1/. Auxiliary Feedwater Flow Rate H R
/O. 3/ 'aactor Coolant System Subcooling MarDi n Monitor M R 14 ]#. PORV Position Indicator M R
- 12. k PORV Block Valve Position Indicator M R Passuct ve u> 83.lK 3 Safety Valve Position Indicator H R l
l.9w t
-. 4u. t o n t o . .,.. . . 1 _ _ . ' -
Set'
' ' ." . . _ .. ._..,_} M- 4-rg; NM Containment Water 3 Level (Wide Range) H -
R EM. In Core Thermocouples H R
_ :. ,6 INTRUMENTATION CHL NE DETECTION SYSTEMS LIMITING C DITION FOR C.0ERATION _
/
3.3.3.7 Two ind endent chlorine detection systems, with
/eir alarm / trip setpoints adjusted +o actuate at a chlorine concentratio of less than or equal to 5 ppm, shal be OPERABLE.
APPLICABILITY: ALL MOD." ACTION:
- a. With one chlorine de ection syst inoperable, restore the inoperable detection system to 0 'RABLE st us within 7 days or within the next 6 hours initiate and ma tain/perationofthecontrolroomemergency ventilation system in the etirculation mode of operation.
- b. With both chlorine dete- ion vstems inoperable, witnin 1 hour initiate and maintain peration of the control room emergency ventilation system i the recirc ation mode of operation.
- c. The provisions o Specification 3.0. are not applicable.
SURVELLIANCE RF UIREMENTS
- s 4.3.3.7 tach chlorine detection system shall be demonstrated ERABLE by perfo .ance of a CHANNEL CHECK at least once per 12 hours, an AN OG CHANNEL OPE IONAL TEST at least once per 31 days and a CHANNEL CALIBRATI at least o per 18 months.
l O W-STS 2/4 3-67 SEP 151361 a%.._....--.... - . _ _
INSTRUMENTATION < FIRE DETECTION INSTRUMENTATION I l LIMITING CONDITION FOR OPERATION 3.3.3.8 As a minimum, the fire detection instrumentation for each fire detection zone shown in Table 3.3-11 shall be OPERABLE. 6 & d m O
- crea ptaSrd APPLICABILITY: Whenever equipment p etu tcd by the fire detection instrument is required to be OPERABLE.
ACTION: 5 the number of OPERABLE fire detection instrument (s) less than the mum numbe ERABLE requirement of Table 3.3-11:
- a. Wit I hour establish a fire watch patrol to i ect the zone (s) with t inoperable instrument (s) at least a per hour, unless the
~
instrument is located inside the cent ent, then inspect the containment at st once per 8 hours (monitor the containment air temperature at t once per r at the locations listed in Specification 4.6.1.6).
- b. Restore the inoperable i rument - o OPERABLE status within
(/) 14 days, or in lieu any other repor auired by Specification 6.9.1, prepare submit a Special Report u he Commission pursuant to Specific +' n 6.9.2 within the next 30 days o 'ning the action Q taken, + cause of the inoperability and the plans- schedule for j j res+ ing the instrument (s) to OPERABLE status. The provisions of Specifications 3.0.3 and 3.0.4 are not applicab SURVEILLANCE REQUIREMENTS
' ' 8.1 Each of the above required fire detection instruments which are accessw. uring plant operation shall be demonstrated OPERABLE at 1 . once per 6 months , rformance of a TRIP ACTUATING DEVICE OPERATIOP ' CST. Fire i detectors which are . accessible during plant operation be demonstrated
( OPERABLE by the performa1 each COLD SHUTDOWN exceeding 2*
- a TRIP ACTUATING DEVIC eRATIONAL TEST during s unless per* ...ed in the previous 6 months.
( 4.3.3.8.2 The NFPA Standard 720 superv' ~--uits supervision associated with the detector alarms of each of ...e above req d fire detection instruments shall be demonstrated OPERABLC 6 least once per 6 man. 4.3.3.8.3 The non - vised circuits, associated with detector a ' ms, between h I the instrumen once per . days.
.d the control room shall be demonstrated OPERABLE,at st W-STS
_ 3/4 3-68 g . 5 19 31 amae,, e m -._2__ u - - - --
DUKE POWER COMPANY Form 00184 (6-81) Dev./ Station Unit File No. Subject By Date l
,I ' ' Sheet No. _of Problem No. Checked By Date l ,i !
j .
! j I ! l i l I l
, i i !
- l : i' !
' l l I l l l l ! ! l; I
_j a i 1 1 j i , ACTION: ' + l I I' ' 2 i
' } .! ;; a. ;i With any, but not more than one-half the total in any fire zone, I ti ' Function A fire detection instruments shown in Table 3.3-11 ! !
it
' inoperable, restore the inoperable instrument (s) to OPERABLE statut within 14 days or within the next 1 hour establish a fire watch i l
l
;, patrol to inspect the zone (s) with the inoperable instrument (s) at ! - i least once per hour, unless the instrument (s) is located inside the lI containment, then inspect that containment zone at least once per -I p. !! ,j 8 hours or monitor the containment air temperature at least once !
ll per hour at the locations given in Specification 4.6.1.5.1 or
,t ii 4.6.1.5.2. ;
i
;i ,
- b. -
l j' i With more than one-half of the Function A fire detection instruments ; i
' in any fire zone shown in Table 3.3-11 inoperable, or with any j;i Function B fire detection instruments shown in Table 3.3-11 i
' inoperable, or with any two or more adjacent fire detection A instruments shown in Table 3.3-11 inoperable, within 1 hour !
{i ! i
! j ,', establish a fire watch patrol to inspect the zone (s) with the ' '
t ' inoperable instrument (s) at least once per hour, unless the $ i i instrument (s) is located inside the containment, then inspect that i jf t containment Zone at least once per 8 hours or monitor the contain- l I l ment air temperature at least once per hour at the locations given I i ! h. in Specification 4.6.1.5.1 or 4.6.1.5.2. ; i i I c. , The provisions of Specifications 3.0.3 and 3.0.4 are not applicable, , , i j , ;;;;! ' ' i ! ' ' i
! l i
! i i i
! i l I i !
I I l l i I ! l i , , i l i i ! ii ! ! l i i ! i i l : i ! l l l i I t I i ! i i l i l. j l l! ! l i i ! ! , I l ! i I I ! I i ! I i ! if l ii i i ! ! i ! l ! i I I I l ! l ! i l i !l l l ! F ! !! l l Iii l l ! I i i
! i l l l l l l l l l l ! I d
p i i l ! I i I i ! ! I I I. ! l! ! l 1 I ! I I l l l l I! l l l ! l !! ! I ! l l l l i l l i. l i i > i i ! 4 I i . t i i l i ! ! l l i I l i ! ! : i l l l l l l l I I l l ! l ! l ! ! ! i l : i l l l i ! n i ! : : I !
! l i ! !! l I I ! i !
t ! I i i, I ' ' ' ; : i
! i ! ! ! l ! ! ! I i : ! l ! l l l l l l i H l l ! ! !: ! -
i ' : l i l : ! ! l ! ! l ! ! ! ! ! l l l l ! i i i j i i - i !
! !! l l ! i i I i i ! l l
l ! ! ! i i i l l i l . I I I i i t I I i ! i ! - i _ l l d: i i I i i i i i i i i : i ! l ! l l , ! i j i I , l l !l
l 4.3.3.8.1 - Each of the above required Fire Detection Zone Circuits shall be demonstrated operable at least once per six months by performance of an Analog Channel Operational Test. Smoke Detection Instruments shall be demonstrated operable at least once per six months as follows: A. For Fire Detection Zones containing 1-15 Smoke Detection Instruments, Test one Detector per Zone by Performance of a Trip Actuating Device Operational Test. B. For Fire Detection Zones containing 16-25 Smoke Detection Instruments, Test two Detectors per Zone by Performance of a Trip Actuating Device , Operational Test.
. Different Detectors of each Zone shall be selected for Testing at each ! Test Interval until all Smoke Detectors have been tested. Smoke Detection l Instruments which are not accessible during plant operation shall be i demonstrated operable during each cold shutdown exceeding 24 hours unless performed in the previous six months as described above.
4
#d Each of the above required Heat Detection Instruments shall bc
,,( demonstrated operable as follows:
$ . A. For combination fixed Temperature / Rate of rise Heat Detectors,
>* demonstrated the rate of rise function operable in accordance with the
%r Manufacturers Instruction by performing Trip Actuating Device Operational
,,, lests. At least one Detector per Fire Detection Zone Circuit shall be selected per six months. Different Detectors shall be selected for each g3
. Test.
Pi h4 The rate of rise function of Detectors not accessible during plant 93 operation shall be demonstrated operable in accordance with the Manufacturers Instructions by performing Trip Actuating Device Operational Tests during each cold shutdown exceeding 24 hours unless performed in the previous six months. At least one Detector per Fire Detection Zone Circuit shall.be L4- selected and different Detector should be selected for each test.
~2l After the fifteenth year of Detector Service and every five years
$2 thereafter, verify the fixed temperature Detectors function properly by
\= removing at least two Detectors per hundred, or fraction there of, and N
W transmit the removed Detectors to a nationally recognized Testing Labcratory for tests. The Detectors which have been removed shall be replaced with new di Detectors. For each failure that occurs on a removed Detector, two additional
'Y(
Detectors shall be removed and tested. i B. For Line-typed Heat Detectors, measure the loop resistance of each i Detector in accordance with the Manufacturers Instructions at-least every six months. Line-type Heat Detectors which are not accessible during plant operation shall be demonstrated operable by performing the prescribed test during each cold shutdown exceeding 24 hours unless performed in the i previous six months. Each of the above required Flame Detection Instruments shall be demonstrated operable as follows: A. For Flame Detectors, perform tests on each Detector as prescribed ! by the Manufacturer at least once per six months. 4.3.3.8.2 - The NFPA Code 72D-1975 Supervised Circuits associated with-the Detector Alarms of each of the above required Fire Dection Instruments , shall be demonstrated operable at least once per six months.
'X (f I i TABLE 3.3-11 FIRE DETECTION INSTRUMENTS INSTRUMENT LOCATION (Illustrative **} MINIMUM INSTRUMENTS OPERABLE
- HEAT FLAME SMOKE
- 1. Containment Zone 1 Elevation Zone 2 Elevation 1
- 2. Control Room l
- 3. Cable Spreading Zone 1 Elevation Zone 2 Elevation
- 4. Computer Room
- 5. - Switchgear Room
- 6. Remote Shutdown Panels l
- 7. Station Battery Rooms Zone 1 Elevation h*. i Zone 2 Elevation
- 8. Yurbine '
Zone 1 Elevation Zone 2 Elevation
- 9. Diesel Generator Zone 1 Elevation Zone 2 Elevation
- 10. Diesel Fuel Storage .
- 11. Safety Related Pumps Zone 1 Elevation Zone 2 Elevation
- 12. Fuel Storage i
Zone 1 Elevation Zone 2 Elevation "The fire detection instruments located within the Containment are not required to be OPERABLE during the performance of Type A Containment Leakage Rate Tests.
"" List all detectors in areas required to insure the OPERABILITY of Safety related equipment and indicate instruments which automatically actuate fire suppression systems.
W-STS 3/4 3-69 SEP . 51981 C_^ _m -
I n INSTRUMENTATICH RADICACTI'IE LICU D E: L'JENT INSTRUMENTAT'.CN LIMITING CONDIT'ON FOR OPERATION a. 3.3.3.89 The radioactive licuid effluent monitoring instrumentation l channels shown in Table 3.3 . shall be OPERABLE with their alam/ trip l setroints set to ensure that the limits of Specification 3.11.1.1 are I e.mehe ulfa 4Ke ubl4togy and pramfers e & emme DWnot exceeded.Tw ab +c.f s cd'cuurras ,*ubm (ome4, 2-APPLICABILITY: :': - '- '
^':'....
ACTION: 1
- a. With a radioactive liquid effluent monitoring instrumentation g& channel alam/ trip setpoint less conservative than h
"'I g iPc3 p *
]g ^)
_ W -'?" .m... . :: . . . . . ' ' ' u c ' : .1. . . . . . . % i mm e-diately suspend the release of radioactive licuid effluents monitored by the affected channel or declare the channel in-operable. h b. - . :' : ; .. . . . . _d':::**": ' f ;. . . . T 7 . . . . ..~ . : L. .. - c u et ;; :': : :- ;;; ' ;;: ::':, 2::: -': ' ? ~ ? " c ' '-
- : . u,_ , ,.
- -- " ~ ^
ed I,.9.l.13 b p, c. The provisions of Specifications 3.0.3,.ese3.0.44are not g apol icable. E. .
! SURVEILLANCE REOUIREMENTS
] ' . ^ . ^ . C . . -" . . ;; 2 : ' t : '-1'.
.. _ .... .o w.,,,...~.
- ^ '
.. . ,. . . . : c ; ;
.C^ I: ^; .
ana.'
..w o .os wi.A,.7 c. r . u .. . . - . . I ' C ; i . .. . . . . $ 1 3 s 4.3.3. ( AW404 cwxW62. OPsegnm, Each radioactive liquid effluent monitoringl instrumentation channel shall be demonstrated OPERABLE by perfomance CHECX, SOURCE CHECK, CHANNEL CALIBRATION, and """""' "of the CHANNEL
'J"C : ^ : " ' TEST.
operations .. . .., 1 M^;;; .mv at the frequencies. shown in Table 4.3(. 2 . , ...
. 2, ._< ,_
/ 2.
.wW M . V . .# T E '* Fi .. --- - - . -ww -...=..g gf G illQ e e e gg a y rg w g 8 44 .,,,i.gg3g,
, . . .c Tb and 3ag hl i E i GQ 8 V Gh h 5 Y C 4 8 QM i qd .
'Z- ....wusa' wi.4Vu al un C...
^
l "^"! , ..
^
i ^^ " " ""*'*4"t j . .1,.n i .r ..r.. ...
.+4---
ch.99 _;_, '* '*; +;., _ , _ ,, a' 7 7 7'; * > > ;; g
"^^;'..., C.....'.1 ... _t.
PWR-STS-1 3/4 3-44 t I L)c4 im u\ces M on bn Oc m% wder ef codiac.41n.t h ud EM"8^b mon;Ior'T cus waane, we o Acnoo theva in 72e c.t-tz. ksbe .Ae inerer.Me indrunentM on 4e of6EA64.E ddus udA'n 4he fiac. spe h be ACI'304 or, in litit of a licensec 6VeM- Reped ) cr.p(4/ninffmeg[ Senand %ltosdie Ebed Ve%as< Tegock uk 3 4;S unegges;l;/y w.r
& coceeded unELin he 4rw sfeed d.
t~t-y TABLE 3.3- R 3: P RADIOACTIVE LIQUID EFFLUENT MONITORING INSTRUMENTATION n
- l T.-
INSTRUMENT OPERABLE " ""' ' "" ' L : !'.' - ACTION
- 1. Gross Radioactivity Monitors Providing Automatic Termination of Release
- a. ga,}c,
>i-"i*L;p"j bish.7"<
" r t- '"^-t/haller L.._ (.E'rfF-e\ (1) ".; ;; ; : . . ;- W ZB (1) "; ; ? t! : _
. 49-ffftet'mMMme-b (. Turbine Building 7 :;;. Sr ' ;) (1) " :!! ti :: _ h 2f!
Sumpf " ... '.in;" Aon:1.c (E4F-Dh R. I'2. Gross Radioact!vity Monitors N Not Providing Automatic Termination of Release Jhe.\e<r
- a. 4 Service Water System Effluent Line (.E/F- Ms A4 6 (.64,0) (1) ! ' t l -,- 20
- b. Component Cooling Water System Effluent Line (E4 4b A46 11 4 (I) '" " ' ' " ~ , - 20 upt cl.ses Kc. wqe f .k. v,ed vedveQ 2 im. i uuc t r i nas , G..n, onu . ; .. . , .. :: . . i um a c w. .. . . , :y:": ::xf::: *^ ?_ ,. .. utm...s..;.tc, u, ' ' ! !; . ---
mum i nu, o . .s. m
- 2. (edir.uous (e r.s t h. 6*NLr ..d Sm tu. Vlw PM b e- 2)
- a. f-awh.~t uak Lajee Trealn.el- tsau. \
- 5. Flow ? 3c A<ase a4 hv tee.s
- a. (Ja s k uguid E Went- L u 1 b . rea<cnh.J Uas t<. tu.b Tn l=4- L'a=_ ' b
II TABLE 3.3-Jf (Continued) [ RADI0 ACTIVE LIQUID EffLUENI MONiiORING INSTRtNENTATION MINIMUM
,L CHANNELS INSTR OPERABLE APPLICABILITY ACIIDH
- 3. Flow Rate rement Devices **
I
- a. Liquid Radwaste f. Iuent Line (1) At all times 21
- b. Discharge Canal (1) At all times 21
- c. SteamGenerator810wdownEffluebg Line N,,
(1) At all times / 21
/
- 4. Radioactivity Recorders x
- a. Liquid Radwaste Effluent Line*** (1) N'A6 11 times 23
$ b. Steam Generator Blowdown Effluent Line 23 u
E
*5. Tank Level Indicating Devices ****
(1)/At
/
all%imes (for tanks outside plant buildings)
/
- a. (1) At all times 22 b.
c. (1) At all times \ 22 (1) At all times 22
- d. ,
(1) At all times 22
/
*aPump curves may befdtilized to estimate flow; in such cases, action statement 21 is not required.
*** Required only ! alarm /tripsetpointisbasedonrecorder-controller.
****Not requi for tanks which have dikes or retention ponds capable of preventing runoff in the event of a tank ov low and have provisions for sampling collected liquids and routing them to a liquid radwaste treat t system.
h TABLE 3.3-11 (Continued) U Y' RADI0 ACTIVE LIQUID EFFLUENT HONITORING INSTRUMENTATION MINIMUM CilANNELS INSTRUMENT OPERABLE APPLICABILITY ACTION
- 6. Continuous Compo itq" Samplers and Sampler Flow Monitor
- a. SteamGeneratorBlowdowba (1) At.a 1 times 19
, Effluent Line g%g
- b. Turbine Building Sumps Effluent % s(1) , At all times 20 l Line* ^V w
/ '%
/
h / , N,
/
.s
/ - N r
- Includes rinse, flush, and slurry waste from secondary system condensate deep bed dem heralizer er f11ter-demitieralizers.
N
\
I t M Tne ehas el }/e com man.a[p%
}><&ewd n1 camputre e,.putee inpd -lor Ne coluse ab calc L1.) The edire. relute rale edcdalrw s*E.ruch calcaldm pa,re perhored
###"##h- TABLE 3.3-lrQ 7, (Continuec)
TABLE NOTAT:CN 2b ACTION X With the numoer of channels CPERABLE less than requirec oy the Minimum Channels OPERABLE requirement, effluent releases may to ce,4tu assumes for up to la cays, providec that prior to 111tiating a release: 1 A1. At least two incependent amoles are analyzed in accorcance with Specification 4.11.1. . , ana; b7 At least two technically qualified memoers of the racility Staff incepencently verify che ese disenarge g valvinglard uoc - - O;therwise, suspend release of radioactive effluents via this pa thway. m; . , . . . . . . ~ . ~ . . . . . d-
. .' . . ; - : ' ^ o e *
- r ' - - *':- :;_. .. , -'
Channels CPERABLE requirement, effluent releas Inis pa continue for up to 14 cays or d
. rao samples are ana .,
a ross radioac* ' tmeta or gamma) a1 a limit of detection of a. ** uCi/ gram; L. At least once nours when the . 4 fic ac*ivity of the seconcar tant is > 0.01 uCi/ gram DOSc ENT I-131, 2 s east once per 24 nours wnen tne soecific activity . seconcary wav. n. ia ; .s. ..,3. suac cvui su.si . .;', d 17. 30 ACTION M With the numcershof channels OPERABLE ess than required oy the Minimum Channels ,0PERASLE requiremen , effluent releases via this pathway mayj continue for uo to cays proviced thatj at least once per K hours gran samples are collected and analyzed for gross radioactivity ( detection of at least 10 geta or gamma) at a lower limit of uCi/ml. ACTION N With the numoer of enannels OPERABLE ess than required oy the Minimum Channels OPERABLE requirement, effluent releases via this pathway may continue for up to days provided the flow rate is estimated at least once per 4 hourg dyring actual releases.Le cwn m be uel 43 4.shmait.+lo< s . m CE sn uw :t 2: -r : n :f c.; . :' : Oar"'l : .n on n . . . . r w -ha 1 n =um cnannei s vn.tvwd rCyuirement, eiouia_aouicivu. A {- ,
}_.., -ai y .. . . : n..
.'. . u, ou co cays proviceu w.
wu aur i ng . . . ..wo.w auuieiuns
.a
-eent~
nCH un ca n . un m
.....,.w. wnannui s unemou .... .. .; n . . ., . . . , w
~
M4 4 7 N _ . . .;'. ; ^^Ca ""'l ..
, . .. a . m .. . ,,. ...-. , - ,., . . . . . . _ _ .. .,
- 7;d]=y + * *'.w' " ,-. wa. y. . . . ,n......-
esvia
"" " ~ E , e uu.vc6ielV3if 6CVC. Ib iUbWFMCU G. 6 E4. w i r. s y.. -
2 ' ^ ^ _. , ......, .,....I - '::^^_ PWR-STS-1 3/4 3-48
/2-u TABLE 4.3-X !O - ?.
RADI0 ACTIVE LIQUID EFFLUENT HONITORING INSTRUMENTATION SURVEILLANCE REQUIREMENTS IA AdA to 4 (llANNEL CilANNEL SOURCE CilANNEL ftNteMONAE- oNedenML INSTRUMENT CllECK CllECK CALIBRATION - TEST
- 1. Gross Beta or Gamma Radioactivity Monitors Providing Alarm and Auto-matic Isolation s.ksk ligaid t>mlioma h.*: lee (ExF-14)
- a. ' "; 0 4 "_.f.. .;e C ri;....;., L ;..
. - DX. P R(3) Q(1)
' . . S;; . ^ .. .asui sio ,uumi Eii! ..; 8*- M-
- L '. ;; 4 tit) .QR) g jf. Turbine Building F '.... u..... } D/( H R(3) Q(1) w Sumpf ':ff t ;;t ' ':: k;b &w.3h W
- 0. "re:: ?:t : "1__ : :d ::;;;, , if w
fkmtte n Fiuviu..,3 Aioim 0 , k. h
.".;.'d';; ". * --*ie ' r ? ; .u.. o
- e. St. .;m. '.'; i; . "., ;;... Ef f L ..; L ;,ic . ear M- -- R(3 q(it
- u. h- ..uiicis t cooinig5piom Tf!;;;i - D*- -ff- -29)- n(7}-
. L 'n:-
- 3. Continuous Composite Samplers and Sample Flow ."a. . - - - ..i :. . ':: ri.a.4 c~n%t vask Ube%ked-L;ae
- a. Sicom ;;.c. :t:.- "?r::5.: E f f i.m... DK. N/A Jt'N.f . Q ttfie-
- 4. ! . ;,:.. " ':I' ; Gw Fffb.^
- 96 -ggfA- 4 g b4ne
Ib
, y TABLE 4.3-Jf (Continued)
Y i y RADIDACTIVE LIQUID EFFLUENT MONITORING INSTRUMENTATION SURVEILLANCE REQUIREMENIS T
~
l
, CllANNEL CilANNEL SOURCE CilANNEL FUNCT10NAL INSTRUMENT CllECK CllECK CAllBRATION 1EST I
- 4. ,^d i.;i f ";;;.is . (0) ,
-- ; . Liyuiu hauwaste u s iuers ' -^ -U n.a. "
Q .
-t . S t r r C;..;; ;;;;- 9 6 ~%q lfm.asi Line "
".*. A yw
, nie,.s.2 e ,." 1
,m
_ C N.A. n 1 Y b I uk Luvs$ .vss 'ius a ( c. I'"b' a 8 ;;d.iue tne building) (7) al A' U N.k.
}
l . D.
- N A. I t
C , D A h A. I d D A.
,A Nj d pancema4 W ees
- 6. Flow Rate 44eeMere 9
a . @_5f N ; ?l'if..'d
.. d
. ;e Effluent Line D(J) N.A. R Q wa,n.t as v6 Q___c___.^-
- - - - - - - " ' " - D N A- R Q n
Te%.64- tJo<. c. Discharge Canal f w . . [(.o D N) N.A. # a.4. Q h ttet.ck.
TABLE 4.3-X (Continued) TABLE NOTATION
- i. ' .; . : smm. .._ th i ., g. ' ,
'-- a" ::::;;_.; C tt: ' ' ' '
.., u .
.w 4W opccAvien (1) The4CHANNELfM$frMeet TEST shall also demonstrate that automatic isolation of this pathway and control room alam annunciation occurs ;
if any of the following conditions exist: 1
- 1. Instrument indicates measured levels above the alarm / trip setpoint. , l
- 2. Circuit failure.(Nm. only) 3
- 3. Instrument indicates a downscale failure (h *ty) j
;;..........,;.;,-.;;--+4" --^-'+a =^d" A A) ALO G g7gg (2) The CHANNElf""CTIWL 3 TEST shall also demonstrate that control room alarm annunciation occurs if any of the following conditions exist:
- 1. Instrument indicates measured levels above the alarmpeng.
setpoint.
- 2. Circuit failure.
- 3. Instrument indicates a downscale failure.
l l :. : . . . . . .. . . . . . . _ . . . . : ' : :t x t ' :;:- +- ---- l (3) The initial CHANNEL CALIBRATION ':- ::' ' ' ' '" r r _ r;.. '- e4eememeenm shall be perfomed using one or more of the reference standards certified by the National Bureau of Standards or using standards that have been obtained from suppliers that participate in measurement assurance activities with NBS. These standards ehendesbil pemit calibrating the system over its intended range of energy and y,,_4-rog--> ._;_ ._,_ . iti::. have been related to the initial calibrationFor subsequent CHANNEL be used,.e h CALIBRATION,
-- ,: .: .; , - - + - = . ;fr---- m.~--,,; ::
2-^^ ;'i..... .....3 . 7..I'~.; ..t_,... Y i ti- ; 7 ' '- * * - - __. ,
.tt...e g . m . ,. v u a b . . .. ., ' . . . .. . . 1 : _ - - ' ' - - - ^ ' " -- #^ - *hi*
_ _ . . . . . . . . . . , - - Qskalj
&n LWEL. Met Ao con +sk of veAlying indihn of Ru Lesq p<riod.reSn$"te-c4wam. csae dog be. wl, .4- l=s4 ence per- 24 k.cs on dy e4 @
O ueul,pt.riecl/t,oc hf e k r* l** scs at't. mAsle . l PWR-STS-1 3/4 3-51
- 'C. 2.3.?;
,,L" 2 " * ' ~ u ?
(4 . requirement is applicable only to systems where the service wa ter m or component cooling water system is discharged to effluent str. . (5) CHANNEL CHECK shall ist of verifying indic n of flow during periods of release. CHA - ' CHECK shall b .ade at least once daily on any day on which continuou , ' rio , or batch releases are made. (6) This requirement is appi .e only to sys... where an alann/ trip action is performed ecorder-controller inst nta tion.
. (7) This requir t is not applicable to tanks which have '
s o r re-tention nds capable of preventing runoff in the event of
- nk ova ow and have provisions for sampling collected liquids an outing them to a liquid radwaste treatment system.
l l i l l i i PWR-STS-1 3/4 3-52 t
INSTRUMENTATION RADIOACTIVE GASEOUS PROCESS AND EFFLUENT MONITORING INSTRUMENTATION LIMITING CONDITION FOR OPERATION e- t.s 3.3.3.s!D The radioactive gaseous process and effluent monitoring instru-
- mentation channels shown in Table 3.3Mshall be OPERABLE with their
. alarm / trip setpoints set to ensure that the limits of Specifica-ition 3.11.2.1 are not exceeded.% .Jw//r,j .,/a,soh f ./ Ac cli e/.s r/e//kde/teda</
(;aed udJinuudan< win #<m<%dl gy a p ,su,,.n & e m .
*APPLI ABILITY: As shown in Taole 3.3 13
!. ACTION:
'etW e'l k3 b *b" a. With a radioactive gaseous paeseasie effluent monitoring in-p,.;/;../wi,imdM g ~
trumentation channel alam/ trip setpoint less conservative 9 d de edur< d a .c-/ w p ic a r e/Macds
\ than,: .;'. t.f:P .....m uno 6 w. m ; un . 62 vi S. ..^..
m . m ., declare the channel inoperable.
,. 4,e1 J,y se o less h A 4 e=~ b w kee of h"#f # -
, b. With a - radioactive gaseous ,meeeeper effluent monitoring instrumentation channels inoperable, take the ACTION shown in Table 3.3-M.
59 ..d(..i.l.t% ( I -
- c. The provisions of Specifications 3.0.3p 3.0.4gare not applicable.
SURVEILLANCE REOUIREMENTS
'. .0.^. T. .rw.o . :h;' ' i; d; t,. .
..;d
.. .j : : ith,r;...d.. -
_. . ...uvu m wm vuun anu 2.m.. - . . . . . . . . . . . , . . . . . . . . .
.to AuMa4 onurrenAn.
gaseouseffluent m toring instrumen-l l '4.3.3.3et ltation channelEach shall be radioactive demonstrated OPERABLE ;- z :q(by perfomance of the C
' CHECK, SOURCE CHECK, CHANNEL CALIBRATION, and" CHANNEL ""01"".' TEST opera-tions fr'n; th; I'^Z: ...J at the frequencies shown in Table 4.3-X. G A 2. 0. ^ . ^ nu o ?.;t ' ; :; - -d - c': i: T. . . U n : d ; f ^.. .. . '. . . '. . . m . . .... d : ,
Tb [.. : 4a : /5.,' - - [ l .t;
} [:'- ;.dur apeciosaw. .
i,
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...wa
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kkre. &
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.ge;(icJ.Wt6a&he Eeprf 4 As ;o9nJ;f;fy ums oc4 w;As cecredc4 w ,J @,,(,,
;44 fla c J.
PWR-STS-1 3/4 3-53 i l i l
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c V - v I 3 i ^ f T r a . r 3 g s . . r C o. e e h o . . o A t m t t , l .. . t D u a p . I D i%)C n . i i R u a x i n o o sI . w u E . A Hr - . s. . .% , M R m e yP t . o . m' e' . . n t t J. M . o i l F t m e iJ,.E u . 2 . s t e t se . _ . r g S y i vA 0 . mc ei b u Ss yt . . .
. t o y x
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; er s . . g 3 s
a e 3s . uu . s st o . l a 1 l s . . ai o- r b%l . g G e . Gn c ., - T e
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; EH ..
m t eH, 3 l l rf M s
.e e ss .
u a . . . aa . . . t i T W a s 4 s WG _e. a b S . . N . [ I 1 b 2
,rn a._. n ./
E w < w *~
- 1. (d.arer Em{ con fyrle,w
- a. a.WGs M.v ly %%- 1 p- 37 (Am-nb 13 TABLE 3.3-Jf (Continued) i f n
RADI0 ACTIVE GASEOUS EFFLUENT MONITORING INSTRUMENTATION T
~ HINIMUM CilANNELS INSTRUMENT OPERABLE APPLICABILITY PARAMETER ACTION Waste Gas Holdup System Explosi nitoring System (for ems not desig to withstand il fects of a hydrogen e sion
- a. Hydro fe} ^
nit T ";&c;cn- g b ydrogen or Oxygen Hon e r -(e}- .5 ..,u. vgn or uxygerr '- 3t'r t{ [. Cy 9~ .gc wu Lur aug ays Lt5n [ a. Noble Gas Activity Monitor (1) * ^
.. ..m ..'t) ";tt 'fr 31 4
un am-30 ,
, ~ . . . . . ~ . .
- b. Iodine Sampler O rt 'd;; (1) * n ' f.,
. ,,. m..a of 34 90 (ca.9) c=r+ 8_g
- c. Particulate Sampler filts (1) * .m. isy v cacnss. ;f ' ti.
(cm-153 ,a4 yo
- d. -... -... .,_ _ Flow Rate Aalbe (1)
- ayt u:m i; . ".;r ,Jfr %
1 . ., '.. 3 .Os..su- -1. 2 . ... . . i
- e. Sampler Flow Rate D r _r'03 (1)
- 9eftee p o b
- S ony . m. ' h.. ".;t; efr 36
. ~ . . . . . . ~ . . .
I. l b!4nmesv-l- T 4 hC l 6 Ak % Ga A h ;ly k <% - % iJ13 Ahu..,j l s. 3B j Maheba./,. 4 falcare (fxA-3gw.sg L. AJiar, $s t);ag y[;lak Sy,},, s ~+
- a. p.% s., as;<iy 8..ac cerer-ur, enc s4 1
'l. G.\51.<3< Ace s A;k-1,sn Sys k g
- q. AW 6 s Ad;vily / bike (EM.92,EHF-30 I
pABLtM;3:12'(conLiiiued)
$ RAD N .IVE-GASEGUS Effluent MONITORING"INSTRUMENIAfl0N ?>
L! 4 MINIMUM CilANNELS INSTRUMENT OPERABLE APPL.ICABILITY ARAMETER ACTiott
. (See list below)
- a. Noble Gas Activity /
Monitor (1) Radioactivity Rate Measurement 2/
- b. Iodine Sampler Cartridge (1) /* Verity presence of cartridge 31
- c. Particulate Sampler Filter (1) /
- Verify presence of filter 31 2
y d. Effluent System flow /
/
o Rate Measuring Device j(1)
- 26
{ystem flow Rate Mirasuressient w , Si
- c. Sampler Flow Rate ,/
Measuring Device ,' (1)
- Samp flow Rate Measureisiesit 26
/
f N (a) CondesjsirEvacuationSystem (b) Vent lleader Systesse f
)' Auxillary llullding Ventflation System -
j (d) fuel Storage Area (llullding) Ventilation System
, (e) Radwaste Area Vesitilation System
,/
(f) Steam Generator Blomlowa Vent System
/(6 % M {1r%o eS condu intd $ar k es\ene. od< <alcAdus 74.,f,,,,j, , L l
heub , e e-UA .h enb ede re oxle. edudabs ;[ rud cdcu.lalion.s cre perfonmJ , ..n.J/y, TABLE 3.3-12 (Continued) TABLE NOTATION t
*0uring releases via this pathway.
**0uring waste gas holdup system operation (treatment for primary system offgases). ,
g ' MEW f ACTION)6 With the number of channels OPERABLE less than required by the . k, Minimum Channel s OPERABLE requirement, the contentsj'of the tank may be released to the environnent for up to '? 'na provided l that prior to initiating the release: 4./ At least two independent samples of the tank's contents I are analyzed, and h./. At least two technically qualified members of the Facility l Staff independentiy verify the - -......L... ; end discharge valve lineupg : ; Otherwise, suspend release of radioactive effluents via i this pathway. l 6 W ! ACTION h With the number of channels OPERABLE ess than reoufred by the Minimum Channels OPERABLE requirement, effluent releases via .
+ this pathway may continue for up to days provided the flow l rate is estimated at least once per 4 hours. '
g \L 3D ACTION #I With the number of channels OP BLE less than required by the Minimun Channels OPERABLE requi l ent, effluent releases via this pathway may continue for up days provided grab samples are taken at least once per hours and these samples are analy:ed for grossg activity within 24 hours. A. Del eted) ACTION 29 With the . r of channels CPERABLE less than requira . the Minimum Channe rRABLE requirement, operat the waste gas holdup system may tinue for up t days provided grab ! samples are collected at per 4 hours and analyzed l within ensuing 4 hours. ACTION 30 With the n of channels OPERABLE one than required by the M Channels OPERABLE requirement, ope on of this s may continue for up to 14 days. With both nels in-perable, be in at least HOT STANDBY within 1 hour. PWR-STS-1 3/4 3-57
TABLE 3.3 ,'<f/3 (Continuec) TABLE NOTATION AC ION "' numoer of channels CPERABLE 1ess than ree i. y the Minimum Chan 'Q ABLE recui remen
- releases via this pathway may continu ' w to eo cuys r.arnvided samples are continuousi - ad with auxiliary sampifng ech for peri n the order of seven (7) days and analyzec within 48 . urs of the end of sample collection.
Ac,rea 18 (Ji% Aa w%e .4 kds OPeitass.e Iers-lhenrepew) 13 lla Ps..w cl. anne /r C9EAA642 regsstre= man l2 ine.MA N fy s(s., fen d Vtd TsA Xp and Ptt< SING a[ myg,qef;y, e#La+r vr Ar pa.Avey. Ac.Troa 39 LJi+k 44,e nae af chands offtMw ana l<ss fAa,, coyairch ig L, Mis,% Cka.nuls cXtARLC regWre,ned, esjoerm% aS thLr sysb 'rnay conNnut br up b lal .fayg. UiN h.ro c/w,,ne/s itspraS{.o, le in *l l<*rl Nei" TMND$f wh le haues. Ac.rios yo urn A< wkr d edw*n</t *w" len/Aen reywred i de 7 in;<,,,,,, 1 Chaa,,els e/f/MLf refWre**d, e$d relenrer we ffe e e/e/pafjm ca,rhaue 6,up h 3o dy.rje>vicl<d fiaf ws/ha 4 4,ca., s/h,. pf,4 c),o,,,2.sf bos lees dedared in efernSQ T"#dfb r ar<. as /; mag,,f y a t/aefed w,Yh av//,'oey sn*,pt,*ny ayut(mu/ ., reyui,,a m Tall 1.It-2 4 c,,aa q r u;.g +k whe a/ clran*dr We'sA/LG It'ss A terweed Cy /Je
,wnimua,, cho,,,4 Cf[fd6LE re/C"'A b s usfot s cl c m y n s upy p> l Io /ke receMliners, pyg.STS-1 3/' 3-53
i , 13 TABLE 4.3- M
;M
{ RADIDACTIVE GASEOUS EFFLUENT HONITORING INSTRUMENTATION SURVEILLANCE REQUIREMENTS
;j opse4riogau A*W moco ,a c., aim
' CilANNEL CllANNEL SOURCE CilANNEL ."J:: !!^^i'!. "*'*
INSTRUMENT CilECK CilECK CALIBRATION TEST *"" _.
- 1. Waste Gas lloidup System i a. Noble Gas Activity Honitor- P/ P R(3) Q(1)
- Pr.wiJg Atam .1 e ? __,
Aab.1,c rcr,,4g7,, ,f y p g. 4 R.cle me. a ns . so,ey r.3g u k I k I I2- FIII2"
^
+ D M M t.>/ st fflue 2 Flow Rate ,eir N/A R Q~ g
'asuring Device
- e. S ;!e- F!er n am u..acuring a e 4 + 4 R
** 2. Waste Gas lloldup System Explosive m *;* Gas Monitoring System E a. liydrogen Honitor t_!'___...td De N/A H Q(4) 94
-5. !Olcer . . .-. . . w . ' e' tcr.. .t:) h -My%- 6 +
k 4. Oxygen Monitor Dew N/A Q(5) H gj c_ #. Oxygen Monitor (alternate) Da N/A Q(5) H 3,
~5.
Conlessu- Gsawdn,n Sys4em ( Mdb bss Mfir.h A4en"(ec-(EME.38 . D M
TABLE 4.3- (Continued)
.o RADIDACTIVE GASEQUS EFFLUENT MON 110 RING INSTRUMENTATION SURVEILLANCE REQUIREMENTS E
~ be CllANNEL Y' CllANNEL SOURCE CllANNEL FUNCTIONAL INSTRUMENT CllECK CllECK CAllBRATION TEST DN"
'/4 ; .i '-- '-i "cr;,2 Vent Sys tem p1 2-
- a. Noble Gas Activity Monitor O k' .V R(3) 4(#) "
(vs F -w)
- b. lodine Sampler (egp. 3 h D4 N/A N/A N/A :4
- c. Particulate Sampler (car- 35) D/ N/A N/A N/A y.
d."4u
'~f nt Flow Rate /bA, --
D/ N/A R 0 nrric.., Lce W . 4
$ e. Sampler Flow Rate ""'r "'r^; Ur N/A R 4 #
-C.;'.:;- fros;4ae 5.(auw,d bgehskw h "P
.. AW.o Att. 4.s ,ti;,ity #wA - bearng '12.C sh M'T a A Ad m/s. Term,,,ff,,, 3p Tda.re (tm-Y), Enr 'x) b A* ilia 7 h k b-ht.fi,,, sys h b M N S
".hU* Cus Ac.hst E m -3L) y A %rlar (g e.y, "l. 4 6 1 Sloca3e Ar% VenMJron T y sk , '
4 . A k W G o s A c. b l y Mondoc ( EMF-% D M f.A C U 4 6M r- %) l
!f.1 ;;3-T7[conunued)
$ RADI0 ACTIVE GASEOUS EFFLUENT MONITORING INSTRUMENTATION SURVEILLANCE REQUIREMENTS b
m INSTRUMENT CilANNEL CHECK SOURCE CHECK CHANNEL-CALIBRATION CilANNEL FUN TES NAL l-. %
. (see list below) N. ,
N
- a. Noble Gas Activity Monit'o'r ~., O* M R(3) Q(2)
~.,.
- b. Iodine Sampler D *N s. N.A. N.A. N.A.
- c. Particulate Sampler D* 'N,A. / .flA. N.A.
'/
~
- d. System Effluent flow Rate f '^%s Measurement Device D.* y N.A. SS Q
- e. Sampler Flow Rate Measurement Device g/
,.D'*
/ N.A. R
\ \.
Q y g
/
(a) Copdenser Evacuation System
'N (b)/ Vent lleader System f(c) Auxiliary Building Ventilation System
,!(d) Fuel Storage Area (Bailding) Ventilation System
/
(e) Radwaste Area Ventilation System (f) Steam Generator Blowdown Vent System
l TABLE 4.3- d l3 (Continued) TABLE NOTATION
" ' ; . ;i ; _ _; : ': th' : : " ';'
- A4 att f;mes. .
**During waste gas holdup system operation (treatnent for primary system offgases).
M AL*4 epCA*rreAL (1) The CHANNEL ~'r:M TEST shall also demonstrate that automatic isoiation o#f this pathway and control room alarm annunciation occurs if any of the foilowing conditions exist: .
- 1. Instrument indicates measured levels above the alam/ trip setpoin t. -
l 2. adar-eMb 1 Circuit failurg
- 3. Instrument indicates a downscale failureg (4.<- *MN 3
'
- r:-' ::-r:i; n : _; ; _r.._ ::_.
kJAtoG pgeg (2) The4 CHANNEL p"*MrMWee. TEST shall also demonstrate that control rocm alam annunciation occurs if any of the following conditions exist:
- 1. Instrument indicates measured levels above the alampenne setpoint.
- 2. Circuit failure.
l
- 3. Instrument indicates a downscale failure.
- -t ::r: :': e : - #-
- :t: :: . .-
(3) The initial CHANNEL CALIBRATION f:- t' ::tf f 7, ............; '-
*----****- shall be perfomed using one or more of the reference standards certified by the National Bureau of Standards or using standards that have been obtained from suppliers that participate y in measurement assurance activities with N8S. These standards .
pemit calibrating the system over its intended range of energy and ~~~l enes.e - * ---2 :':::.;. For subsequent CHANNEL CALIBRATION, sources that
~ have been related to the initial calibration eheelje be used,,:t ' -
+- ::i: :' :t i n;t : :: :: : f ; h t_., ..~. . -2. o.
- - - -* <eh.a A,. u ; :f.,,,,,, _ :;::_ $ . , ; , , f . f,- ,,. ., .,,. ,,,
... y. .: ..: ,; _t e_ _
..... -- n ..,., ...c,, m .s n ,,su--~_<_-.
r __
. . > . . . , .> - - - - . \
PWR-STS-1 3/4 3-62
TABLE 4.3-M G (Continued) (4) The CHANNEL CALIBRATION shall include the use of standard gas samples in
---t:t-:.3 . ........'a ace.a. ace wiA A bkrevs re %4 tdiens.
J na- "'r: ;... ... nyu.v3.u, e : o, n. . n 6,v3sn, onu-O f ^ " "'
" ^' ' " * *^ -" : . I l,j u . vy su , wo;anua n. . ;:- _
(5) The CHANNEL CALIBRATION shall include the use of standard gas samples in
- .......3 o avin . .h acc.,-aan=4 w.A A ~%fack e/s rew. ,Wo,u. g,
.=w .W - - - - _ w w mg g w e 5 g ut ww wu v i w w w ww- y w=
- 2. ": _ . . /. .. . , r. sno -s , . . . , b : ' - - -
a4+*acda O k700 y q3 bor) as nombN u,e- vc(atne f rt;.M h CX yyn,
% dan u sk.y, s%tt % used nn & aufmhin 4e ehe.k. Vnea 1, 4 b ogea 4 w. .
f PWR-STS-1 3/4 3-63
4 INSTRUMENTATION CHLORINE DETECTION SYSTEMS LIMITING CONDITION FOR OPERATION 3.3.3.11 Two independent chlorine detection systems, with their ale.rm/ trip setpoints adjusted to actuate at a chlorine concentration of less than or equal to 5 ppm, shall be OPERABLE. i l APPLICABILITY: ALL MODES ACTION:
- a. With one chlorine detection system inoperable, restore the inoperable detection system to OPERABLE status within 7 days or within the next 6 hours initiate and maintain operation of the control room emergency ventilation system in the recirculation mode of operation.
- b. With both chlorine detection systems inoperable, within 1 hour initiate and maintain cperation of the control room emergency ventilation system in the recirculation mode of operation.
- c. The provisions of Specification 3.0.4 are not applicable.
SURVEILLANCE REOUIREMENTS 4.3.3.11 Each chlorine detection system shall be demonstrated OPERABLE by performance of a CHANNEL CHECK at least once per 12 hours, an ANALOG CHANNEL OPERATIONAL TEST at least once per 31 days and a CHANNEL CALIBRATION at least once per 18 months. l l l { r I l CATAWBA - UNIT ' 3/4 3-70 t .~ s.2n:_: . ... . . . . < l
m INSTRUMENTATION LOOSE-PART DETECTION INSTRUMENTATION LIMITING CONDITION FOR OPERATION G-3.3.3./ The loose part detection system shall be OPERABLE. APPLICABILITY: MODES 1 and 2 ACITON:
- a. With one or more loose part detection system channels inoperable for more than 30 days, prepare and submit a Special Report to the Commission pursuant to Specification 6.9.2 within the next 10 days outlining the cause of the malfunction and the plans for restoring the channel (s) to OPERABLE status.
- b. The provisions of Specifications 3.0.3 and 3.0.4 are not applicable.
SURVEILLANCE REOUIRENENTS 1% 4.3.3./ Each char.nel of the loose part detection systems shall be demonstrated OPERABLE by performance of:
- a. A CHANNEL CHECK at least once per 24 hours, auqi k subden af.refen dp
- b. An ANALOG CHANNEL OPERATIONAL3TEST at least once per 31 days, and
- c. A CHANNEL CALIBRATION at least once per 18 months.
O W-STS 3/4 3-70 gg 3333
i 4 l INSTRUMENTATION 3/4.3.4 TURBINE OVERSPEED PROTECTION LIMITING CONDITION FOR OPERATION 3.3.4 At least one turbine overspeed protection system shall be OPERABLE. APPICABILITY: MODE $1,' 1. 0; ACTION:
- a. With one stop valve or one governor valve per high pressure turbine steam lead inoperable and/or with one reheat stop valve or one reheat intercept valve per low pressure turbine steam lead inoperable, restore the inoperable valve (s) to OPERABLE status within 72 hours, or close at least one valve in the affected steam lead (s) or isolate the turbine from the steam supply within the next 6 hours.
- b. With the above required turbine overspeed protection system otherwise inoperable, within 6 hours isolate the turbine frem the steam supply.
SURVEILLANCE REQUIREMENTS 4.3.4.1 The provisions of Specification 4.0.4 are not applicable. 4.3.4.2 The above required turbine overspeed protection system shall be demonstrated OPERABLE:
- a. At least once per 7 days by cycling each of the following valves through at least one complete cycle from the running position.
- 1. (Four) high pressure turbine stop valves.
- 2. (Four) high pressure turbine valves.
- 3. ( ) low pressure turbine [ M Y op valves.
su t
- 4. (Sees) low pressure turbine m intercept valves,
- b. At least once per 31 days by direct observation of the movement of each of the above valves through one complete cycle from the running position.
- c. At least once per 18 months by performance of a CHANNEL CALIBRATION on the turbine overspeed protection systems.
- d. At least once per 40 months by disassembling at least one of each of the above valves and performing a visual and surface inspection of valve seats, disks and stems and verifying no unacceptable flaws or corrosion.
W-STS 3/4 3-71 NOV " 1931
3/4.4 REACTOR COOLANT SYSTEM 3/4.4.1 REACTOR COOLANT LOOPS AND COOLANT CIRCULATION STARTUP AND POWER OPERATION LIMITING CONDITION FOR OPERATION l 3.4.1.1 All reactor coolant loops shall be in operation. APPLICABILITY: MODES 1 and 2.* ACTION: With less than the above required reactor coolant loops in operation, be in at least HOT STANDBY within 1 hour. SURVEILLANCE REQUIREMENT 4.4.1.1 The above required reactor coolant loops shall be verified to be in operation and circulating reactor coolant at least once per 12 hours.
*See Special Test Exception 3.10.4.
W-STS 3/4 4-1 MAY 151980
REACTOR COOLANT SYSTEM HOT STANOBY LIMITING CONDITION FOR OPERATION 3.4.1.2 a. At least two of the Reactor Coolant loops listed below shall be OPERABLE:
- 1. Reactor Coolant Loop (A) and its associated steam generator and Reactor Coolant pump,
- 2. Reactor Coolant Loop (B) and its associated steam generator and Reactor Coolant pump,
- 3. Reactor Coolant Loop (C) and its associated steam generator and Reactor Coolant pump,
- 4. Reactor Coolant Loop (D) and its associated steam generator and Reactor Coolant pump.
- b. At least one of the above Reactor Coolant loops shall be in operation.*
APPLICABILITY: MODE 3 ACTION:
- a. With less than the above required Reactor Coolant loops OPERABLE, restore the required loops to OPERABLE status within 72 hours or be in HOT SHUTDOWN within the next 12 hours.
- b. With no Reactor Coolant loop in operation, suspend all operations involving a reduction in boron concentration of the Reactor Coolant
. System and immediately initiate corrective action to return the j required Reactor Coolant loop to operation. l SURVEILLANCE RE0VIREMENTS A.4.1.2.1 At least the above required Reactor Coolant pumps, if not in operation, shall be determined to be OPERABLE once per 7 days by verifying correct breaker alignments and indicated power availability. 4.4.1.2.2 The required steam generators shall be determined OPERABLE by verifying secondary side water level to be greater than or equal to (17%) at least once per 12 hours. 4.4.1.2.3 At least one Reactor Coolant loop shall be verified to be in operation and circulating reactor coolant at least once per 12 hours.
"All Reactor Coolant pumps may be de-energized for up to 1 hour provided (1) no operations are permitted that would cause dilution of the reactor coolant system boron concentratioa, and (2) core outlet temperature is .
maintained at least 10*F below saturation temperature. W-Sis 3/4 4-2 NOV 3 61980
REACTOR COOLANT SYSTEM HOT SHUTDOWN LIMITING CONDITION FOR OPERATION 3.4.1.3 a. At least two of the Reactor Coolant and/or residual heat removal ( M ) loops listed below shall be OPERABLE: ND
- 1. Reactor Coolant Loop (A) and its associated steam generator
! and reactor coolant pump,*
~
- 2. Reactor Coolant Loop (B) and its associated steam generator and reactor coolant pump,*
- 3. Reactor Coolant Loop (C) and its associated steam generator and reactor coolant pump,*
- 4. Reactor Coolant Loop (D) and its associated steam generator and reactor coolant pump,*
- 5. Residual Heat Removal Loop (A),
- 6. Residual Heat Removal Loop (B).
~
ND
- b. At least one of the above Reactor Coolant and/or M loops shall be in operation.**
APPLICABILITY: MODE 4. ACTION: db
- a. With less than the above required Reactor Coolant and/or M loops j OPERABLE, immediately initiate corrective action to return the l required loops to OPERABLE status as soon as possible; if the l remaining OPERABLE loop is an #NR loop, be in COLD SHUTDOWN within 1 24 hours. *D Hb l b. With no Reactor Coolant or AWR loop in operation, suspend all operations involving a reduction in boron concentration of the Reactor Coolant System and immediately initiate corrective action to l return the required coolant loop to operation. jy) l 02 fo(IN## 300
*A Reactor Coolant pump shall not be starte ith one or more of the Reactor Coolant System cold leg temperatures less hanL or equal to_ ; F unless l 1) the pressurizer water volume is less thar or 2) the secondary water temperature of each steam g6iferator is less than 50 F above each of the Reactor Coolant System cold leg temperatures. **All Reactor Coolant pumps and residual heat removal pumps may be de-energized for up to I hour provided 1) no operations are permitted that would cause dilution of the Reactor Coolant System baron concentration, and 2) core outlet temperature is maintained at least 10 F below saturation temperature.
W-STS 3/4 4-3 JUL 2 71931
REACTOR COOLANT SYSTEM SURVEILLANCE REQUIREMENTS
, 4.4.1.3.1 The required Reactor Coolant pump (s), if not in operation, shall be determined to be OPERA 8LE once per 7 days by verifying correct breaker alignments and indicated power availability.
4.4.1.3.2 The required steam generator (s) shall be determined OPERABLE by verifying secondary side water level to be greater than or equal to 4473P. at least once per 12 hours. GL AD 4.4.1.3.3 At least one Reactor Coolant or AMR loop shall be verified to be in . operation and circulating reactor coolant at least once per 12 hours. l i l W-STS 3/4 4-4 ,tuy, 2 01980 l __ _ _ __ _ .~. - - - - - - -
- E!.: :: :D:L W 5+5 Ew C:LD SHU DO N - LCC:5 :ILLE LIMITING CONDITION ::E 0 ERATICN =
ND 3.a.1.4.1 At ieast one resicual heat removal (4i=6) loco shall ne OPERABLE and in operation *, anc either: N
- a. One acditional Tw=D loop snall be OPERABLE #, or
- b. The seconda y side water level of at least twc steam generators snail be greater tnan J,P';*..
82. APPLICABILITY: MODE 5 with Reactor Coolant loops filfed # ACTION: ene ebe f/D bers' ine;c.redI.c. sn$
- a. Withfma .. .a n .. . e . . . .-,:.e '.m.,~ : T.1:_: a with less than the required steam generator level, immediately initiate corrective action to return the ::_ 1- loopt to OPERABLE status or 'J(, restore the required 1evel,as soon as possible.,
ob Geo 4ymers;te r- incperd4.
- b. With no aus loop in operation, suspend all operations involving a <
reduction in boron concentration of the Reactor Coolant System and immediately initiate corrective action to return the required Ieini #D loop to operation. SURVEILLANCE REOUIREMENTS
* * :.".1.1 ~5: g ' :1 '"' :::;
i ' n _... n :t:d T:"":L: r . . .. r n age...wa..m. ,... . 4.4.1.4.1./1 The secondary side water level of at least two steam generators when required shall be determined to ba within limits at least once per 12 hours. rlh 4.4.1.4.1./2. At least one M loop shall be determined to be in operation and circulating reactor coolant at least once per 12 hours. 4
# One feeis loop may be inoperable for up to 2 hours for surveillance testing provided the other M loop is OPERABLE and in operation.
## 't ?3* f 5**
A Reactor Coolant pump shall not be start d with one or more{of the Reactor Coolant System cold leg temperatures less than or equal to M F unless
- 1) the pressurizer water volume is less than (Sco cubic feet)or 2) the secondary water temperature of each steam generator is less than _c3 F above each cf the Reactor Coolant System cold leg temperatures.
**The pump may be de-energized for up to 1 hour provided 1) no operations are permitted that would cause dilution of the Reactor Coolant System boron concentration, and 2) core outlet temperature is maintained at least 10 F below saturation temoerature.
W-STS. 3/4 4-5 JUL 2 7 toS1
REACTOR COOLANT SYSTEM COLD SHUTDOWN - LOOPS NOT FILLED LIMITING CONDITION FOR OPERATION No 3.4.1.4.2 Two residual heat removal (aN#) loops shall be OPERABLE # and at least one RNR= loop shall be in operation."
#D APPLICABILITY: MODE 5 with Reactor Coolant loops not filled.
ACTION:
- a. With less than the above required loops OPERABLE, immediately initiate corrective action to return the required loops to OPERABLE status as soon as possible. g, MD
- b. With no 4WWF loop in operation, suspend all operations involving a i9 duction in boron concentration of the Reactor Coolant System and immediataly initiate corrective action to return the required 4EN>AD loop to operation.
SURVEILLANCE REOUIREMENTS
,.4 4.j.i.
, Tgo , . .yu . . cu ; ; :..r. : .'. ; " L _ . . .. . . o uronnocu guisuo.. ..
.y .........- . ...
AD 4.4.1.4.2./ At least one #MR loop shall be determined to be in operation and circulating reactor coolant at least once per 12 hours. tra One RNR 4 1oop may be inoperable for up to 2 hours for surveillance testing provided the other #MR loop is OPERABLE and in operation.
"D Wo
- The ANR pump may be de-energized for up to I hour provided 1) no operations are permitted that would cause dilution of the Reactor Coolant System boron concentration, and 2) core outlet temperature is maintained at least 10*F below saturation temperature.
W-STS
- 3/4 4-6 NOV 2- 1981
l REACTO COOLANT SYSTEM ISOLATED P (OPTIONAL) l l LIMITING CONDI ON FOR OPERATION 1 1 3.4.1.5 The boron ncentration of an isolated loop s 1 be maintained , greater than or equal the boron concentratiori of operating loops. 1 APPLICABILITY: MODES 1, , 3, 4, and 5. ACTION: i With the requirements of the ve specifi tion not satisfied, do not open the isolated loop's stop valves; ither ~ crease the boron concentration of the isolated loop to within the li 'ts ithin 4 hours or be in at least HOT STANDBY within the next 6 hours with he unisolated portion of the RCS borated to a SHUTDOWN MARGIN equivalent to t east 1% delta k/k at 200*F. I 1 SURVEILLANCE REQU EMENTS
, s 4.4.1.5 Th oron concentration of an isolated loop shall b determined to be greater th or equal to the boron concentration of the opera 'ng loops at least on per 24 hours and within 30 minutes prior to opening 'ther the hot leg or ld leg stop valves of an isolated loop.
1 1 1 PSTS 3/4 4-7 '!OV 2 1981 l
TOR COOLANT SYSTEM ISOLA LOOP STARTUP (OPTIONAL) LIMITING C0 TION FOR OPERATION s , 3.4.1.6 A reactor olant loop shall remain isolated ntil:
- a. The isolated cop has been operating on recirculation flow of greater than o equal to gpm for at east 90 minutes and the temperature at t cold leg of the iso ated loop is within 20 F of the highest cold 1 temperature of e operating loops.
- b. The reactor is subcrit al by at 1 ast 1 percent delta k/k.
APPLICABILITY: ALL MODES. ACTION: With the requirements of the above s cific ion not satisfied, suspend startup of the isolated loop. SURVEILLANCE REQUIREMENTS 1 ~ 4.4.1.6.1 The isolat loop cold leg temperature shall be dete 'ned to be within 20 F of the h4 hest cold leg temperature of the operating 1 ps within 30 minutes prior to apening the cold leg stop valve. 4.4.1.6.2 The r ctor shall be determined to be subcritical by at leas 1 percent delta k within 30 minutes prior to opening the cold leg stop lve. W-STS 3/4 4-8
<!.I! 2 1981
REACTOR COOLANT SYSTEM 3/4.4.2 SAFETY VALVES SHUTDOWN LIMITING CONDITION FOR OPERATION 3.4.2.1 A minimum of one pressurizer code safety valve shall be OPERABLE with a lift setting of 2485 PSIG 1L
- APPLICABILITY: MODES 4 and 5. -
ACTION: With no pressurizer code safety valve OPERABLE, immediately suspend all operations involving positive reactivity changes and place an OPERABLE residual heat removal loop into operation in the shutdown cooling mode. I SURVEILLANCE REOUIREMENTS 4.4.2.1 No additional Surveillance Requirements other than those required by Specification 4.0.5.
"The lift setting pressure shall correspond to ambient conditions of the valve at nominal operating temperature and pressure.
W-STS 3/4 4-9 -
REACTOR COOLANT SYSTEM OPERATING LIMITING CONDITION FOR OPERATION 3.4.2.2 All pressurizer code safety valves shall be OPERABLE with a lift setting of 2485 PSIG t 1%.* APPLICABILITY: MODES 1, 2, and 3. ACTION: With one pressurizer code safety valve inoperable, either restore the inoperable valve to OPERABLE status within 15 minutes or be in at least HOT STAN0BY within 6 hours and in at least HOT SHUTOOWN within the following
- 6 hours.
SURVEILLANCE REOUIREMENTS 4.4.2.2 No additional Surveillance Requirements other than those required by Specification 4.0.5.
"The lift setting pressure shall correspond to ambient conditions of the valve at nominal operating temperature and pressure. 'f-STS 3/4 4-10
REACTOR COOLANT SYSTEM 3/4.4.3 PRESSURIZER LIMITING CONDITION FOR OPERATION (epieled +e e MMed texwl *f test % oe eyes 4 h f a9, en (lir00 wer,a v3e ensiemnead) 3.4.3 Thel pressurizer shall be OPERABLE with a water volume of less than or equal to J,;A6Ff cubic fee and at least two groups of pressurizer heaters each having a capacity of at least (150) kw. APPLICABILITY: MODES 1, 2, and 3. ACTION:
- a. With one group of pressurizer heaters inoperable, restore at least two groups to OPERABLE status within.72 hours or be in at least HOT STANDBY within the next 6 hours and in HOT SHUTDOWN within the following 6 hours,
- b. With the pressurizer otherwise inoperable, be in at least HOT STANDBY with the reactor trip breakers open within 6 hours and in HOT SHUTDOWN within the following 6 hours.
l SURVEILLANCE REQUIREMENTS 4.4.3.1 The pressurizer water volume shall be determined to be within its limit at least once per 12 hours. 4.4.3.2 The capacity of each of the above required groups of pressurizer heaters shall be verified by, measuring circuit current at least once per 92 days. w,ggngey,hr,og 4.4.3.3 The emergency power supply for the pressurizer heaters shall be demonstrated OPERABLE at least once per 18 months by manually transferring l power from the normal to the emergency power supply and energizing the heaters. l l l W-STS _ 3/4 4-11 i
REACTOR COOLANT SYSTEM 3/4.4.4 RELIEF VALVES LIMITING CONDITION FOR OPERATION 3.4.4 All power-operated relief valves (PORVs) and their associated block valves shall be CPERABLE. APPLICABILITY: MODES 1, 2, and 3. ACTION:
- a. With one or more PORV(s) inoperable, within I hour either restore the PORV(s) to OPERABLE status or close the associated block valve (s) and remove power from the block valve (s); otherwise, be in at least HOT STANOBY within the next 6 hours and in COLD SHUTDOWN within the following 30 hours.
- b. With one or more block valve (s) inoperable, within 1 hour either restore the block valve (s) to OPERABLE status or close the block valve (s) and remove power from the block valve (s); otherwise, be in at least HOT STANOBY within the next 6 hours and in COLD SHUTOOWN within the following 30 hours.
- c. The provisions of Specification 3.0.4 are not applicable.
SURVEILLANCE REQUIREMENTS 4.4.4.1 In addition to the requirements of Specification 4.0.5, each PORV shall be demonstrated OPERABLE at least once per 18 months by:
- a. Performance of a CHANNEL CALIBRATION, and
- b. Operating the valve through one complete cycle of full travel.
4.4.4.2 Each block valve shall be demonstrated OPERABLE at least once per 92 days by operating the valve through one complete cycle of full travel unless the block valve is closed with power removed in order to meet the requirements of Specification 3.4.4.a. 4.4.4.3 The emergency power supply for the PORVs and block valves shall be demonstrated OPERABLE at least once per 18 months by:
- a. Manually transferring motive and control power from the normal to the emergency power supply, and
- b. Operating the valves through a complete cycle of full travel.
W-STS 3/4 4-12 ggy 2 1981
l l REACTOR COOLANT SYSTEM 3/4.4.5 STEAM GENERATORS LIMITING CONDITION FOR OPERATION 3.4.5 Each steam generator shall be OPERABLE. APPLICADILITY: MODES 1, 2, 3 and 4. ACTION: With one or more steam generators inoperabl.e, restore the inoperable generator (s) to OPERABLE status prior to increasing T,yg above 200*F. SURVEILLANCE REQUIREMENTS 4.4.5.0 Each steam generator shall be demonstrated OPERABLE by performance of the following augmented inservice inspection program and the requirements of Specification 4.0.5. 4.4.5.1 Steam Generator Sample Selection and Inspection - Each steam generator shall be determined OPERABLE ouring shutdown by selecting and inspecting at least the minimum number of steam generators specified in Table 4.4-1. t 4.4.5.2 Steam Generator Tube Sample Selection and Inspection - The steam generator tube minimum sample size, inspection result classification, and the corresponding action required shall be as specified in Table 4.4-2. The inservice inspection of steam generstor tubes shall be performed at the fre-quencies specified in Specification 4.4.5.3 and the inspected tubes shall be verified acceptable per the acceptance criteria of Specification 4.4.5.4. The tubes selected for each inservice inspection shall include at least 3% of the total number of tubes in all steam generators; the tubes selected for these inspections shall be selected on a random basis except: I a. Where experience in similar plants with similar water chemistry j indicates critical areas to De inspected, then at least 50% of the l tubes inspected shall be from these critical areas,
- b. The first sample of tubes selected for each inservice inspection (subsequent to the preservice inspection) of each steam generator shall include:
W-STS 3/4 4-13 N
REACTOR COOLANT SYSTEM SURVEILLANCE REQUIREMENTS (Continued)
- 1. All nonplugged tubes that previously had detectable wall penetrations (greater than 20%).
- 2. Tubes in those areas where experience has indicated potential problems.
- 3. A tube inspection (pursuant to Specification 4.4.5.4.a.8) shall be performed on each selected tube. If any selected tube does not permit the passage of the eddy current probe for a tube inspection, this shall be recorded and an adjacent tube shall be selected and subjected to a tube inspection.
- c. The tubes selected as the second and third samples (if required by Table 4.4-2) during each inservice inspection may be subjected to a partial tube inspection provided:
- 1. The tubes selected for these samples include the tubes from those areas of the tube sheet array where tubes with imperfections were previously found.
- 2. The inspections include those portions of the tubes where imperfections were previously found.
The results of each sample inspection shall be classified into one of the following three categories: Category Inspection Results l C-1 Less than 5% of the total tubes inspected are degraded tubes and none of the inspected tubes are defective. C-2 One or more tubes, but not more than 1% of the total tubes inspected are defective, or between 5% and 10% of the total tubes inspected are degraded tubes. C-3 More than 10% of the total tubes inspected are degraded tubes or more than 1% of the inspected tubes are defective. Note: In all inspections, previously degraded tubes must exhibit significant (greater than 10%) further wall penetrations to be included in the above percentage calculations. W-STS 3/4 4-14 NOV 2 1981
REACTOR COOLANT SYSTEM SURVEILLANCE REQUIREMENTS (Continued) 4.4.5.3 Inspection Frequencies - The above required inservice inspections of steam generator tuDes snall be performed at the following frequencies:
- a. The first inservice inspection shall be performed after 6 Effective Full Power Months but within 24 calendar months of initial criticality.
Subsequent inservice inspections shall be performed at intervals of not less than 12 nor more than 24 calendar months after the previous inspection. If two consecutive inspections following service under AVT conditions, not including the preservice inspection, result in all inspection results falling into the C-1 category or if two consecutive inspections demonstrate that previously observed degra-dation has not continued and no additional degradation has occurred, the inspection interval may be extended to a maximum of once per 40 months.
- b. If the results of the inservice inspection of a steam generator conducted in accordance with Table 4.4-2 at 40-month intervals fall in Category C-3, the inspection frequency shall be increased to at least once per 20 months. The increase in inspection frequency shall apply until the subsequent inspections satisfy the criteria of Specification 4.4.5.3.a; the interval may then be extended to a maximum of once per 40 months.
- c. Additional, unscheduled inservice inspections shall be performed on each steam generator in accordance with the first sample inspection specified in Table 4.4-2 during the shutdown subsequent to any of the following conditions:
- 1. Primary-to-secondary tubes leaks (not including leaks originating from tube-to-tube sheet welds) in excess of the limits of l Specification 3.4.6.2.
- 2. A seismic occurrence greater thhn the Operating Basis Earthquake.
- 3. A loss-of-coolant accident requiring actuation of the engineered safeguards.
- 4. A main steam line or feedwater line break.
W-STS 3/4 4-15
REACTOR COOLANT SYSTEM SURVEILLANCE REQUIREMENTS (Continued) 4.4.5.4 Acceptance Criteria
- a. As used in this Specification:
- 1. Imoerfection means an exception to the dimensions, finish or contour of a tube from that required by fabrication drawings or specifications. Eddy-current testing indications below 20% of the nominal tube wall thickness, if detectable, may be -
considered as imperfections.
- 2. Degradation means a service-induced cracking, wastage, wear or general corrosion occurring on either inside or outside of a tube.
- 3. Degraded Tube means a tube containing imperfections greater than or equal to 20% of the nominal wall thickness caused by degradation.
- 4. % Degradation means the percentage of the tube wall thickness affecteo or removed by degradation.
- 5. Defect means an imperfection of such severity that it exceeds the plugging limit. A tube containing a defect is defective.
- 6. Pluacing Limit means the imperfection depth at or beyond which the tube snall be removed from service and is equal to (40)%*
of the nominal tube wall thickness.
- 7. Unserviceable describes the condition of a tube if it leaks or contains a defect large enough to affect its structural integ-rity in the event of an Operating Basis Earthquake, a loss-of-coolant accident, or a steam line or feedwater line break as specified in 4.4.5.3.c, above.
- 8. Tube Insoection means an inspection of the steam generator tube from tne point of entry (hot leg side) completely around the U-bend to the top support of the cold leg.
"Value to be determined in accordance with the recommendations of Regulatory Guide 1.121, August 1976. NOV 2 1981 W-STS 3/4 4-16
REACTOR COOLANT SYSTEM SURVEILLANCE REOUIREMENTS (Continued)
- 9. Preservice Inspection means an inspection of the full length of each tube in each steam generator performed by eddy current techniques prior to service to establish a baseline condition of the tubing. This inspection shall be performed after the field hydrostatic test and prior to initial POWER OPERATION using the equipment and techniques expected to be used during subsequent inservice inspections.
- b. The steam generator shall be determined OPERABLE after completing
- the corresponding actions (plug all tubes exceeding the plugging limit and all tubes containing through-wall cracks) required by Table 4.4-2.
4.4.5.5 Reoorts
- a. Within 15 days following the completion of each inservice inspection of steam generator tubes, the number of tubes plugged in each steam
! generator shall be reported to the Commission in a Special Report pursuant to Specification 6.9.2.
- b. The complete results of the steam generator tube inservice inspection shall be submitted to the Commission in a Special Report pursuant to Specification 6.9.2 within 12 months following the completion of the inspection. This Special Report shall include:
- 1. Number and extent of tubes inspected.
- 2. Location and percent of wall-thickness penetration for each indication of an imperfection.
l 3. Identification of tubes plugged. l
- c. Results of steam generator tube inspections which fall into Category C-3 and require prompt notification of the Commission shall be reported pursuant to Specificati.on 6.9.1 prior to resumption of plant operation. The written followup of this report shall provide a description of investigations conducted to determine cause of the tube degradation and corrective measures taken to prevent recurrence.
I l W-STS 3/4 4-17 NOV 2 1981
lE a vi TABLE 4 4-1 MINIMUM NUMBER OF STEAM GENERATORS TO BE INSPECTED DUHING INSERVICE INSPECTION Preservice inspection No Yes No. of Steam Generators per Unit Two Three Four Two Three Four w N First inservice inspection All One Two Two Second & Subsequent inservice inspections One l One l One2 One3 co _ Table Notation:
- l. The inservice inspection enay be limited to one steam generator on a rotating schedule encompassing 3 N % of the tubes (where N is the number of stearn generators in the plant) if the results of the first or previous inspections indicate that all steam generators are gierforming in a like manner. Note that under some circumstances, the operating conditions in one or more steam generators may be found to be more severe than those in other steam generators. Under such circum-stances the sampla sequence shall be modified to inspect the most severe corulitions. 4 l
- 2. The other steam generator not inspected during the first inservice inspection shall be inspecie.d. The third and subsequent ,
inspections shoukt follow ti.e instructions described in 1 above. I
- 3. Each of the other two steam generators not inspecte.sl during the first inservice inspections shall be inspected during the secosul aral third inspections. The fourth and subsequent inspections shall follow the instructions described in 1 above.
L
~;
to Eb
'T vi , y TABLE 4.4-2 i i
STEAM GENERATOR TUSE INSPECTION IST SAMPLE INSPECTION 2ND SAMPLE INSPECTION 3RD SAMPLE INSPECTION Sample Sise Result Action Required Remalt Action Required Result Action Requival 1 1 A minimum of C-1 None N/A N/A N/A N/A l l S Tubes per I S. G. C-2 Plug defective tubes C-1 None N/A N/A and impect mional Pisg defective tut =s C-1 None 2S tubes in this S. G. C-2 and inspect additionel y pg w;, % , I 4S tubes in this S. G. Perform action for C-3 C-3 result of first ta sarngh
) Perform action for
, C-3 C-3 result of first N/A N/A e.', .
"*8*
*D C-3 Inspect all tubes in All ottier this S. G., plug de- S. G.s are None N/A N/A factive tubes and C-1 t 2S h G.s Poiform action for N/A N/A
"' C-2 result of seconri additional g Prompt notification S. G. are to NRC purmsant C-3 to specifkation Additionel Inspect all hebes in 6.9.1 S. G. is C-3 each S. G. and plus defective tulies.
Prompt notification N/A N/A to NRC pursuant to specification l 6.9.1 1
, . 3 5 m. ore N is ine m e,ber of steem -siors in ihe onit. and n is ii.e nu,,,6er of sie -aims inspeci.i s n during an impaction i3 0
Et
REACTOR COOLANT SYSTEM , 3/4.4.6 REACTOR COOLANT SYSTEM LEAKAGE LEAKAGE DETECTION SYSTEMS LIMITING CONDITION FOR OPERATION 3.4.6.1 The following Reactor Coolant System leakage detection systems shall be OPERABLE:
- a. The containment atmosphere monitoring systemic (EMF-3h{ gaseous cr ;_cM:_i;tO radioact I
- b. The containment W sump level and flow monitoring system, and
- c. Ei the r the ';;. . .. : . .... . . . . . - ' -- ~ ~-'-- : t M - -* ^? " '--
containmentatmosphere,";;_.._.;. particulate / radioactivity monitoring system g
\cvel men %cing syskm. (. EMF-38h er b cenkinMt vedildion doodeosd bk APDLICABILITY: MODES 1, 2, 3 and 4.
ACTION: With only two of the above required leakage detection systems OPERABLE, operation may continue for up to 30 days provided grab samples of the contain-ment atmosphere are obtained and analyzed at least once per 24 hours when the required gaseous or particulate radioactive monitoring system is inoperable; otherwise, be in at least HOT STANDBY within the next 6 hours and in COLD SHUTDOWN within the following 30 hours. , SURVEILLANCE REOUIRIMENTS l 4.4.6.1 The leakage detection systems shall be demonstrated 0PERABLE by:
- a. Containment atmosphere / gaseous and/er particulate / monitoring i systerkperformance of CHANNEL CHECX, CHANNEL CALIBRATION and ANALOG CHANNEL OPERATIONAL TEST at the frequencies specified in Table 4.3-7,4 b.
a c.a.:.,~ + ved.l.dr a oa=4s.h !ad. Jud ..;wg l Containment.eeeke4 sump level and flow monitoring systegperformance sys6-of CHANNEL CALIBRATION at least once per 18 months m r e -- u., .-- -- 4o. ,,,,..,.433,--- .~e a----e
; _ j;;7-*4.m e.,-+-
e ,,
- - 13;;g; g
-'-*f,p W-STS 3/4 4-20 ;931 NG'l 2
REACTOR COOLANT SYSTEM OPERATIONAL LEAKAGE LIMITING CONDITION FOR OPERATION 3.4.6.2 Reactor Coolant System leakage shall be limited to:
- a. No PRESSURE BOUNDARY LEAKAGE,
- b. 1 GPM UNIDENTIFIED LEAKAGE,
- c. 1 GPM total primary-to-secondary leakage through all steam I
generators not isolated from the Reactor Coolant System and (500) gallons per day through any one steam generator not isolated from the Reactor Coolant System,
- d. 10 GPM IDENTIFIED LEAKAGE from the Reactor Coolant System, and
- e. O GPM CONTROLLED LEAKAGE at a Reactor Coolant System pressure of 4 5 1 20 psig.
- f. 1 GPM leakage at a Reactor Coolant System pressure of 2235 20 psig from any Reactor Coolant System Pressure Isolation Valve specified in Table 5.4-1.
APPLICABILITY: MODES 1, 2, 3, and 4. ACTION:
- a. With any PRESSURE BOUNDARY LEAKAGE, be in at least HOT STANDBY within 6 hours and in COLD SHUTDOWN within the following 30 hours,
- b. With any Reactor Coolant System leakage greater than any one of the above limits, excluding PRESSURE BOUNDARY LEAKAGE and leakage from Reactor Coolant System Pressure Isolation Valves, reduce the leakage rate to within limits within 4 hours or be in at least HOT STANDBY within the next 6 hours and in COLD SHUTDOWN within the following 30 hours.
- c. With any Reactor Coolant System Pressure Isolation Valve leakage greater than the above limit, isolate the high pressure portion of the affected system from the low pressure portion within 4 hours by use of at least two closed manual or deactivated automatic valves, or be in at least HOT STANDBY within the next 6 hours and in COLD SHUTDOWN within the following 30 hours.
W-STS 3/4 4-21 00V 2 9 31
REACTOR COOLANT SYSTEM SURVEILLANCE REQUIREMENTS , 4.4.6.2.1 Reactor Coolant System leakages shall be demonstrated to be within each of the above limits by: :
- a. Monitoring the containment atmosphere [ gaseous .. ,..........r radioactivity monitor at least once per 12 hours.
- b. Monitoring the containment ;
- :': t sump inventory and discharge at least onc,e per 12 hours,
~
- c. Measurement of the CONTROLLED LEAKAGE to the reactor coolant pump l seals when the Reactor Coolant System pressure is 2235 20 psig at least once per 31 days.efth th: n i h ti:;-velve full.;- ;21 The
- provisions of Specification 4.0.4 are not applicable for entry into MODE 3 or 4.
- d. Performance of a Reactor Coolant System water inventory balance at least once per 72 hours,
- e. Monitoring the reactor head flange leakoff system at least once per 24 hours.
4.4.6.2.2 Each Reactor Coolant System Pressure Isolation Valve specified in , Table 3.4-1 shall be demonstrated OPERABLE pursuant to Specification 4.0.5, except that in lieu of any leakage testing required by Specification 4.0.5, each valve shall be demonstrated OPERABLE by verifying leakage to be within its limit:
- a. At least once per 18 months.
- b. Prior to entering MODE 2 whenever the plant has been in COLD
- SHUTDOWN for 72 hours or more and if leakage testing has not been performed in the previous 9 months.
- c. Prior to returning the valve to service following maintenance, repair or replacement work on the valve.
- d. Within 24 hours following valve actuation due to automatic or manual action or flow through the valve. ,
The provisions of Specification 4.0.4 are not applicable for entry into MODE 3 or 4. ' I40V ~* 1931 W-STS 3/4 4-22
TABLE 3.4-1 REACTOR COOLANT SYSTEM PRESSURE ISOLATION VALVES VALVE NUMBER FUNCTION CN-1562-1.1 INI59 Accumulator Discharge 1NI60 Accumulator Discharge 1NI70 Accumulator Discharge i INI71 Accumulator Discharge 1NI81 Accumulator Discharge 1NI82 Accumulator Discharge 1NI93 Accumulator Discharge 1NI94 Accumulator Discharge CN-1562-1.2 1NI124 Safety Injection (Hot Leg) 1NI126 Safety Injection (Hot Leg) 1NI128 Safety Injection (Hot Leg) 1NI134 Safety Injection (Hot Leg) INI156 Safety Injection (Hot Leg) INI157 Safety Injection (Hot Leg) 1NI159 Safety Injection (Hot Leg) 1NI160 Safety Injection (Hot Leg) i CN-1562-1.3 INI165 Safety Injection / Residual Heat Removal (Cold Leg) 1NI167 Safety Injection / Residual Heat Removal (Cold Leg) INI169 Safety Injection / Residual Heat Removal (Cold Leg) INI171 Safety Injection / Residual Heat Removal (Cold Leg) 1NI175 1NI176 Safety Injection / Residual Heat Removal (Cold Leg) ( 1NI180 Safety Injection / Residual Heat Removal (Cold Leg) ! 1NI181 Safety Injection / Residual Heat Removal (Cold Leg) l
- Safety Injection / Residual Heat Removal (Cold Leg) l CN-1562-1.4 1NI248 Upper Head Injection l INI249 Upper Head Injection
! 1NI250 Upper Head Injection 1NI251 Upper Head Injection 1NI252 Upper Head Injection 1NI253 Upper Head Injection i PSTS 3/4 4-23 E2
REACTOR COOLANT SYSTEM 3/4.4.7 CHEMISTRY LIMITING CONDITION FOR OPERATION 3.4.7 The Reactor Coolant System chemistry shall be maintained within the limits specified in Table 3.4-2. APPLICABILITY: At all times. ACTION: MODES 1, 2, 3, and 4:
- a. With any one or more chemistry parameter in excess of its Steady State Limit but within its Transient Limit, restore the parameter to within its Steady State Limit within 24 hours or be in at least HOT STANOBY within the next 6 hours and in COLD SHUTDOWN within the following 30 hours.
- b. With any one or more chemistry parameter in excess of its Transient Limit, be in at least HOT STANOBY within 6 hours and in COLD SHUTOOWN within the following 30 hours.
At All Other Times: With the concentration of either chloride or fluoride in the Reactor Coolant System in excess of its Steady State Limit for more than 24 hours or in excess of its Transient Limit, reduce the pressurizer pressure to less than or equal to 500 psig, if applicable, and perform an engineering evaluation to determine the effects of the out-of-limit condition on the structural integrity of the Reactor Coolant System; determine that the Reactor Coolant System remains acceptable for continued operation prior l to increasing the pressurizer pressure above 500 psig or prior to proceeding to MODE 4. . SURVEILLANCE REQUIREMENTS 4.4.7 The Reactor Coolant System chemistry shall be determined to be within the limits by analysis of those parameters at the frequencies specified in Table 4.4-3. NOV 2 1991 W-STS 3/4 4-24
TABLE 3.4-2 REACTOR COOLANT SYSTEM CHEMISTRY LIMITS STEADY STATE TRANSIENT PARAMETER LIMIT LIMIT DISSOLVED OXYGEN
- 1 0.10 ppm 1 1.00 ppm CHLORIDE $ 0.15 ppm i 1.50 ppm FLUORIDE 5 0.15 ppm 5 1.50 ppm
" Limit not applicable with T,yg less than or equal to 250*F.
i W-STS 3/4 4-25 NOV 2 1981 c .- . - . _ - . - -._ - _ _ - - ,. -. . - -
' TABLE 4.4-3 REACTOR COOLANT SYSTEM CHEMISTRY LIMITS SURVEILLANCE REQUIREMENTS SAMPLE AND PARAMETER ANALYSIS FREQUENCY DISSOLVED OXYGEN
- At least once per 72 hours CHLORIDE At least once per 72 hours FLUORIDE .
At least once per 72 hours 4
"Not required with T,yg less than or equal to 250*F i
! W-STS 3/4 4-26 jay 3 1981 t.
REACTOR COOLANT SYSTEM 3/4.4.8 SPECIFIC ACTIVITY LIMITING CONDITION FOR OPERATION 3.4.8 The specific activity of the primary coolant shall be limited to:
- a. Less than or equal to 1.0 microcurie per gram DOSE EQUIVALENT I-131, and
- b. Less than or equal to 1004 microcuries per gram g efgress spm'[ "'//v//r.
APPLICABILITY: MODES 1, 2, 3, 4, and 5. ACTION: MODES 1, 2 and 3*:
- a. With the specific activity of the primary coolant greater than 1.0 microcurie per gram DOSE EQUIVALENT I-131 but within the allowable limit (below and to the left of the line) shown on Figure 3.4-1, operation may continue for up to 48 hours provided that the cumula-tive operatino time under these circumstances does not exceed b* 800hoursinanyconsecutive12monthperiod.AWiththetotalcumulative operating time at a primary coolant specific activity greater than 1.0 microcurie per gram DOSE EQUIVALENT I-131 exceeding 500 hours in any consecutive 6-month period, prepare and submit a Special Report to the Commission pursuant to Specification 6.9.2 within 30 days indicating the number of hours above this limit. ha ~^"'4-~ d e--- .
--.r.. , n i ,,, ... ,. - u,-
- c. h, With the specific activity of the primary coolant greater than 1.0 microcurie per gram DOSE EQUIVALENT I-131 for more than 48 hours during one continuous time interval or exceeding the limit line shown on Figure 3.4-1, be in at least HOT STANDBY with T less than 500 F avg within 6 hours. . .
yess cl %. With the, specific activity of the primary coolant greater than 1006 microcuries per gram, be in at least HOT STANDBY with T less than avg 500'F within 6 hours; and
- e. The pewirions e f Qecifcaltoa 5.o.4 are uf 9 c de b le..
- Witn T,yg grear.er than or equal to 500 F.
l l W-STS 3/4 4-27 NCY .0 1981
REACTOR COOLANT SYSTEM ACTION: (Continued) MODES 1, 2, 3, 4, and 5:
- a. With the specific activity of the primary coolant greater than 1.0 microcurie per gram DOSE EQUIVALENT I-131 or greater than 100/E microcuries per gram, perform the sampling and analysis requirements of item 4a of Table 4.4-4 until the specific activity of the primary coolant is restored to within its limits. 4-MP9RTM!tMfet9RRfM6E-s 2.0 L g. gd -d " 'tt:f t: C. imm....m. g , m. . _ : :T; This report shall contain the results of the specific I activity analyses together w.ith the following information:
- 1. Reactor power history starting 48 hours prior to the first sample in which the limit was exceeded,
- 2. % L.4 5., :: : 4: r, i 3. Clean-up flow history starting 48 hours prior to the first sample in which the limit was exceeded,
- 4. History of de gassing operations, if any, starting 48 hours prior tc. the first sample in which the limit was exceeded, and
- 5. The time duration when the specific activity of the primary coolant exceeded 1.0 microcurie per gram DOSE EQUIVALENT I-131.
' %Jie d L lasl 13S y c asulysir kr radiciedioses ferbe,nedf eier- h, e.uted/sg L ttA, ukda lM4 as eucedeJ, <nd one m(y,;.r eRei. }},e can,;ocii,,e acMy was wk"4 h less -{lwn }he limsh includ/ny be each halefic l 1 a*< \ su ,-ihe elale an/ &ne ol' sa,,,pf,ng ad f, rggaaa;4e w, g f ,,,.
f SURVEILLANCE REOUIREMENTS 4.4.8 The specific activity of the primary coolant shall be determined to be within the limits by performance of the sampling and analysis program of Table 4.4-4.
~
& \;es el uy elbee reprf rtjuired flj S ecobeab*n l l-l, $ 01s Wicid Ye'"N Uch lo %s, yegau ad what/ a Spetal Refer l la +5e Cwassion f*N N Seac;heak L.9. 2. u}h a cog f .)fa bi,ecfar, Ade<< Acaebi- Aap/das , 7%% :
G% den t<dar~nea. Bcnuk ,aa,.I ci,ief de:c;h,J Emlu/ ras koch, u. s'. A. Mica,. WA lemmiss>% a L&sbing }lrn, 3.d. , 2 o,$ g NOV ~0 1991 W-STS 3/4 4-28
TABLE 4.4-4 19 PRIMARY COOLANT SPECIFIC ACTIVITY SAMPLE AND ANALYSIS PROGRAM i l TYPE Of MEASUREMENT SAMPLE AND ANALYSIS MODES IN WilICll SAMPLE AND ANALYSIS FREQUENCY AND ANALYSIS REQUIRED ,
- 1. Gross Activity Determination At least once per 72 hours 1, 2, 3, 4
- 2. Isotopic Analysis for DOSE EQUIVA- 1 per 14 days 1 LENf I-131 Concentration
- 3. Radiochemical for E Determination U 1 per 6 months
- 1
- 4. Isotopic Analysis for Iodine a) Once per 4 hours, 1,2,3,4,5 Including I-131, I-133, and 1-135 whenever the specific w activity exceeds 1.0
) pCi/ gram DOSE EQUIVALENT I-131 Jgres m g hdh c', or 100/E pCi/ gram and e 4 b) One sample between 2 1,2,3
, and 6 hours following ! a TilERMAL POWER change ! exceeding 15 percent
- of the RATED THERMAL POWER within a 1-hour period.
#U ntil the specific activity of the primary coolant system is restored within its limits.
- Sample to be taken af ter a minimum of 2 EFPD and 20 days of POWER OPERATION have elapsed since reactor was last subcritical for 48 hours or longer.
it 2 3gg h TMEEET 5! , tO b b
t l l v . , . . . . _ , 6 1 ... , , i 6 u,i
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- 6
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. . ; e i x.
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,,it i i
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6i i . , .
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l ,,,, g g i . . .
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. , si iN , , .. .
' UNACCEPTABLE ' '
< . *
- i . .,. . . ,1 i i , . .
6 i OPERATION i 4 , o i ei. . . . i e i .T e i . . i t i . i . i . E i , , . ..,
, eii e.,i -t x.,
i . i , i i e i
. . . . . . . . , , i i i . ,
e t . . 4 . 4 . ili 6 . t i , , , e e s
- 6. I I t i i li i i . ! I i i ' .
m '
.' i !
. . . i i, is e i , . i i . , . . i pg z
e . ... 6 A
. . .x , , 4 e i 6 e . 4 i e i , .
.2 i , i
. ... , , i . .. . . .x ... . ,. i , i . . . , i 5 . . , , , . , i .
1
, ii-ti , , . ... , , , . . , ,,
, ., , . ..ii i.,i 6 . 1i i .i i . . . . . .i a
i iii .. .... se i .,i . . . . . , . .
. i . ... . . i i i si e i . i . . i . , ,
> .ai t i,i i i . , , .,s i . . ! . . . # .
m .4 , i .,t . , iA ,4 , 4 , , e . , , ,
. .$ } , t , 9 . . e g , i 6 il ei . . 4 e i , t i l
=
g 100- .' .' . . i i , , ' , ' '.
. . , (.
i . ,,
- n. . ' ' ' liei t ' i i e' , \+'. e . ' i ei
,,,, . . i , 4 . i6 , 6 i i ex, . . . .i. . . . ,
es i e . . . i e . i ,e eti ; i .! i i . ..
- . . . . , . . , i . . . , i. i y . . . i . . . . ,
1 . . 6 ii i ei i i i i 6 . i i s. 61
, , i .
. , 6 i p i 6 . ! , i ACCEPTABLE '
z ' '
' ' 6+ ' i *'A * ' - .*
"j . . ! OPERATION ll4 . ll.l , ll'
, e l llll
< 50 , , , , ,,,, , , , 4 , , ,,,, , ,, , , , , . . ,
> e . . . 6 i , , i i . . . i i,,i . i i i i . . .,.6 5
g I . . I i .
' i t . .' i
, s . . ' ' .i ie +.
i i '
, e .' ' ' '
, , t
- i . '
. t 6 5 tj . . . - i . . i i i i , ei . i i . , ,
i , i , i i i
- g i 6
- 1. i . t , i .i e i . . i i ..it . i i .
m i .. . . t . . ., e i . .ii. . . . . .6 , l,
. e .. . , i i , , . , , , i , i . . . ,
8 . , ,
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, 4 1
ii 20 30 40 50 80 70 80 90 100 PERCENT OF RATED THERMAL POWER FIGURE 3.4-1 DOSE EQUIVALENT l-131 Primary Coolant Specific Activity Limit Versus Percent of RATED THERMAL POWER with the Primary Coolant Specific Activity >1.0gCi/ gram Dose Equivalent 1-131 E-STS 3/4 4-30 NOV 2 S
SE E-T~l . 14 . _ . _ __ _. _. . _ d - - - -- - -. , z
,g __ ._ .- -. -_ - _ .. ._ __ _ _ _ . ._ _ __ ._. __._. _. __ _ __- ___ _ .__ _
'~ ~
A gross radioactivity analysis shall consist of the quantitative measurement of the totai specific activity of the reactor coolant except for radionuclides with half-lives less than 10 minutes and all radioiodines. -- --- s i lhe total specific activity snall be the sum of the degassed beta gamma activity and the total of all identified gaseous activities in the sample within 2 hours after the sample is taken and extrapolated back g g to when the sample was taken. Determination of the contributors to the gross specific activity shall be -- -- o based upon those energy peaks identifiable with a 95% confidence level. The latest available data may be _. .__ [f, used for pure beta emitting radionuclides. 4 AAA _ Q A radiochemical analysis for E shall consist of the quantitative measurement of the specific activity for m each radionuclide, except for radionuclides with half-lives less than 10 minutes and all radioiodines, s which is identified in the reactor coolant. The specific activities for these individual radionuclides ._ _
; shall be used in the determination of E for the reactor coolant sample. Determination of the contributors t
. to E shall be based upon those energy peaks identifiable,with a 95% confidence level. -- '- -
i
, , l . ._ -_ ._ . . _ _ _. ._
3 g - . . . ._ _ _ __ ._ . _ _. ._. ._ ._ __ _ _ _ _. g _. . - _ _ . __ __ _ ._ _ __ _ ___ __ _ _ _ ._ _ __ __ _ _ z l - .
._ r ._. _ ._ ._._ __ _ _ _ _ _ _. . _ . .
o U. . - - ._ s 8 l . _ . . _ _ _ __. _ . . _ . __ _-._ _ ._.__ _. _. _ ___2 _. . . _ . __ __ _____ ___ _ _ ._ r i d m z o g g. s ~ N b
._,j____________.___._
( 35 6;
REACTOR COOLANT SYSTEM 3/4.4.9 FRESSURE/ TEMPERATURE LIMITS REACTOR COOLANT SYSTEM LIMITING CONDITION FOR OPERATION LACD 3.4.9.1 The Reactor Coolant System 4(except the pressurizer) temperature and pressure shall be limited in accordance with the limit lines shown on Figures 3.4-2 and 3.4-3 during heatup, cooldown, criticality, and inservice leak and hydrostatic testing with:
- a. A maximum heatup of (100)*F in any 1-hour period.
- b. A maximum cooldown of (100)"F in any 1-hour period.
- c. A maximum temperature change of less than or equal to (10)*F in any 1-hour period during inservice hydrostatic and leak testing operations above the heatup and cooldown limit curves.
APPLICABILITY: At all times. ACTION: h'ith any of the above limits exceeded, restore the temperature and/or pressure to within the limit within 30 minutes; perform an engineering evaluation to determine the effects of the out-of-limit condition on the structural integrity of the Reactor Coolant System; determine that the Reactor Coolant System remains acceptable for continued operation or be in at least HOT STANDBY within the next 6 hours and reduce the T and pressure to less than 200*F and 500psig,respectively,withinth0VEollowing30 hours. NC. SURVEILLANCE REQUIREMENTS 4.4.9.1.1 The Reactor Coolant System temperature and pressure shall be determined to be within the limits at least once per 30 minutes during system heatup, cooldown, and inservice leak and hydrostatic testing operations. 4.4.9.1.2 The reactor vessel material irradiation surveillance specimens shall be removed and examined, to determine changes in material properties, as required by 10 CFR 50, Appendix H in accordance with the schedule in Table 4.4-5. The results of these examinations shall be used to update Figures 3.4-2 and 3.4-3. y-STS 3/4 4-31 SOV 2 19M
i TABLE 4.4-5 REACTOR VESSEL MATERIAL SURVEILLANCE PROGRAM - WITl10RAWAL SCHEDULE h CAPSULE VESSEL LEAD NUMBER LOCATION FACTOR WITl10RAWAL TIME (EFPY)
% 3e Swp D<d. L o ke r e+
I n s s m
'T <n
-4 (n
... .... ... . . . . $ .i UI !!r ;j d jli] I"i Ulj $ !!h !!jjPRESSURE - TEMPERATUFIE jj - j h l lil h$ !! ij $ i
% W! iHi b Ii!: kr ':["H- : ' 'H! LIMIT DURING llYDROSTATIC ?: . l.. ! h!:I{h. !!i ".
dE " 26W
~ ~
;; 2'
;= mi. .= ]. y ,;;,; ={};; =. ;g TESTING OPERATIONS e
p iir "i N~ -i +3 I p'i t I! f92 T N: 7 .. ! =.a
; 42
- 4:- HF :::.
"=J::
M :9 ;L 22 nF f-tr n 24 "-? N'%{ R " 9 -
.9: u 2400 CURVES APPLICABLE FOR SERVICE
-l: a -
;:n a 2.. .:. = ..: .2:. ' '. 7. .+ ..f- := -
l r u - H m.
"p.
.=.:- . c: n :..: n; mi
'f
' " ~
.. L Z -
T: $l-
' ..;' Z G.d h $]j4 jb j}i
, PERIODS UP TO (15) EFPY (AND CONTAIN -
= ' p F:@,i '! y l g$ j; @ 3" O MARGINS OF 10'F AND 60 PSIG FOR - "" --- "' :
d ali f : Hi! bn 2' 4
-[ 2200 POSSIHLE INSTRUMENT ERRORS) ACCEPTABLE rj j ;.J.. g -);- i g" y gj g jjy gij
;j
.2, REGION FOR m =. :a. ;e r= = :. r.
q
" T"- :
L; lI y ,
"; h y 2000 .E ..s. ,
T.. ;;;.;. ;m E_.I. . . .: _. . . p u,.,-f.- flYDROSTATIC l} - g j. . J? "
! f y
ji F ]d U I paII!!!
.TES11NG OPERATIONS I I t MATERIALS BASIS. ifil i. ic !!-
--=m>
g 1800 ! 9 Ig h$
~ ~
us CONTROLLING MATERIAL-(RV LOWER SilELL) -
% f,[. .
',. (( lhq id hg , [
[ COPPER CONTENT: (0.16%) --
+- $AdCEUTEBLEIIII[I i
!il i!['
"! iI $I !flifi l[I] l' f g 1600 PHOSPilORUS CONTENT: (0.08%) . . . ..a OPERATION E ." r j! 9 ' "- ';"
RT NDT ORIGINAL: (10' F) gji -E ;r y I! f -
"1 so 1400 :RT NDTAFTER (15) EFPY @ 1/4T = {109* F) { 2 h j fi!y yf ur;! :1{
] h{ j 'j l D [ RTN DT AFTER (15) EFPY 9 3/4T = (77* F) 5 i:9,; g h'i L ^M :p u;ir g.g:
i,j g: I - - j, -
* * ' " " ' 'I " "' '" #8 #" "" *
.e. 3 1200 j .E
"
- E E 'W "" '- I .F '
'*'d j ((jijiji j' [ijj i y ') 4 i iN !El iiii i iii: ["[lj i
# $j ! I CRITICALITY LIMIT es ill! A .~
[ 1 in dj j$j !jh;I:! [iNi
@ .ih !i iiE iii. OENj! ! -l 4 +L +-il i: 32
- IJ i;u 'I
!! j!-"
" "'- : : PRESSURE - TEMPERATURE !!! g[;p o "- :
g;tpr y y n :p ie y i G"E r.li for at least 15 minutes, a (N.4 .
- b. By conducting overall air lock leakage tests at not less than P ,
MJR, psig), snd verifying the overall air lock leakage rate is within Hd its limit:
- 1. At least once per 6 months,# and
- 2. Prior to establishing CONTAINMENT INTEGRITY when-esim6enenee.
tr M n ,...'...... ... .:.. :f '..L -
'. ~ --7&'i liiopened sakan coarMAMr WN4LIW mz
...id.
sa{ regatr
- c. At least once per 6 months by verifying that only one door in each air lock can be opened at a time.
A. A4- Ianf ones par lo monSt by conduding ars uenell airlod ,prenun Nff to var:S1 door seal g,Jep}y, Wilh a measure.) /ed refe of /ers hi, or eBu=I lo H.95 secm. The provisions of Specification 4.0.2 are not applicable.
*":: r ; " - ' - i;; :-
- 3 r ' '_^ T : 0_
W-ICE CONDENSER 3/4 6-7B SEP 151981 l
CO N NMENT SYSTEMS C,0NTAI T' ISOLATION VALVE AND CHANNEL % ELD PRESSURIZATION SYSTEM (OPTIONA LIMITING CONDI N FOR OPERATION 3.6.1.4 The contai t isolation valve and channel we pressurization systems shall be OPERA 3 APPLICA8ILITY: MODES 1, 2, and 4. ACTION: With the containment isolation val . or cha el weld pressurization system inoperable, restore the inoperable s tem ,0PERABLE status within 7 days or L be in at least HOT STANDBY within the . 6 hours and in COLD SHUT 00WN within l the following 30 hours. SURVEILLANCE REOUIREMENTS , l 4.6.1.4.1 The cent nment isolation valve pressurization s, tem shall be I demonstrated OPE E at least once per 31 days by verifying hat tha system is pressurized t greater than or equal to 1.10 P (22 psig) ahd has adequate capacity to ma tain system pressure for at least,30 days.
\
4.6.1.4.2 e containment channel weld pressurization system shal e demon-t strated RABLE at least once per 31 days by verifying that the syse m is pret.su zed to greater than or equal to P (20 psig) and has adequate pacity to rr ntainsystempressureforatleast$0 days.
/
l W-ICE CONDENSER 3/4 6-8B OCT I 1975
l< r, CONTAINMENT SYSTEMS INTERNAL PRESSURE LIMITING CONDITION FOR OPERATION Y 3.6.1.5 % dontainment internal pressure shall be maintained between
-c.1 and +c.3 psig.
APPLICABILITY: MODES 1,.2, 3 and 4. ACTION: With the containment internal pressure outside of the limits above, restore the internal pressure to within the limits within 1 hour or be in at least HOT STANDBY within the next 6 hours and in COLD SHUTDOWN within the following 30 hours. SURVEILLANCE REQUIREMENTS Y 4.6.1.( -The M containment internal pressure shall be determined to within the limits at least once per 12 hours. i l t l l l l l W-ICE CONDENSER 3/4 6-9B OCT 1 1975
CONTAINMENT SYSTEMS AIR TEMPERATURE LIMITING CONDITION FOR OPERATION S 3.6.1.if .", ..., dontainment average air temperature shall be maintained:
- a. Between 7S'[and leo "F in the containment upper compartment, and
- b. Between toe *F and 12o *F in the containment lower compartment.
APPLICABILITY: MODES 1, 2, 3 and 4.
. ACTION:
With the containment average air temperature not conforming to the above limits, restore the air temperature to within the limits within 8 hours or be in at least HOT STANDBY within the next 6 hours and in COLD SHUTDOWN within the following 30 hours. SURVEILLANCE REQUIREMENTS f ' 4.6.1.g.1 The % containment upper compartment average air temperature 4 '^ #a11~4a; shall
' - - 'be - - the arithmetical average of ma.the temperature
~5vi $g f thIsons lideJ Selou.
% "N f re*E;"p weil be alfatnad oJ. leesf onu pas. 2q j,,,, .f,., af. fe,7p Location be e4' A. 6H wrng loce.S,nr:
- a. Elev. l.53' d k inle+ of y mien,,ual vufilafros uni /~ IA-o
- b. Gisv. L,5'3'o+ %< rnle +. af uspe,. w fain,.,et sesit/shon kaih I A.
- c. Elev. G,s 3 '4 4, mle 4 o[after cashinerd- Vedil'l7bs ""'l -
I- - Elss ten 4.6.1.6.2 lhe : 'a+ At intel
' :r; conta mentellower
$orcompartment coalais<anf vroft'I*l<on average b'Y air temperature shall be the arithmetical average of the t...,... :tr:: 1' ": ':'l: i ; ' _ . _
c.uco+ ate +empra.%< moeikin 1%g lic+ed 6a law. W7e,,ye,,}ur.e redeta-Location A.u locaohind tiea s : a;. ta $ eau (,. 2 9 %.ars % ,4. Iu,4 %, ep y,, su,_,.,,$
- a. Glu.s1o' d ik is,ht cl #a lowce confaismeaf veoliLka usil- M.
- b. GIev C-7c' o$.4, ,.,,kj ,j .;l,, hwee cesfas,,,,u/ ved// den unII U-
- c. 6Iev. 57e 'a} 6a mief *-l de tw cefuin,ned vesl'Ialun Wll N
- f. , flef no' a+ Aa inle.L a { Hro is e. a,s/ainmed resfilo/;on usil iD.
..~ s ....., ---+-, - + e - ego en ; _ .., , 1 7;- g, , g _. :
. . ... . x :: :- :- '- s
# cver L limil ny be resfaeal -}s so *F ;, /'10bt!~ 2,3 nd L/,
}{-ICECONDENSER 3/4 6-10B JUI.151979
\
CONTAINMENT SYSTEMS CONTAINMENT VESSEL STRUCTURAL IN1EGRITY LIMITING CONDITION FOR OPERATION b
- 3. 6.1. i The structural integrity of the containment vessel shall be maintained at a level consistent with the acceptance criteria in Specification 4.6.1.1.
L-APPLICABILITY: MODES 1, 2, 3 and 4. ACTION: With the structural integrity of the containment vessel not conforming to the , above requirements, restore the structural integrity to within tha limits prior to increasing tne Reactor Coolant System temperature above 200*F. l SURVEILLANCE REQUIREMENTS b 4.6.1.I The structural integrity of the containment vessel shall be determined during~the shutdown for each Type A containment leakage rate test (reference Specification 4.6.1.2) by a visual inspection of the exposed accessible interior
, and exterior surfaces of the vessel. This inspection shall be performed prior to the Type A containment leakage rate test to verify no 3pparent changes in appearance of the surfaces or other abnormal degradation. Any abnormal degra-dation of the containment vessel detected during the above required inspec-l tions shall be reported to the Commission pursuant to Specification 6.9.1.
i 9 W-ICE CONDENSER 3/4 6-11E DEC 15 B7B
CONTAINMENT SYSTEMS
'REACTat.
SM Mt9 BUILDING STRUCTURAL INTEGRITY LIMITING CONDITION FOR OPERATION 3.6.1.8 The structural integrity of the building shall be maintained at a level consistent with the acceptance criteria in Specification 4.6.1.K.
~+
APPLICABILITY: MODES 1, 2, 3 and 4. ACTION: With the structural integrity of the building not conforming to the above requirements, restore the structural integrity to within the limits prior to increasing the Reactor Coolant System temperature above 200*F. SURVEILLANCE REQUIREMENTS T reachey 4.6.1.3 The structural integrity of the .: MJ building shall be determined during the shutdown for each Type A containment leakage rate test (reference Specification 4.6.1.2) by a visuni inspection of the exposed accessible interict and exterior surfaces of the f.' y.f building and verifying no apparent changes
; in appearance of the concrete surfaces or other abnormal degradation. Any l abnormal degradation of the eheeM building detected during the above required inspections shall be reported to the Commission pursuant to Specification 6.9.1. o 1
l I 1 l l l W-ICE CCNDENSER 3/4 6-128 DEC 5 1979
i CONTAINMENT SYSTEMS MmLL15 4wTlGATIDD SiSTut
^ ^ l J' C '.': C ' .
LIMITING CONDITION FOR OPERATION 3.6.1.9Twoindependent;bi;?_yUOfon Ank E M f..., .. .:._.._;.$ystems shall be OPERABLE. APPLICABILITY: MODES 1, 2, 3 and 4. ACTION: With oner._.;h'NM'Y":' '"" ^=7 System inoperable, restore the inoperable system to OPERABLE status within 7 days or be in at least HOT STANDBY within the next 6 hours and in COLD SHUTDOWN within the following 30 hours. SURVEILLANCE REOUIREMENTS 6 Anu\ws %hlbm l 4.6.1.8f Each F - "#
; "" ' ;.. ; $ystem shall be demonstrated OPERABLE:
- a. At least once per 31 days on a STAGGERED TEST BASIS by initiating, from the control room, ficw through the HEPA filters and charcoal adsorbers and verifying that the system operates for at least 10 hours with the, heaters % epec Fng M
- b. At least once per 18 months or (1) after any structural maintenance on the HEPA filter or charcoal adsorber housings, or (2) following.
painting, fire or chemical release in any ventilation zone communi-cating with the system by: 4 ,m g:.7 +s,+ m4+w + u ,;.,+->my + 3 ,+ ,<,- - --<
; c ' - 1 ' ^^' . .u =mmu .:n;-+ '--"? + ' ""' " i t; . 4
-" : .1 .J...rhr;, th: i: t_ ', L 7,,. :n c' th g:t: te th:_
'^' ' ' i t., ,on , i nu uw ny . ways ....__;h ' " C:':- ' : . . : .;
":'1 , i ; I ; . th .. . . . ywo '. . 1% . n .. .. ; , ; t: i; t . . ." -
h) L ... I ti l . 3 w1u uur aL Luc by a wun. uwans. ( ui ay a . -.wu d' ::ti.; z ..?..: } ae2.kk.s
) 1. Verifying that the 90-" system satisfies the in place testing l acceptance criteria and uses the test procedures of Regulatory l Positions C.5.a, C.S.c and C.5.d of Regulatory Guide 1.52, Revision 2, March 1978 g and the system flow rate is 1000 8 cfm 1OL (,, u,g4 Sc.jk,9,rwid=u af AA151 ALSto Seh 6d 1 3. Verifying within 31 days after removal that a laboratory analysis l of a representative carbon sample obtained in accordance with t
Regulatory Position C.6.b of Regulatory Guide 1.52, Revision 2, W-ICE CONDENSER 3/4 6-13B APR I3 7g73
CONTAINMENT SYSTEMS SURVEILLANCE REQUIREMENTS (Continued) March 1978, meets the laboratory testing criteria of Regulatory Position C.6.a of Regulatory Gaide 1.52, Revision 2, March 1978p n e,@ @ gus.htw ef less Am 17..
]k. Verifying a system flow rate of 9000 cfm operation when tested in accordance with ANSI N510-1975.
10% during system
- c. After every 720 hours of charcoal adsorber operation by verifying within 31 days after removal that a laboratory analysis of a repre-sentative carbon sample obtained in accordance with Regulatory Position C.6.b of Regulatory Guide 1.52, Revision 2, March 1978, meets the laboratory testing criteria of Regulatory Position C.6.a of Regulatory Guide 1.52, Revision 2, March 1978%ea twA y l teJile puebhan*/
len No1%.
- d. At least once per 18 months by:
- 1. Verifying that the pressure drop across the combined HEPA filters and charcoa1 adsorber banks is less than.(6) inches Water Gauge while operating the system at a flow rate of 9000 cfm 10%. gN.6.)
- 2. Verifying that the sys. tem starts automatically on d contain-me g i ation test signalg(fg
- 3. Verifying that the filter cooling bypass valves can be manually opened.
c.S e a c. 6.,..pr bl
- 4. Verifying that each system [ produces a negative pressure of greater than or equal to (=^4e^fr) incnes W.G. in the annulus within (1) minute after a start signal.
- 5. Verifying that the[hebrs dissipate 45.0 le.7 kw when tested in accordante with ANSI N510-1975.
- e. After each complete or partial replacement of a HEPA filter bank by verifying that the HEPA filter banks remove greater than or equal to (99.95)%W of the 00P when they are tested in place in accordance with ANSI N510-1975 while operating the system at a flow rate of 9000 cfm 10%.
- f. After each complete or partial replacement of a charcoal adsorber bank by verifying that the charcoal adsorbers remove greater than or equal to 99.95% of a halogenated hydrocarbon refrigerant test gas when they are tested in place in accordance with ANSI N510-1975 while operating the system at a ficw rate of 1 coo cfm 10%.
T.R , .;_ .. . . _ m i:__. ;"'-'^-;'^^*'----""'"a ^%
....,__:, R - n .. _. "':'--~; ^' ^^* '- --- --t W-ICE CONDENSER 3/4 6-148 MAY l 51980
f CONTAINMENT SYSTEMS fu,C4C CONTAINMENTp ;;7 : _J '::;, SYSTEM l LIMITING CONDITION FOR OPERATION l l Ng % ge. lswee ca par +-.d 9 S Minst~ men & reu~ .F % e-3.6.1. E The sm .- _ :'--- ' / purge supply and exhaust isolation valvesj'** b."* "g shall be sealed closed. OperationIwith the (C :..;r purge supply and/or y exhaust isolation valves open hel be limited to less than or equal to 250 b.w.s .L. 4-06 h 5 per255 nyt for 4Le upper e.,nparfment of-+he conteIntuaah 4,'c le.nJar yeer prwl. Lad no more. APPLICABILITY: MODES 1, 2, 3, and 4. % 4 cme gate (one. suyly aniL one. eW>d asd ACTION: 4re ope.r, e d. ene br '. w . u. " 4 - containment purge supply and/or exhaust isol open, or with the o i ne. / ex aus iso ation valve (s) open for more the '
) ours per 365 days, en valve (s) within one hour or b 6 least HOT STANDBY within the next 6 hours , TDOWN A in the following 30 hours.
A TMSEET. SURVEILLANCE REOUIREMENTS See lhe lower amparfmed and raslewneotf rooo , of f-he ten hna'ninenf 4.6.1. .1 The (12 ' :': ::-':i n 7,' purge supply and exhaust isolation valveQshall be verified to bel
. 01,., _ :.t ':::^_- ; . 21 ' _ _ .1.
A Sealed -4erclosed at leastjge caHeineenper 31 day .
+ke uptoe any rved g 4.6.1.10.2 The umulative time that;,- '" '._.. purge supply and exhaust isolation valve have been open during ""- --* " ty: shall be determined at least once per 7 days.
***]**" g j ,,,.gf g ,,4 ,g,( sags 4.6.1 34.3 At least once per 6 months on a STAGGERED TEST BASIS eac sealed l closed fC ' M containment purge supply and exhaust isolation valve,shall I
be demonstrated OPERABLE by verifying that the measured leakage rate is less than or equal to (0. 05) L v c. shen ,ceswc;ted -!.'P, .
".f.cee uger e. f.< beat w i+b ced'ai M'"I*I 5**
4.6.1.10.4 At least once per 3 months each-f6-4wh-)-containment purge supply and exhaust isolation valve shall be demonstrated OPERABLE by verifying that the measured leakage rate is less than or equal to (0.0 ) L,x t.) hen premeltello k. W-ICE CONDENSER 3/4 6-15B gEp .3 g ggg1
CONTAINMENT SYSTEMS 3/4.6.2 DEPRESSURIZATION AND COOLING SYSTEMS CONTAINMENT SPRAY SYSTEM (
'.. ._..~....._.2 LIMITING CONDITION FOR OPERATION
' tf-3.6.2.1[TwoindependentcontainmentspraysystemsshallbeOPERABLEwitheach spray :;:t r capable of taking suction from the $WST and transferring suction to the containment sump. f APPLICABILITY: MODES 1, 2, 3 and 4.
ACTION: l With one containment spray system inoperable, restore the inoperable spray ! system to OPERABLE status within 72 hours or be in at least HOT STAN0BY within the next 6 hours; restore the inoperable spray system to OPERABLE status within the next 48 hours or be in COLD SHUTDOWN within the following 30 hours. SURVEILLANCE REQUIREMENTS 4.6.2.1 Each containment spray system shall be demonstrated OPERABLE:
- a. At least once per 31 days by verifying that each valve (manual,
, power operated or automatic) in the flow path that is not lo'cked sealed, or otherwise secured in position, is in its correct positon. en a b By verifyingr tbt c- "~"' etir gaaeferly baUdluY
' N each pump develops a discharge pressure of greater than or equal to 185 psig.www u; u-i n. a.:. ~ 3yed , J . :.- ' :. % .
- c. At least once per 18 months during shutdown, by:
Genfa!nnedNge.6 isolaiton (Sh
- 1. Verifying that each automatic valve 'in the flow path actuates to its correct position on a 4 test signal.
- 2. Verifying that each spray pump starts automatically on a C 6tamen+%e 6 is.\,b.a(SA test signal.
- d. At least once per 5 years by performing an air or smoke flow test through each spray header and verifying each spray nozzle is unobstructed.
- 5. hedy;nb %IexL cookine,ebs ray fut n= reevenfed fr ~ slar kag 6 ike. c.nk:n,,,ed fresrure sen s almospore fressare it teu % o,3 egal h c.2sp,:t.
- 4. <edst d valve i.s pr. w aj 4 ,,, e fru'm Adexksecaypu,.y;ube5a ,,nast-un.,(sm prass.,, g,, g,pa,,;ks, afnl sv iten, a. Ba c-t s e.1g
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'"*^f a9forf A m preun ie reked to~ w sya asa-a le ss Man ee W-ICE CONDENSER 3/4 6-168 . MAR 151978
DUKE POe ER COMPANY Form 00184 481;
~ !. i! ; ; DevJStation Unit File No. . t ' ' Subject !
IhDD By Date
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'[ , a. With any containment purge supply and/or exhaust isolation valve ! i j k'
( for the lower compartment or inTtrument room open or not sealed ij ; ; closed, close and/or seal closed that valve or' isolate the penetra- - ' tion (s) within 4 hours, otherwise be in at least HOT STANDBY within ' k
- s .the next 6 hours and in COLD SHUTDOWN within the following 30 hours.
.: p s p b. With tne containment purge supply and/or exhaust isolation valve (s) h i i-._ for the upper compartment open for more than 250 hours during a calendar ' p' year, close any open valve or isolate the penetration (s) within 4 hours, ' @ otherwise be in at least HOT STANDBY within the next 6 hours, and in jp COLD SHUTDOWN within the following 30 hours. j c. ll{ With a containment purge supply and/or exhaust isolation valve (s) i 1i [, having a measured leakage rate in excess of the limits of Specifica- i ' ii tions 4.6.1.9.3 and/or 4.6.1.9.4, restore the inoperable valve (s) to jp ' OPERABLE status within 24 hours, otherwise be in at least HOT , h STANDBY within the next 6 hours, and in COLD SHUTDOWN within the
! following 30 hours. ; ii
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CO .INMENT SYSTEMS 3/4.6 DEPRESSURIZATION AND COOLING SYSTEMS CONTAINM T SPRAY SYSTEM (No credit taken for iodine removal) LIMITING CON ' TION FOR OPERATION 1 / l 3.6.2.1 Two inde ndent containment spray systems s 11 be OPERABLE with each ! spray system capab of taking suction from the RWS and transferring suction l to the containment s p. APPLICABILITY: MODES 2, 3 and 4. ACTION:
- a. With one containm t spray syst inoperable and at least (four) containment coolin fans OPERA E, restore the inoperable spray system to OPERABLE s atuc wi in 7 days or be in at least HOT STANDBY within the next 6 hou s and n COLD SHUTDOWN within the following 30 hours.
- b. With two containment sp systems inoperable and at least (four) containment cooling fa ERABLE, restore at least one spray system to OPERABLE status wi in hours or be in at least HOT STANDBY within the next 6 ho rs and COLD SHUTDOWN within the following 30 l hours. Restore bo spray sy of initial loss o be in at le, ems to OPERABLE t HOT statusthe STANDBY within within next76days l
l hours and in COL SHUTDOWN with the following 30 hours.
- c. With one conta nment spray system 'noperable and one group of required con inment cooling fans operable, restore either the inoperable ray system or the inop able group of cooling fans to l OPERABLE s tus within 72 hours or b in at least HOT STANDBY within
[ the next hours and in COLD SHUTDOWN ithin the following 30 hours. Restore oth the inoperable spray syst and the inoperable group of coolin fans to OPERABLE status within days of initial loss or be in at east HOT STANDBY within the next hours and in COLD SHUTDOWN with' the following 30 hours. SURVEILI.ANC REOUIREMENTS
, s 4.6.2.1 Each containment spray system shall be demonstrat OPERABLE:
. At least once per 31 days by verifying that each va ve (manual, power operated or automatic) in the flow path that i not locked, sealed or otherwise secured in position, is in its co rect position.
W-ICE CONDENSEP. 3/4 6-17B MAR 151978
CONTAINMEh5sSYSTEMS SURVEILLANCE REQUIR NTS (Continued)
- b. By verifying, that recirculation # ow, each pump develops a discharge pressure of eater tha r equal to psig when tested pursuant to Speci 'catio .0.5.
- c. At least once per 18 mont, , ring shutdown, by:
- 1. Verifying that h automati valve in the flow path actuates to its correc position on a test signal.
- 2. Verifyin hat each spray pump star automatically on a test signal.
- d. At lea . once per 5 years by performing an air smoke flow test thro h each spray header and verifying each spra ozzle is u structed.
I l i l l l I l W-ICE CONDENSER 3/4 6-188 MAR 151978
CO AINMENT SYSTEMS SPRA DDITIVE SYSTEM (OPTIONAL) LIMITING 'DITION FOR OPERATION
\ f 3.6.2.2 The sp y additise system shall be OPERABLE w' h:
- a. A spray ditive tank containing a volume between and ga ons of between and . percent by weight NaOH solution, a d
- b. Twosprayad'tiveeductorseachcapab)/ e of adding Na0H solution from the chemi 1 additive tank to a vontainment spray system pump flow.
APPLICABILITY: MODES 1, 2, 3 nd 4. ACTION: With the spray additive system ino rab) , restore the system to OPERABLE status within 72 hours or be in at ka k HOT STANDBY within the next 6 hours; restore the spray additive system to WPERABLE status within the next 48 hours or be in COLD SHUTDOWN within the fo.1 ing 30 hours. SURVEILLANCE REQUIREMENTS 4.6.2.2
/ \
The spray additive s stem shall be dem strated OPERABLE:
- a. At least once per 1 days by verifying t at each valve (manual, power operated o. automatic) in the flow th that is not locked, sealed, or othe 'ise secured in position, 5 in its correct position.
- b. At least once er 6 months by:
- 1. Verifyi g the contained solution volume i the tank, and
- 2. Verif ng the concentration of the NaOH sol tion by chemical anal is.
- c. At leas nce per 18 months during shutdown, by veri ing that each l automapic valve in the flow path actuates to its corr t position on a i test signal.
- d. At 1 ast once per 5 years by verifying each solution flo rate (to be etermined during preoperational tests) from the follow'ng drain c nections in the sp. ray additive system:
. (Drain line location) gpm
- 2. (Drain line location) gpm i
W-ICE CONDENSER 3/4 6-19B MAR 15 lii78
CONThMENTSYSTEMS CONTAIN T COOLING SYSTEM (CPTIONAL) (Credit taken for i ine removal by spray syst s) LIMITING CONDI ON FOR OPERATION A I 3.6.2.3 (Two) inde ndent groups of containment coo ing fans shall be OPERABLE with (two) fan system to each group. (Equivalent o 100% cooling capacity.) APPLICA8ILITY: MODES 1, , 3 and 4. ACTION:
- a. With one group of th above require containment cooling fans inoperable and both co tainment sp y systems OPERABLE, restore the inoperable group of coo ng fans OPERA 8LE status within 7 days or be in at least HOT STANO withi the next 6 hours and in COLD SHUTDOWN within the follow g3 hours.
- b. With two groups of the above quired containment cooling fans inoperable, and both contain t spray systems OPERABLE, restore at least one group of cooling f ns o OPERA 8LE status within 72 hours or be in at least HOT STAN Y wi in the next 6 hours and in COLD SHUTDOWN within the follo ng 30 h urs. Restore both above required groups of cooling fans t OPERA 8LE atus within 7 days of initial loss or be in at least T STANDBY w hin the next 6 hours and in COLD SHUTDOWN within t following 30 ours.
- c. With one group of th above required con inment cooling fans inoperable and one ntainment spray systdm inoperable, restore the inoperable spray s stem to OPERA 8LE status ithin 72 hours or be in at least HOT STA 8Y within the next 6 hours and in COLD SHUTDOWN within the fall ing 30 hours. Restore the i operable group of containment cc ing fans to OPERABLE status wi in 7 days of initial loss or COLD be in tleastHOTSTANDBYwithinthenkt6hoursandin SHUTDOWt within the following 30 hours.
SURVEILLANCE RE00I ENTS s 4.6.2.3 Each oup of containment cooling fans shall be demonstr *ed OPERA 8LE:
- a. At east once per 31 days by:
. Starting each fan group from the control room and veri ing that each fan group operates for at least 15 minutes.
- 2. Verifying a cooling water flow rate of greater than or e ual to gpm to each cooler.
At least once per 18 months by verifyir.g that each fan group starts automatically on a test signal. W-ICE CONDENSER 3/4 6-208 MAR 151979 l
= hTAINMENTSYSTEMS CON NMENT COOLING SYSTEM (OPTIONAL) (No credit taken for iodine re val by spray stems) LIMITING C DITION FOR OPERATION s , I f 3.6.2.3 (Two) dependent groups of containment cooling ns shall be OPERABLE' ! with (two) fan s tems to each group. (Equivalent to 10 . cooling capacity.) ' APPLICABILITY: MOD 1, 2, 3 and 4. ACTION:
- a. With one group f the above required ntainment cooling fans ,
inoperable and b 'h containment spr systems OPERABLE, restore the ' inoperable group cooling fans t OPERABLE status within 7 days or be in at least HOT TANDBY withi he next 6 hours and in COLD SHUTDOWN within the llowing 3 hours. ! b. With two groups of the ove equired containment cooling fans inoperable, and both con i nt spray systems OPERABLE, restore at least one group of coolin ans to OPERABLE status within 72 hours or be in at least HOT ST within the next.6 hours and in COLD SHUTDOWN within the fol win 30 hours. Restore both above required groups of cooling fans o OPER LE status within 7 days of initial loss or be in at leas HOT STAN Y within the next 6 hours and in COLD SHUTDOWN withi the followin 30 hours.
- c. With one group of he above required ontainment cooling fans inoperable and e containment spray s tem inoperable, restore either the ino .rable group of containm t cooling fans or the inoperable sp ay system to OPERABLE statu within 72 hours or be in at least HOT STANDBY within the next 6 hour and in COLD SHUTDOWN within the ollowing 30 hours. Restore both he inoperable group of containme cooling fans and the inoperable sp y system to OPERABLE status w hin 7 days of initial loss or be in a least HOT STANDBY within he next 6 hours and in COLD SHUTDOWN with the following 30 hours SURVEILLANC REQUIREMENTS
, s 4.6.2.3 Each group of containment cooling fans shall be demonstrated ERABLE:
. At least once per 31 days by:
- 1. Starting each fan group from the control room and verifying hat each fan group operates for at least 15 minutes.
l h'-ICE CONDENSER 3/4 6-21B MAR 151979 L -
CONTAINMENT 5 Ms SURVEILLANCE REQUIREME (Continued)
- 2. Verifying a cooling w r ficw rate of greater than or equal to gpm to each coo r.
- b. At least once per months by vert ing that each fan group starts automati ly on a tes ignal.
i l l l 1 l l 'f-ICE CONDENSER 3/4 6-228 MAR 151978
CBliTAINMENT SYSTEMS 3/4 3 IODINE CLEANUP SYSTEM (OPTIONAL) LIMITING NDITION FOR OPERATION s , 3.6.3 Two i endent containment iodine cleanup syste shall be OPERABLE. APPLICABILITY: M S 1, 2, 3 and 4. ACTION: With one iodine cleanup s tem inoperable, restope the inoperable system to OPERABLE status within 7 dab or be in at least OT STANDBY within the next 6 hours and in COLD SHUTDOWN wb hin the followin 30 hours. SURVEILLANCE REQUIREMENTS s 4.6.3 Each iodine cleanup system shal
/e demonstrated OPERABLE:
- a. Atleastonceper31dayspnaST(.GGEREDTESTBASISbyinitiating, fromthecontrolroom,f)owthrou the HEPA filters and charcoal adsorbers and verifying /that the sy +em operates for at le'ast 10 hours with the heaters /on.
l /
- b. At least once per 1.8' months or (1) aftergny structural maintenance on the HEPA filter /or charcoal adsorber h sings, or (2) following painting,fireor/chemicalreleaseinanyv7tilationzonecommuni-cating with the ystem by:
- 1. Verifyin that the cleanup system satisfiegthe in place testing acceptance criteria and uses the test proced res of Regulatory Positi/ns C.S.a, C.S.c and C.S.d of Regulator Guide 1.52, Revisfon 2, March 1978, and the system flow ra is cfm 10%./
/
- 2. Verifying within 31 days after removal that a labo atory analysis of a representative carbon sample obtained in accor nce with egulatory Position C.6.b of Regulatory Guide 1.52, vision 2, March 1978, meets the laboratory testing criteria of gulatory Position C.6.a of Regulatory Guide 1.52, Revision 2, Ma h 1978.
- 3. Verifying a system flow rate of cfm 10% during syste operation when tested in accordance with ANSI N510-1975.
W-ICE CONDENSER 3/4 6-23B EN I 1979
CONTAINMENT SYSTEMS SURVEILLA REQUIREMENTS (Continued) s i
- c. After ery 720 hours of charcoal adsorber operation verifying within days after removal that a laboratory anal is of a repre-sentative arbon sample obtained in accordance wit Regulatory Position C. b of Regulatory Guide 1.52, Revisio 2, Maren 1978, meets the lab ratory testing criteria of Regula ry Position C.6.a of Regulatory ide 1.52, Revision 2, March 19 .
- d. At least once per 8 months by:
- 1. Verifying that t pressure drop ac ss the combined HEPA filters and charc 1 adsorber ban is less than (6) inches Water Gauge while o rating the jstem at a flow rate of cfm t 10%.
- 2. Verifying that the system st ts on either a Safety Injection Test Signal or on a Cont ent Pressure -High Test Signal.
- 3. Verifying that the filte c oling bypass valves can be opened by operator action.
[
- 4. Verifying that the h ters dis 'pate kw when tested in accordanc with ANSI N 10-1975.
- e. After each complete o partial replacem t of a HEPA filter bank by \
verifying that the H A filter banks remo e greater than or equal to (99.95)%* of the 00 when they are tested 'n place in accordance with ANSI N510-197 while operating the sys em at a flow rate of cfm 10%.
- f. After each co 'lete or partial replacement of charcoal adsorber i bank by veri fing that the charcoal adsorbers r ove greater than or i
' equal to 99 5% of a halogenated hydrocarbon ref 'gerant test gas when they re tested in place in accordance with A.SI N510-1975 while op ating the system at a flow rate of fm : 10%. l A 99.95% appl cable when a filter efficiency of 99% is assumed in the afety analyses; 9% when a filter efficiency of 90% is assumed. W-ICE CONDENSER 3/4 6-248 APR 151978
l l l CONTAINMENT SYSTEMS 3/4.6.g.5 CONTAINMENT ISOLATION VALVES l LIMITING CONDITION FOR OPERATION ; I 3.6.4 The containment isolation valves specified in Table 3.6-2 shall be OPERABLE with isolation times as shown in Table 3.6-2. APPLICABILITY: MODES 1, 2, 3 and 4. ACTION: With one or more of the isolation valve (s) specified in Table 3.6-2 inoperable, maintain at least one isolation valve OPERABLE in each affected penetration that is open and either:
- a. Restore the inoperable valve (s) to OPERABLE status within 4 hours, or
- b. Isolate each affected penetration within 4 hours by use of at least one deactivated automatic valve secured in the isolation position, or
- c. Isolate each affected penetration within 4 hours by use of at least one closed manual valve or blind flange, or d Be in at least HOT STANDBY within the next 6 hours and in COLD SHUTDOWN within the following 30 hours.
i SURVEILLANCE REQIIIREMENTS 3 4.6.4.1 The isolation valves specified in Table 3.6-2 shall be demonstrated OPERABLE prior to returning the valve to service after maintenance, repair or replacement work is performed on the valve or its associated actuator, control or power circuit by performance of a cycling test and verification of isolation time. l l l
- W-ICE CONDENSER 3/4 6-25B JUN 1 3 73
CONTAINMENT SYSTEMS SURVEILLANCE REQUIREMENTS (Continued) 3 4.6.#.2 Each isolation valve specified in Table 3.6-2 shall be demonstrated OPERABLE during the COLD SHUTDOWN or REFUELING MODE at least once per 18 months by: Ch
- a. Verifying that on a Phase A containment isolation 3t est signal, each Phase A isolation valve actuates to its isolation position.
- b. Verifying,that on a Phase B containment isolationA t signal, each Phase B isolation valve actuates to its isolation position. .
&te u.hil He Verifying that on a Containment [ 7 - - y "" gh__ . . . . '. . . . . . . t e s t c.
signal, each Purge and Exhaust valve actuates to its isolation position. 4.6.4.3 The isolation time of each power operated or automatic valve of Table 3.6-2 shall be determined to be within its limit when tested pursuant to Specification 4.0.5. W-ICE CONDENSER 3/4 6-26B SEP 2 81981
l r, TABLE 3.6-2 D
?? CONTAINMENT ISOLATION VALVES ??
HAXIMUM e ISOLAll0N { VALVE NUMBER FUNCTION TIME (5FC.)
~ A. PilAFE "A" ISOLATION BB-578# Steam Generator 1A Blowdown Containment Outside Isolation <10 BB-218# Steam Generator IB Blowdown C9ntainment Outside Isolation 210 88-61B# Steam Generator 1C Blowdown tontainment Outside Isolation 210 BB-10S# Steam Generator ID Blowdown Containment Outside Isolation 210 BB-56A# Steam Generator IA Blowdown Containment Inside Isolation 210 BB-19A# Steam Generator IB Blowdown Containment Inside Isolation 210 BB-60A# Steam Generator 1C Blowdown Containment Inside Isolation 210 BB-8A# Steam Generator 10 Blowdown Containment Inside Isolation 210 5d 88-1488# Steam Generator 1A Blowdown Containment Isolation Bypass *o BB-150B# Steam Generator 18 Blowdown Containment Isolation Bypass
{lo 88-149B# $10 7' Steam Generator IC Blowdown Containment Isolation Bypass $10 D? BB-1478# Steam Generator ID Blowdown Containment Isolation Bypass . -<10 CF-60# Steam Generator ID Feedwater Containment Isolation <5 CF-51# Steam Generator 1C Feedwater Containment Isolation 25 CF-42# Steam Generator 18 Feedwater Containment Isolation 75 CF-33# Steam Generator 1A Feedwater Containment Isolation 75 CA-149# Steam Generator IA Main feedwater to Auxiliary feedwater Nozzle Isolation ES CA-150# Steam Generator 1B Main Feedwater to Auxiliary Feedwater Nozzle Isolation CA-151# {5 Steam Generator IC Main Feedwater to Auxiliary Feedwater Nozzle Isolation (5 CA-152# Steam Generator 3D Main Feedwater to Auxiliary Feedwater Nozzle Isolation 25 CF-90# Steam Generator IA Feedwater Containment Isolation Bypass CF-89# {5 Steam Generator IB Feedwater Containment Isolation Bypass 55 CF-88# Steam Generator 1C Feedwater Containment Isolation Bypass CF-87# 15 Steam Generator ID Feedwater Containment Isolation Bypass s5 CA-185# Auxiliary Nozzle Temper SGIA $5 CA-186# Auxiliary Nozzle Temper SG1B $5 CA-187# Auxiliary Nozzle Temper SGIC $5 CA-188# Auxiliary Nozzle Temper SG1D 15
TABLE 3.6-2 (Continued) CONTAINMENT ISOLATION VALVES 9 MAXIMUM N I501Al10N h VALVE NUMBER FUNCTION TIME (SfC.) , '_ A. PHASE "A" ISOLAlION U KC-3058# Excess Letdown lix Supply Containment Isolation (Outside)
- KC-3158#
120 Excess Letdown lix Return lleader Containment Isolation (Outside) 120 KC-320A# NCOT Hx Supply lidr Containment Isolation (Outside) KC-3328# 120 NCDT lix Return lidr Containment Isolation (Inside) 120 KC-333A# NCDT lix Return lidr Containment Isolation (Outside) KC-429B 120 RB Drain lleader Inside Containment Isolation <10 KC-4308 RB Drain lleader Outside Containment Isolation 710 KC-3388# RV Support and /CP Cooler Supply Outside Containment Isolation KC-4248# RV Support and KCP Cooler Return Inside Containment Isolation [40 KC-42bA# 140 RV Support and P Cooler Return Outside Containment Isolation 140 NB-2608 Reactor Makeup Water Tank to flush Header 110 NC-S3B Nitrogen to Pressurizer Relief Tank #1 Containment Isolation Outside 110 o- NC-54A Nitrogen to Pressurizer Relief Tank #1 Containment Isolation Inside <10 A>
" NC-56B RMW Pump Disch Cont Isolation 210 NC-195B NC Pump Motor Oil Containment Isolation Outside 510 NC-196A NC Ptap Motor Oil Containment Isolation Inside <10 NF-228A Unit 1 Air llandling Units Glycol Supply Containment Isolation Outside 110 Nf-233B Unit 1 Air llandling Units Glycol Return Containment Isolation Inside Nf-234A 110 Unit 1 Air flandling Units Glycol Return Containment Isolation Outside <
_10 NI-4 7A Accumulator N., Supply Outside Containment Isolation NI-95A $10 Test lidr Inside Containment Isolation <10 NI-96fl Test Ildr Outside Containment Isolation 710 NI-120B" Safety Injection Ptap to Accumulator fill Line Isolation NI-1228# 310 llot leg Injection Check INI124, INIl28 Test Isolation 110 NI-1548# llot leg Recirculation Check NI125, Nil 29 Test Isolation N1-25SB 110 Uill Check Valve Test Line Isolation <10 NI-258A Ull! Check Valve Test Line Isolation 710 NI-264tl UHI Check Valve Test Line Outside Containment Isoaltion 510
1 1 TABLE 3.6-2 (Continued) CONTAINHENT ISOLATION VALVES O HAXIMOH g ISOLAll0N g VALVE NUMBER FUNCTION TlHE ($1C.) h A. PHASE "A" ISOLATION 5 H NI-266A UllI Check Valve Test Line Inside Containment Isolation slo
- NI-267A UllI Check Valve Test Line Inside Containment Isolation NI-153A# 510 llot Leg Injection Check NI156, NI159 Test Isolation (10 NH-3A Pressurizer Liquid Sample Line Inside Containment Isolation slo NH-6A Pressurizer Steam Sample Line Inside Containment Isolation 101 NH-78 Pressurizer Sample Header Outside Contairment Isolation (10 NH-22A NC Hot Leg A Sample Line Inside Containment Isolation 710 NH-25A NC Hot Leg 0 Sample Line Inside Containment Isolation 710 NH-268 NC llot Legs Sample Hdr Outside Contaliment Isolation 310 NH-728# NI Acctmulator IA Sample Line Inside Containment Isolation $10 NH-758# NI Accumulator 18 Sample Line Inside Containment Isolation $10 g NH-78B# NI Acctmulator 1C Sample Line Inside Containment Isolation $10 o NH-818# NI Accumulator ID Sample Line Inside Containment Isolation <10 p NH-82A# NI Acctmulator Sample Hdr Outside Containment Isolation [10 g NH-187A# SG 1A Upper Shell Sample Containment Isolation Inside 110 NH-190A# SG 1A Blowdown Line Sample Containment Isolation Inside <10 NH-1910# SG 1A Sample lidr. Containment Isn1ation Outside 710 NH-1978# SG IB Upper Shell Sample Containment Isolation Inside 710 NH-200B# SG 1B Blowdown Line Sample Containment Isolation Inside 710 NH-201A# SG 18 Sample Hdr Containment Isolation Outside 710 NH-207A# SG IC Upper Shell Sample Containment Isolation Inside 710 NH-210A# SG IC Blowdown Line Sample Contairment Isolation Inside 710 NH-211B# SG IC Sample Hdr Containment Isolation Outside 210 NH-2178# SG ID Upper Shell Sample Containment Isolation Inside 710 NH-220B# SG 10 Blowdown Line Sample Containment Isolation Inside 210 NH-221A# SG ID Sample lidr Containment Isolation Outside 710 NV-ISB# Letdown Containment Isolation Outside <10 NV-89A NC Pumps Seal Return Containment Isolation Inside 210 NV-918 NC Pumps. Seal Return Containment Isolation Outside 210 NV-314B Charging Line Containment Isolation Outside 710
TABLE 3.6-2 (Continued) CONTAINMENT ISOLATION VALVES 9 g MAXIMUM C ISOLAlION y val.VF NUMBER FUNCTION TIME (SEC.) h A. PHASE "A" ISOLATION 5-8
~
NV-11A# 45 gpm Letdown Orifice Outlet - Containment Isolation $10 NV-13A# 75 OPm Letdown Orifice Outlet - Containment Isolation 110 NV-10A liigh Pressurizer Letdown Orifice Outlet - Containment Isolation $10 NV-872A Standby Makeup Pump to RCS seals *
$10 RF-38911 Interior Fire Protection Containment Hose Rack Isolation Valve 15 (Outside Containment)
RF-4478 Reactor Building Sprinklers Contaisunent Isoaltion Valve 15 (Outside Containment) Vil-830 Breathing Air Unit 1 Containment Isolation 110 m VY- 180# Containment #2 Purge to Annulus Inside Containment Isolation 110 2 VY-17A# Containment #2 Purge to Annulus Outside Containment Isolation 110 m VY-ISB# Containment #2 Purge Blower Outlet, Containment Isolation (Outside) 1]O VI-312A RB Isolation Valve for VI Supply to annulum Vent. 110 V P- Ill*
- Upper Contailwnent Purge Supply #1 Outside Isolation VP-2A** 15 Upper Containment Purge Supply #1 Inside Isolation 15 VP-30^^ Upper Containment Purge Supply #2 Outside Isolation VP-4A** 15 Upper Contaisment Purge Supply #2 Inside Isolation 15 VP-68^^ Lower Containment PurDe Supply #1 Outside Isolation VP-/A^^ 15 Lower Containment Purge Supply #1 Inside Isolation 15 VP- Bil *
- Lower Containment Purge Supply #2 Outside Isolation 15 VP-9A^^ Lower Containment Purge Supply #2 Inside Isolation 15 VP-10A*^ Upper Contain:nent Purge Exhuast #1 Inside Isolation 15 VP-11B** Upper Containment Purge Exhaust #1 Outside Isolation VP-12A** 15 Upper Containment Purge Exhaust #2 Inside Isolation 15 VP-138^^ Upper Containment Purge Exhaust #2 Outside Isolation VP-ISA^^ 15 lower Containment Purge Exhaust #1 Inside Isolation 15 VP-16B^^ Lower Containment Purge E-xhuast #1 Outside Isolation VP-1/A** 15 Incore Instru. Room Purge Supply Inside Isolation 15 VP- 1811*
- Incore Instru. Room Purge Supply Outside Isolation 15
TABLE 3.6-2 (Continued) CONTAINMENT ISOLATION VALVES s> MAXIMUM i ISOLAl10N g VALVE NUMBER FUNCTION TIME ($fC d A. PilASE "A" ISOLATION VP-19A** Incore Instru. Room Purge Exhaust Inside Isolation VP-20B** 15 Incore Instru. Room Purge Exhaust Outside Isolation
]5 VQ-2A Containment Air Release Inside Isolation 15 VQ-3B Containment Air Release Outside Isolation $5 VQ-150 Containment Air Addition Outside Isolation 15 VQ-16A Containment Air Addition Inside Isolation <S VS-54B Unit 1 Containment Header Outside Isolation _lb M . . w . n,im u u l, mm y m . . !.. d; S :?:t! _ ==M-44-36 % m. ._.;r' **- - h - Mid; R;.hih.
- ttt
-t' -
WL-8078# NCDT Pumps Discharge Outside Containment Isolation <10
? WL-805A# NCDT Pumps Discharge Inside Containment Isolation 210 U$ WL-450A NCDT Vent Inside Containment Isolation E10 WL-451B NCDT Vent Outside Containment Isolation 210 WL-825A# RB Sump Pump Discharge Inside Containment Isolation WL-8278# RB Sump Pump Discharge Outside Containment Isolation {lo WL-867A $10 Containment Vent Unit Drains Inside Containment Isolation <10 WL-8690 Containment Vent Unit Drains Outside Containment Isolation [10 YH-1198 Demin. Water Containment Outside Isolation 110 B. PilASE "B" ISOLATION l
KC-3388 NC Pump Supply lleader Pent. Isolation (Outside) 140 KC-424B NC Pumps Return lidr. Pent. Inside Isolation <40 KC-425A NC Pumps Return lidr. Outside Isolation [40 l
)
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- ~ $ mA*
TABLE 3.6-2 (Continned) CONTAINMENT ISOLA 110N VALVES E E MAXIMUM e ISOLATION c- VALVE NUMBER FUNCTION E lillE (SEC.)
~' C. MANUAL
~
IVY-4* Containmerit il2 Sample Supply Cont Isol N/A IVY-10* Containment 112 Sample Return Containment Isolation N/A 1fW-1A Refueling Water 1FW-328 Refueling Water $10
$10 IFW-48 Refueling Water N/A INV-862#* Pressurize Auxiliary Spray ND Outside Containment N/A IWLA-21#* Steam Geneiator Drain Pump Discharge Outside Containment Isolation N/A IWLA-24#* Steam Generator Drain Pump Discharge Outside Containment Isolation N/A R
C May be opened on an intermitten basis under administrative control. T Q* d Valve also receives a liigh Radiation (11) isolation signal.
# Not subject to Type C leakage tests.
NOTE: Times are for valve operation only, and do not include any sensor response or circuit delay times. See 3/4 3.2 for system actuation response times.
CO INMENT SYSTEMS 3/4. CCMBUSTIBLE GAS CONTROL vDR0GE NITORS
, TING COND TION FOR OPERATION .. . ~ -
- 3. 6. 4.1 Two indepe ent containment hydrogen monit - shall be OPERABLE.
APPLICABILITY: MODES and 2. < ACTION: With one hydrogen monitor in erable, e ~ tore the inoperable monitor to OPERABLE status within 30 days or be- at least HOT STANDBY within the next 6 hours.
\
\
\
l SURVEILLANCE REQUIREMEN
\\
\ N 4.6.4.1 Each by ogen monitor shall be demonstrhted OPERABLE by the performance of a CHANNEL C .K at least once per 12 hours, an M ALOG CHANNEL OPERATIONAL TEST at leas ' nce per 31 days, and at least once pe'r 92 sdays on a STAGGERED TEST BASIS performing a CHANNEL CALIBRATION using hydrogen gas mixtures to obtain cal' ration points of: \\
- a. Zero volume percent hydrogen. '
. Nine volume percent hydrogen.
1 CATAWBA - UNIT 1 3/4 6-28
TABLE 3.6-2 sc E
- R CONIAINHENT ISOLATION VALVES /
n ,/ E s / y VALVE NUMBER FUNCTION MAKIMUM lq ISOLATION'ilHE_(Seconds) x
/
A. PilASE "A" ISOLATION / 1.
/
/
- 2. /
! B. PilASE "B" ISOLATION ,
- 1. -
/
- 2. -
i - C. CONTAINMENT PURGE AND EXilAUST 4 g 1. s 7 2. re M D. MANUAL 1.
,2, E. OtilER 1.
i 2. o
- O A May be opened on an intermittent basis under administrative control.
~n
**The provisions of Specification 3.0.4 are not applicable.
i
.- y 12 o Not subject to Type C leakage tests.
I l
l 20NTAIN. MENT SYSTEMS 3/4.6.Si COMBUSTIB)E GAS CONTROL HYDROGEN MONITORS LIMITING CONDITION FOR OPERATION r i l 3.6.4.1 Two independent containment hydrogen monitors shall be OPERABLE. l APPLICABILITY: MODES 1 and 2. ACTION: With one hydrogen monitor inoperable, restore the inoperable monitor to OPERABLE status within 30 days or be in at least HOT STANDBY within the next 6 hours. SURVEILLANCE REQUIREMENTS 4 4.6.1.1 Each hydrogen monitor shall be demonstrated OPERABLE by the performance of a CHANNEL CHECK at least once per 12 hours, an ANALOG CHANNEL OPERATIONAL TEST at least once per 31 days, and at least once per 92 days on a STAGGERED g a CHANNEL CALIBRATION using :- - ~" --"'d"#-- ~ hA.Ien TEST ys e u W BASIS by performi{rayu es 1. eL+,;n au q.ufs of a."fme volume percent hydrogen, "--- ~#"^^':- b.Neew volume percent hydrogen. ic. ;..;; #+- ra W-ICE CONDENSER 3/4 6-28B SEP 151981 1
l 1 I CONTAINMENT SYSTEMS ELECTRIC HYDROGEN RECOMBINERS - W l LIMITING CONDITION FOR OPERATION 3.6. 2 Two independent containment hydrogen recombiner systems shall be OPERABLE. l t i APPLICABILITY: MODES 1 and 2. i ACTI0ft: With one hydrogen recombiner system inoperable, restore the inoperable system to OPERABLE status within 30 days or be in at least HOT STANDBY within the next 6 hours. { SURVEILLANCE REQUIREMENTS N 4.6.f.2 Each hydrogen recombiner system shall be demonstrated OPERABLE:
- a. At least once per 6 months by verifying during a recombiner system functional test that the minimum heater sheath temperature increases to greater than or equal to 700 F within 90 minutes. Upon reaching 700 F, increase the power setting to maximum power for 2 minutes and verify that the power meter reads greater than or equal to 60 Kw.
- b. At least once per 18 months by:
- 1. Performing a CHANNEL CALIBRATION of all recombiner instrumentation and control circuits, 1
l 2. Verifying through a visual examination that there is no evidence of abnormal conditions within the recombiners enclosure (i.e. , loose wiring or structural connections, deposits of foreign materials, etc.), and
- 3. Verifying the integrity of all heater electrical circuits by performing a resistance to ground test following the above required functional test. The resistance to ground for any heater phase shall be greater than or equal to 10,000 ohms.
W-ICE CONDENSER 3/4 6-29B AUG 6 1981
CONTAINMENT SYSTEMS HYDRO N PURGE CLEANUP SYSTEM (If less than two hydrogen recombi rs available) LIMITING DITION FOR OPERATION s , 3.6.5.3 A cont nment hydrogen purge cleanup system s 11 be OPERABLE and capable of being owered from a minimum of one OPERA E emergency bus. APPLICABILITY: MOD 1 and 2. ACTION: sith the containment hydro en purge cleanup stem inoperable, rest 7e the hydrogen purge cleanup syst to OPERABLE s atus within 30 days or be in at least HOT STANOBY within 6 ho rs. SURVEILLANCE REQUIREMENTS 4.6.5.3 The hydrogen purge cleanu s tem shall be demonstrated OPERABLE:
- a. At least once per 31 d ys by i itiating, from the control room, flow through the HEPA filt rs and ch coal adsorbers and verifying that the system operates or at least hours with the heaters on.
- b. As least once per 8 months or (1) a ter any structural maintenance on the HEPA filt or charcoal adsorb housings, or (2) following painting fire o chemical release in a ventilation zone communicating th the system by:
- 1. Verifyi that the cleanup system sat fies the in place testin acceptance criteria and uses o test procedures of Regul ory Positions C.5.a, C.5.c and C. .d of Regulatory Guide 1.52, Revision 2, March 1978, and t e system flow rate is cfm 10%.
- 2. V ifying within 31 days after removal that a laboratory alysis of a representative carbon sample obt ined in ccordance with Regulatory Position C.6.b of Re latory Guide 1.52, Revision 2, March 1975, meets the la ratory testing criteria of Regulatory Position C.6.a of ulatory Guide 1.52, Revision 2, March 1978.
- 3. Verifying a system flow rate of cfm 10% during ystem operation when tested in accordance with ANSI N510-197 .
W-ICE CONDENSER _ 3/4 6-30B
CONTAhMENTSYSTEMS SURVEILLAN. REQUIREMENTS (Continued)
. 1
- c. After very 720 hours of charcoal adsorber ope ation by verifying within 1 days after removal that a laborato analysis of a repre-sentativ carbon sample obtained in accord ce with Regulatory Position C. ,.b of Regulatory Guide 1.52, vision 2, March 1978, meets the lifboratory testing criteria of egulatory Position C.6.a of Regulatory de 1.52, Revision 2, rch 1978.
- d. At least once pe 18 months by:
- 1. Verifying that he pressure rop across the combined HEPA filters and charqoal adsor.er banks is less than (6) inches Water Gauge whilehoperat' g the system at a flow rate of "
cfm 10%. \
- 2. Verifying that the f' 1er cooling bypass valves can be manually opened.
- 3. Verifying that ti heaters., dissipate i kw when tested in accor nce with ANSI N510-1975.
- e. After each complet or partial re cement of a HEPA filter bank by .
verifying that t HEPAfilterbankkremovegreaterthanorequalto (99.95)%" of th 00P wnen they are tested in place in accordance with ANSI N510- 975 while operating thi system at a flow rate of* cfm _ 10%.
- f. After each omplete or partial replacementgof a charcoal adsorber bank by ve ifying that the charcoal adsorbegs remove greater than or equal to 9.95% of a halogenated hydrocarbon \ refrigerant test gas when the are tested in place in accordance wl4h ANSI N510-1975 while o erating the system at a flow rate of \ cfm 10%.
t l (
- l 99.95% pplicable when a filter efficiency of 99% is assumed in t e safety analys s; 99% when a filter efficiency of 90% is assumed.
l l l W-ICE CONDENSER 3/4 6-31B A R 151978 t
CONTAINME YSTEMS HYDROGEN MIXI SYSTEM (OPTIONAL) LIMITING CONDITION R OPERATION s , 3.6.5.4 Two independent drogen mixin systems shall be OPERABLE. APPLICABILITY: MODES 1 and . ACTION: With one hydrogen mixing system operable, restore the inoperable system to OPERABLE status within 30 days r e in at least HOT STANOBY within the next 6 hours. SURVEILLANCE REOUIREMEN75 s
,f 4.6.5.4 Each hydro n mixing system shall be demonstrated OPERABLE:
- a. At least once per 92 days on a STAGG ED TEST BASIS by starting each system a the control room and verit ing that the system operates for a ast 15 minutes.
- b. At 1 st once per 18 months by verifying system flow rate of at lea cfm.
I W-ICE CONDENSER 3/4 6-328 AUG 6 1981
CONT MENT SYSTEMS 3/4.6.6 NETRATION ROOM EXHAUST AIR CLEANUP SYSTEM (OPTIONAL LIMITING CONDI 'ON FOR OPERATION A I 3.6.6 Two independe containment penetration room exh st air cleanup systems shall be OPERA ' E. APPLICABILITY: MODES 1, 3 and 4. ACTION: With one containment penetrati room exhaust a' cleanup system inoperable, restore the inoperable system to PERABLE stat s within 7 days or be in at least HOT STANDBY within the next hours and in COLD SHUTDOWN within the following 30 hours. SURVEILLANCE RE0VIREMENTS v 4.6.6 Each containment penetration r om e aust air cleanup system shall be demonstrated OPERABLE:
- a. At least once per 31 day on a STAGu RED TEST BASIS by initiating, l from the control room, low through t e HEPA filters and enarcoal adsorbers and verifyi that the syste operates for at least 10 hours with the heate on.
- b. At least once per months or (1) after ny structural maintenance on the HEPA filte or charcoal adsorber ho ings, or (2) following painting, fire o chemical release in any v tilation zone communi-cating within t system by:
- 1. Verifyin that with the system operating a flow rate of l cfm 1 and exhausting through the HEPA 'lters and charcoal
! adsorb s, the total bypass flow of the sys m to the facility
- vent, neluding leakage through the system d verting valves, is less whan or equal to 1% when the system is t sted by admitting col DOP at the system intake. (For systems 'th diverting va es.)
- 2. rifying that the cleanup system satisfies the 'n place testing cceptance criteria and uses the test procedures f Regulatory Positions C.5.a, C.5.c and C.5.d of Regulatory Gul e 1.52, Revision 2, March 1978, and the system flow rate is cfm 10%.
W-ICE CONDENSER 3/4 6-33B I M9
CONTAINMEN SYSTEMS SURVEILLANCE OUIREMENTS (Continued) s e
- 3. V ifying within 31 days after removal tha a laboratory anal-ysi of a representative carbon sample o ained in accordance with egulatory Position C.6.b of Regu tory Guide 1.52, Revision 2, Ma h 1978, meets the laboratory t sting criteria of Regula-tory P ition C.6.a of Regulatory G de 1.52, Revision 2, March 1978.
- 4. Verifying system flow rate of cfm 10% during system operation en tested in accor ance with ANSI N510-1975.
- c. After every 720 ho 'rs of charcoa adsorber operation by verifying within 31 days afte removal t t a laboratory analysis of a repre-sentative carbon sa le obtai d in accordance with Regulatory Position C.6.b of Re latory uide 1.52, Revision 2, March 1978, meets the laboratory t stin criteria of Regulatory Position C.6.a of Regulatory Guide 1.5 , evision 2, March 1978.
- d. At least once per 18 mo t by:
- 1. Verifying that ' e pre ure drop across the combined HEPA filters and ch . coal ad rber banks is less than (6) incnes Water Gauge w ile operat g the system at a flow rate of cfm 10%.
- 2. Verifying hat the system s rts on a Safety Injection Test Signal.
- 3. Verifyi g that the filter cool g bypass valves can be manually opene
- 4. Veri ying that the heaters dissip +e kw when te ed in accordance with ANSI N51 -1975.
- e. After ach complete or partial replacemen of a HEPA filter bank by verif ing that the HEPA filter banks remov greater than or equal to (99.5)%"oftheDOPwhentheyaretestedikplaceinaccordance l
l wi ANSI N510-1975 while operating the syst m at a flow rate of cfm 10%.
- f. fter each complete or partial replacement of charcoal adsorber bank by verifying that the charcoal adsorbers r$ move greater than or equal to 99.95% of a halogenated hydrocarbon re, igerant test gas when they are tested in place in accordance with NSI N510-1975 while operating the system at a flow rate of cfm 10%.
99'.95% applicable when a filter efficiency of 99% is assumed 'n the safety analyses; 99% when a filter efficiency of 90% is assumed. W-ICE CONDENSER 3/4 6-348 App y 3 7g7g
J _..-_..____.-.o_.,_.._ CONTAINMENT SYSTEMS hb -
#5? HYDROGEN CONTROL DISTRIBUTED IGNITION SYSTEM LIMITING CONDITION FOR OPERATION 3.6.4.3 The Primary Containment Distributed Ignition System shall be OPERABLE.
APPLICABILITY: MODES 1 and 2. l ACTION: With one train of the Distributed Ignition System inoperable, restore the inoperable system to OPERABLE status within 7 days or increase the surveillance interval of Specification 4.6.4.3 from 92 days to 7 days on the OPERABLE train until the inoperable train is returned to OPERABLE status. SURVEILLANCE REQUIREMENTS 4.6.4.3 The Distributed Ignition System shall be demonstrated OPERABLE: f\
- a. At least once per 92 dcys by energizing the supply breakers and verifying that at least 64 of 66- igniters are energized,* and
- b. At least once per 18 months by verifying the temperature of each igniter is a minimum of 1700*F.
Inoperable igniters must not be on corresponding redundant circuits which
- provide coverage for the same region.
! A \
i 3/4 6-33 1
CONTAINMENT SYSTEMS 3/4.6. f ICE CONDENSER ICE BED LIMITING CONDITION FOR OPERATION 5 3.6.1.1 The ice bed shall be OPERABLE with:
- a. The stored ice having a boron concentration of at least 1800 ppm boron as sodium tetraborate and a pH of 9.0 to 9.5,
- b. Flow channels through the ice condenser,
- c. A maximum ice bed temperature of less than or equal to 27*F,
- d. A total ice weight of at least (ih499;609) pounds at a 95% level of confidence, and +
'L, M, ow
- e. 194A ice baskets.
ADPLICABILITY: MODES 1, 2, 3 and 4. ACTION: . With the ice bed inoperable, restore the ice bed to OPERABLE status within 48 hours or be in at least HOT STANDBY within the next 6 hours and in COLD SHUT-
'DOWN within the following 30 hours.
1 SURVEILLANCE REQUIREMENTS l 4.6. 1 The ice condenser shall be determined OPERABLE:
- a. At least once per 12 hours by using the ice bed temperature monitor-ing system to verify that the maximum ice bed-temperature is less than or equal to 27'F.
l b. At least once per 9 months by: l l 1. Chemical analyses which verify that at least 9 representative l samples of stored ice have a boron concentration of at least i 1800 ppm as sodium tetraborate and a pH of 9.0 to 9.5 at 20*C. iv?
- 2. Weighing a representative sample of at least 144 ice baskets and verifying that each basket contains at least lbs of
- ice. The representative sample shall include 6 baskets from j
each of the 24 ice condenser bays and shall be constituted of 1 W-ICE CONDENSER 3/4 6-35B JUN 1 1979 i
CONTAINMENT SYSTEMS SURVEILLANCE REOUIREMENTS (Continued) IP1 one basket each from Radial Rows 1, 4, 6, 8 and 9 (or from
! the same row of an adjacent bay if a basket from a designated row cannot be obtained for weighing)i within each bay. If any i basket is found to contain less than pounds of ice, a representative sample of 20 additional baskets from the same bay shall be weighed. The minimum average weight of ice from the 20 additional baskets and the discrepant basket shall not be less than MjMPpounds/ basket at a 95% level of confidence.
s u 1- y i The ice cond'enser shall also4 subdivided into 3 groups of baskets, as follows: Group 1 - bays 1 through 8, Group 2 - bays 9 through 16, and Group 3 - bays 17 through 24. The minimum average ice weight of the sample baskets from Radial Rows 1, 2, 4, 6, 8 and 9 in each group shall not be less than (7- @ 1466 pounds / basket at a 95% level of confidence. The minimum total ice condenser ice weight at a 95% level of confidence shall be calculated using all ice basket weights determined during this weighing program and shall not be less than pounds.
- 3. Verifying, by a visual inspection of at least two flow passages per ice condenser bay, that the accumulation of frost or ice on flow passages between ice baskets, past lattice frames, through the h+ a-ad"+ a = ^ top deck floor grating, or past the lower inlet plenum support structures and turning vanes is restricted to a thickness of less than or equal to 0.38 inches. If one flow passage per bay is found to have an accumulation of frost or ice with a thickness of greater than or equal to 0.38 inches, a representative sample of 20 additional flow passages from the same bay shall be visually inspected. If these additional flow passages are found acceptable, the surveillance program may proceed considering the single deficiency as unique and accept-able. More than one restricted flow passage per bay is evidence of abnormal degradation of the ice condenser.
- c. At least once per 40 months by lifting and visually inspecting the accessible portions of at least two ice baskets from each 1/3 of the
, ice condenser and verifying that the ice baskets are free of detri-mental structural wear, cracks, corrosion or other damage. The ice baskets shall be raised at least (12) feet for this inspection. W-ICE CONDENSER 3/4 6-36B JAN 151980 L
CONTAINMENT SYSTEMS ICE BED TEMPERATuk: ..JNITORING SYSTEM LIMITING CONDITION FOR OPERATION 5 3.6.%.2 The ice bed temperature monitoring system shall be OPERABLE with at least 2 OPERABLE RTD channels in the ice bed at each of 3 basic elevations (4tf,go3_"and SS' above the floor of the ice condenser) for each one third of the ice ccndenser. APPLICABILITY: MODES 1, 2, 3 and 4. ACTION:
- a. With the ice bed temperature monitoring system inoperable, POWER OPERATION may continue for up to 30 days provided:
- 1. The ice compartment lower inlet doors, intermediate deck doors, and top deck doors are closed;
- 2. The last recorded mean ice bed temperature was less than or
\ and i equal to 20*F and steadyNoe decreasi9
- 3. The ice condenser cooling system is OPERABLE with at least:
a) 21 OPERABLE air handling units, f b) 2 OPERABLE glycol circulating pumps, and c) 3 OPERABLE refrigerant units; Otherwise, be in at least HOT STANDBY within 6 hours and in COLD SHUTDOWN within the following 30 hours.
- b. With the ice bed temperature monitoring system inoperable and with the ice condenser cooling system not satisfying the minimum compo-nents OPERABILITY requirements of a.3 above, POWER OPERATION may continue for up to 6 days provided the ice compartment lower inlet i
doors, intermediate deck doors, and top deck doors are closed and the last recorded mean ice bed temperature was less than or equal to l 15'F and steady; otherwise, be in at least HOT STANDBY within the next 6 hours and in COLD SHUTDOWN within the following 30 hours. SURVEILLANCE REQUIREMENTS S 4.6.I.2 The ice bed temperature monitoring system shall be determined OPERABLE
- by performance of a CHANNEL CHECK at least once per 12 hours.
4 4 i I W-ICE CONDENSER 3/4 6-37B ggg 15 9979 l
CONTAINMENT SYSTEMS ICE CONDENSER 000RS LIMITING CONDITION FOR OPERATION 3.6.1.3 The ice condenser inlet doors, intermediate deck doors, and top deck doors shall be closed and OPERABLE. APPLICABILITY: MODES 1, 2, 3 and 4. ACTION: With one or more ice condenser doors open or otherwise inoperable, POWER OPERATION may continue for up to 14 days provided the ice bed temperature is ' monitored at least once per 4 hours and the maximum ice bed temperature is maintained less than or equal to 27'F; otherwise, restore the doors to their closed positions or OPERABLE status (as applicable) within 48 hours or be in at least HOT STANDBY within the next 6 hours and in COLD SHUT 00WN within the following 30 hours. SURVEILLANCE REQUIREMENTS
/
5 4.6.I.3.1 Inlet Doors - Ice condenser inlet doors shall be:
- a. Continuously monitored and determined closed by the inlet door position monitoring system, and
- b. Demonstrated OPERA 8LE during shutdown at least once per 3 months during the first year after the ice bed is fully loaded and at least once per'6 months thereafter by:
- 1. Verifying that the torque required to initially open each door is less than or equal to (675) inch pounds.
- 2. Verifying that opening of each door is not impaired by ice, frost or debris.
, 3. Testing a sample of at least 25% of the doors and verifying that the torque required to open each door is less than (195) inch pounds when the door is (40) degrees open. This torque is defined as the " door opening torque" and is equal to the nominal door torque plus a frictional torque component. The doors selected for determination of the " door opening torque" shall be selected to ensure that all doors are tested at least once during four test intervals. ! W-ICE CONDENSER 3/4 6-388 MAR 15 B78 1 l
, - - - .-- . . - - _ - - - - . . . . - - - . - ~-. , - - - . n.,----- -- - , __ - - - - - _ _ - - - . - -
CONTAINMENT SYSTEMS SURVEILLANCE REOUIREMENTS (Continued)
- 4. Testing a sample of at least 25% of the doors and verifying that the torque required to keep each door from closing is greater than 78 inch pounds when the door is 40 degrees open.
This torque is defined as the " door closing torque" and is equal to the nominal door torque minus a frictional torque component. The doors selected for determination of the " door closing torque" shall be selected to ensure that all docrs are tested at least once during four test intervals.
- 5. Calculation of the frictional torque of each door tested in accordance with 3 and 4, above. The calculated frictional torque shall be less than or equal to 40 inch pounds.
5 4.6.I.3.2 Intermediate Deck Doors - Each ice condenser intermediate deck door shall be:
- a. Verified closed and free of frost accumulation by a visual inspection at least once per 7 days, and
- b. Demonstrated OPERABLE at least once per 3 months during the first year after the ice bed is fully loaded and at least once per 18 months thereafter by visually verifying no structural deterioration, by verifying free movement of the vent assemblies, and by ascertain-ing free movement when lifted with the applicable force shown below:
i Door Lifting Force
- 1. S au d k Crans G hll S 3h'/ lbs.
I
- 2. keel un Joe Jtu.4-b cnsne u.ll S 33.6 lbs.
I U 3.Niusd4eeoda:nmealwU $ 3\.8 lbs. l ,
- 4. braluMalaer adW4,vf b ceaki e4 av $ 31.0 lbs.
s 4.6.1.3.3 Top Deck Doors - Each ice condenser top deck door shall be deter-mined closed and OPERABLE at least once per 92 days by visually verifying:
- a. That the doors are in placed, and
- b. That no condensation, frost, or ice has formed on the doors or l
blankets which would restrict their lifting and opening if required. I W-ICE CONDENSER 3/4 6-39B MAR 151978
CONTAINMENT SYSTEMS INLET DOOR POSITION MONITORING SYSTEM LIMITING CONDITION FOR OPERATION 3.6. 4 The inlet door position monitoring system shall be OPERABLE. APPLICABILITY: MODES 1, 2, 3, and 4. ACTION: With the inlet door position monitoring system inoperable, POWER OPERATION may continue for up to 14 days, provided the ice bed temperature monitoring system ) is OPERABLE and the maximum ice bed temperature is less than or equal to 27*F when monitored at least once per 4 hours; otherwise, restore the inlet door position monitoring system to OPERABLE status within 48 hours or be in at least HOT SHUTDOWN within the next 6 hours and in COLD SHUTDOWN within the following 30 hours. 1 SURVEILLANCE REQUIREMENTS 4.6.t.4 The inlet door position monitoring system shall be determined OPERABLE , by:
- a. Performing a CHANNEL CHECK at least once per 12 hours,
- b. Performing a TRIP ACTUATING DEVICE OPERATIONAL TEST at least once per 18 months, and
- c. Verifying that the monitoring system correctly indicates the status
( ' of each inlet door as the door is opened and reclosed during its testing per Specification 4.6.1.3.1.
.I f' -ICE CONDENSER 3/4 6-40B SEP 151981 l.________._ - - -
~ - - - - - - - ~ - - - ~~ - - ~ - -~ ~
1 i i CONTAINMENT SYSTEMS DIVIDER BARRIER PERSONNEL ACCESS DOORS AND EQUIPMENT HATCHES LIMITING CONDITION FOR OPERATION r 3.6.1.5 The personnel access doors and equipment batches between the contain-ment's upper and lower compartments shall be OPERABLE and closed. APPLICABILITY: MODES 1, 2, 3 and 4. AGION:
>2.00V With a personnel access door or equipment hatch inoperable or open except for personnel transit entry, restore the door or hatch to OPERABLE status or to its closed position (as applicable) within 1 hour or be in at least HOT i STANDBY within the next 6 hours and in COLD SHUTDOWN within the following 30 hours.
SURVEILLANCE REQUIREMENTS C 4.6.Y.5.1 The personnel access doors and equipment hatches between the con-tainment's upper and lower compartments shall be determined closed by a visual a. inspection: prior to increasing the Reactor Coolant System T,yg above 200F, and j b.after each personnel transit entry when the Reactor Coolant System T,yg is above 200*F. r
. 4.6.7.5.2 'The personnel access doors and equipment hatches between the con-tainment's upper and lower compartments shall be determined OPERABLE by visually inspecting the seals and sealing surfaces of these penetrations and verifying no detrimental misalignments, cracks or defects in the sealing surfaces, or apparent deterioration of the seal material:
- a. Prior to final closure of the penetration each time it has been i opened, and
- b. At least once per 10 years for penetrations containing seals fabri-
- cated from resilient materials.
i ! W-ICE CONDENSER 3/4 6-41B JUN 1 3 79 l
CONTAINMENT SYSTEMS 1LETutN ANb MM04EM SVmML SYST CONTAINMENT AIR Z :::: a i;an ;;rn LIMITING CONDITION FOR OPERATION
$ 1lehen and " Q ya % ~*"
3.6.1.6 Two independent containment airg.,._' '_ r systems shall be OPERA 8LE. APPLICABILITY: MODES 1, 2, 3 and 4. ACTION: With one containment aira/dut.* 65)k.*l**N#* system inoperable, restore the inoperable system to OPERABLE status within 72 hours or be in at least HOT STAND 8Y within the next 6 hours and in COLD SHUTDOWN within the following 30 hours. SURVEILLANCE RE0VIREMENTS S 4.6. I.61 Each containmentatakena,J air r;;fHy:_^ hab""8' la OPERABLE at least once per 92 days on a STAGGERED TEST BASIS by:
-'- system shall be demonstrated b,3,3 p $#
,9 anlkydenyn%**Q 1 Y cob'*
- a. Verifying that the(returnM Afans startifon,pk*N at : t; ;t;rt ignal after a Rf 1 minute celay and operates for at least 15 minutes. a er s kene$ sie rekes 4*n ofew4 ten y ul& he luypass W,s
- b. Verifying thatAwith the M fan dampery closedj the fan motor 6 46a .r ey.f current isp _ ^
7: when the fan speed is ns? 13 RPM. yy4 c. a;eesken u..he overded la k a> ed'enk k'h'1'f",jau, ute Verifying that with the3 f an off, theg:tur Of #:n- damperAcpens % ,,
&. ; - e ': c' ';;; it- :- - y ' +- ": :: ; W ' " +^ +k^ cer*p q:r:- *
- "* autenaaheattf u,tk a 10 ii see,4s c je(,y aWre a c,af,/ ef 7/><r..d tr.I./i'en At*4 O t**l
- g y;_,.
q
- d. Verifying that the motor operated valve in _sn the[sEction lineg ,t': e7eaf
___._,___m, _ , _______m__ m ______m__ .,:.._m _
~'
adornahaltyccJ +L L Jregen sLme 4ans cau:ve a siari ters uswr signal.
- 4. Ver&iag Q wif, &g, a4 & Q,,, qlx ;g l}g gu k dra as s kn,nt.~ fen oftra{l,sg / le fa'1 aqs alr Un< c(*% Ae.4.* en4ae curreal te less fissa er egaa 1sso + zo er.n.
- t. va.c;4ytog 4 1 < 41, h a:t esk 4ssy afuwk , 6a J,uJ.&a, ,,, jf, a;, re hu,, 4 s iacAy t
+, p s e..+atae,eks laaer ca,npaeh uf is eyes,
'k Yseifriq Ad w1h he fan off, +l,e 4 a,, ,du ,, 4,, ched 4,,, pee ,.,. ,4,,4 4 I..S. h.2. At \eas 4 ex a ce is n,rthsf r
, g,._,,.
S'1s% s e-~u}Li s.- % L.nsfraIv/cetMpc
- u. %p(g g,,,,,, ,,.,4,,
y a,;&,., y,,,,3wl, ag,;,,,,) g,;,. ,,pala,,, p ;,. a a,,s, s,, '" ,"' * / t""" l'lest ha,, o + w ,,,, c. e u ,,,,u,,cr p ,J gjgqmua/>G & g g ,.x j ,,'*[ " W-ICE CONDENSER 3/4 6-42B JUL 151978
CONTAINMENT SYSTEMS FLOOR DRAINS LIMITING CONDITION FOR OPERATION S 3.6.T.7 The ice condenser #1oor drains shall be OPERABLE. l APPLICABILITY: MODES 1, 2, 3 and 4. ACTION: With the ice condenser floor drain inoperable, restore the floor drain to OPERABLE status prior to increasing the Reactor Coolant System temperature above 200*F. i c SURVEILLANCE REQUIREMENTS C
- 4. 6.1. 7 Each ice condenser floor drain shall be oemonstrated OPERABLE at least once per 18 months during shutdown by:
- a. Verifying that valve gate opening is not impaired by ice, frost or depris,
- b. Verifying that the valve seat is not damaged,
- c. Verifying that the valve gate opens when a force of less than or equal to _fgfu lbs is applied, and
- d. Verifying that the drain line from the ice condenser floor to the containment lower compartment is unrestricted.
1 l I W-ICE CONDENSER 3/4 6-43B NAR 15 Eps
CONTAINMENT SYSTEMS REFUELING CANAL DRAINS LIMITING CONDITION FOR OPERATION 2
- 3.6.7.8 The refueling canal drains shall be OPERABLE.
APPLICA8ILITY: MODES 1, 2, 3, and 4. ACTION: With a refueling canal drain , inoperable, restore the drain to OPERABLE status within one hour or be in at least HOT STANDBY within the next 6 hours and in at least COLD SHUTDOWN within the following 30 hours. SURVEILLANCE REOUIREMENTS 4.6. 8 Each refueling canal drain shall be demonstrated OPERABLE. ~
- a. Prior to increasing the Reactor Coolant System temperature above 200*F after each partial or complete filling of the canal with water by verifying that the ; _; ': ----- " '-- - '--#-
Va\VU %kdrah I'.Ms d" awe and that the drain is not obstructed by debris, and lockalc(ca b. At least once per 92 days by verifying, through a visual inspec-tion, that tt: r' ; * - _ _.s. .. J there is no debris that could obstruct the drain. t
)f-ICE CONDENSER 3/4 6-448 Aug 7 1980
l l . CONTAINMENT SYSTEMS DIVIDER BARRIER SEAL LIMITING CONDITION FOR OPERATION i
- 3. 6.1. 9 The divider barrier seal shall be OPERABLE.
APPLICABILITY: MODES 1, 2, 3 and 4.
- ACTION
With the divider barrier seal inoperable, restore the seal to OPERABLE status prior to increasing the Reactor Coolant System temperature above 200*F. SURVEILLANCE REQUIREMENTS 4.6. 9 The divider barrier seal shall be determined OPERABLE at least once per 18 months during shutdown by:
- a. Removing two divider barrier seal test coupons and verifying that the physical properties.of the test coupons are within the acceptable range of values shown in Table 3.6-3.
- b. Visually inspecting at least (95) percent of the seal's entire length and:
- 1. Verifying that the seal and seal mounting bolts are properly installed, and
- 2. Verifying that the seal material shows no visual evidence of deterioration due to holes, ruptures, chemical attack, abrasion, radiation damage, or changes in physical appearances.
1 l 1 W-ICE CONDENSER 3/4 6-45B NAR Ig 797g
- - -- - o
1 l i J TABLE 3.6-3 19: l Fi m DIVIDER BARRIER SEAL g ACCEPTABLE PHYSICAL PROPERTIES
, 2 i R ft,Jr. T ee w $<d5 m
Tensile N h.d
- Strength T4empWen
, t.1 i nnnst fiant __ finnis
- s. ., ,_. , --,-
l ok io 39,7 4,,
/tk ti 3%7 lbs.
l I i w .
)
T
=
5 CN U$ M
CONTAIN NT SYSTEMS 3/4.6.8 ADEUMRELIEFVALVES(OPTIONAL) LIMITING CONDITION R OPERATION s , 3.6.8 The primary contain nt to atmosph e vacuum relief valves shall be OPERABLE with an actuation s ' point of ess than or equal to psid. t APPLICABILITY: MODES 1, 2, 3 an' 4. ACTION: With one primary containment atmosp re vacuum relief valve inoperable, restorethevalvetoOPERABLf'statuswi in 4 hours or be in at least HOT STANDBY within the next 6 urs and in C0 SHUTDOWN wit;hin the following 30 hours. SURVEILLANCE REQUIREMENTS 1 4.6.8 No a itional Surveillance Requirements other tha those required by i Specifica on 4.0.5. 1 4 l l l l W-ICE CONDENSER 3/4 6-478 JUN 1 1979 1 l )
SECTION 3/ .6C CONTAINME SYST SPECIFICATIONS OR ESTINC SE SUBAT SPHERIC TYPE TAINMENT 1 1 l
~
i l l 3/ A CONTAINME SYSTEMS 3/4.6.1 RIMA CONTAINMENT CONTAINMEh NTEGRITY LIMITING NDITIO OR OPERATION f
- 3. 6.1.1 Primary CONTAINMENT INTEGRITY shall be maintained.
APPLICABILITY: MODES 1, 2, 3, and 4. ACTION: Without primary CONTAINMENT INTEGRITY, restore CONTAINMENT INTEGRITY within 1 hour or be in at least HOT STANDBY within the next 6 hours and in COLD SHUTDOWN within the following 30 hours. i SURVEILLANCE REQUIREMENTS t 4.6.1.1 Primary CONTAINMENT INTEGRITY shall be demonstrated: I
- a. At least once per 31 days by verifying that all penetrations
- not capable of being closed by OPERABLE containment automatic isolation valves and required to be closed during accident conditions are closed by valves, blind flanges, or deactivated automatic valves secured in their positions, except as provided in Table 3.6-1 of l
Specification 3.6.4.1.
- b. By verifying that each containment air lock is OPERABLE per Specification 3.6.1.3.
- c. After each closing of each penetration subject to Type B testing, except the containment air locks, if opened following a Type A or B test, by leak rate testing the seal with gas at P (50 psig) and verifying that when the measured leakage rate for,these seals is added to the leakage rates determined pursuant to Specifica-tion 4.6.1.2.d for all other Type B and C penetrations, the combined leakage rate is less than 0.60 L,.
Except valves, blind flanges, and deactivated automatic valves which are located inside the containment and are locked, sealed, or otherwise secured in the closed position. These penetrations shall be verified closed during each COLD SHUTDOWN except that such verification need not be perforned more often than once per 92 days. _W-SUBATMOSPHERIC 3/4 6-1C gg . 3 gg
CONTA ENT SYST CONTAINM LEA GE l LIMITINGCONWk N FOR OPERATION 3.6.1.2 ntaineen leakage rates shall be limited to:
- a. An overall in grated leakage rate of:
- 1. Less than or equal to L containment air per 24 8o,ur(0.20) percent s at P, (50 byor psig), weight of the
- 2. Less than or equal to L , (0.10) percent by weight of the containment air per 24 nours at a reduced pressure of Pt (25 psig).
- b. A combined leakage rate of less than or equal to 0.60 L for all penetrations and valves subject to Type B and C tests, ,ahen pressurized to Pa*
APPLICABILITY: MODES 1, 2, 3 and 4. ACTION: With either (a) the measured overall integrated containment leakage rate or 0.75 L , as applicable, or (b) with the measured combined exceeding leakage rate 0.75L,allper.etr$tionsandvalvessubjecttoTypesBandCtests for exceeding 0.60 aL , restore the overall integrated leakage rate to less than or equal to 0.75 L or less than or equal to 0.75 L , as applicable, and the combined leakag8 rate for all penetrations subjekt to Type B and C tests to less than or equal to 0.60 Lapri r to increasing the Reactor Coolant System temperature above 200*F. , SURVEILLANCE REQUIREMENTS l 4.6.1.2 The containment leakage rates shall be demonstrated at the following test schedule and shall be determined in conformance with the criteria specified in Appendix J of 10 CFR 50 using the methods and provisions of ANSI N45.4-(1972):
- a. Three Type A tests (Overall Integrated Containment Leakage Rate) shall be conducted at 40 + 10 month intervals during shutdown at either P period. aThe(50 third psig)test or at ofP. (25 set each psig) during shall each 10 year be conducted service during the shutdown for the 10 year plant inservice inspection.
- b. If any periodic Type A test fails to meet either .75 L r .75 L a
thetestscheduleforsubsequentTypeAtestsshallbereviewedkn,d approved by the Commission. If two consecutive Type A tests fail to meet either .75 L or .75 L ,t a Type A test shall be performed at least every 18 mo$ths until two consecutive Type A tests meet either l .75 L, or .75 L att which time the above test schedule may be resumed. W-SUBATMOSPHERIC 3/4 6-2C NOV 15 577
I CONTAINME SYSTEM SURVEILLANC EQd REMENTS (Continued)
- c. The'a uracy of each Type A test shall be verified by a supplemental
- dst wh h:
- 1. Confi the accuracy of the Type A test by verifying that the differe between supplemental and Type A test data is within 0.25 L,, o 0.25 L '
t
- 2. Has a duration sufficient to establish accurately the change in leakage rate between the Type A test and the supplemental test.
- 3. Requires the quantity of gas injected into the containment or bled from the containment during the supplemental test to be equivalent to at least 25 percent of the total measured leakage at P, (50 psig) or Pt (25 psig).
- d. Type B and C tests shall be conducted with gas at P (50 psig) at intervalsnogreaterthan24monthsexceptfortest$ involving:
- 1. Air locks,
- 2. Penetrations using continuous leakage monitoring systems, and
- 3. Valves pressu *ized with fluid from a seal system.
- d. Type B and C test shall be conducted with gas at P intervalsnogreaterthan24monthsexceptfortes&s(50psig)at involving:
- 1. Air locks,
- 2. Penetrations using continuous leakage monitoring systems, and
- 3. Valves pressurized with fluid from a seal system.
- e. Air locks shall be tested and demonstrated OPERABLE per Surveillance Requirement 4.6.1.3.
- f. Type B periodic tests are not required for penetrations continuously monitored by the Containment Isolation Valve and Channel Weld Pressurization Systems, provided the systems are OPERABLE per Surveillance Requirement 4.6.1.4.
- g. Leakage from isolation valves that are sealed with fluid from a seal system may be excluded, subject to the provisions of Appendix J, Section III.C.3, when determining the combined leakage rate provided the seal system and valves are pressurized to at least 1.10 P (55 psig)andthesealsystemcapacityisadequatetomaintainsy$ tem pressure for at least 30 days.
W-SUBATMOSPHERIC 3/4 6-3C
CONTAINMENT STEMS SURVEILLANCE R IREME S (continued)
- h. Type B t s for penetrations employing a continuous leakage monitor ~ g stem shall be conducted at P, (50 psig) at intervals no greate than nce per 3 years.
- i. The ovisions Specification 4.0.2 are not applicable.
l l l l l l I l W-SUBATMOSPHERIC 3/4 6-4C AUG o ICSI
CON INMENT S TEMS CONTAI ENT IR LOCKS
/
LIMITINw C0 ITION FOR OPERATION 3.6 1.3 Each co + inment air lock shall be OPERABLE with:
~/
- a. Both doors closed except when the air lock is being used for normal transit entry and exit through the containment, then at least one air lock door shall be closed, and
- b. An overall air lock leakage rate of less than or equal to 0.05 L, at P,, (50 psig).
APPLICABILITY: MODES 1, 2, 3 and 4. ACTION:
- a. With one containment air lock door inoperable:
- 1. Maintain at least the OPERABLE air lock door closed and either restore the inoperable air lock door to OPERABLE status within 24 hours or lock the OPERABLE air lock door closed.
- 2. Operation may then continue until performance of the next required overall air lock leakage test provided tnat the OPERABLE air lock door is verified to be locked closed at least once per 31 days.
- 3. Otherwise, be in at least HOT STANDBY within the next 6 hours and irtCOLD SHUTDOWN within the following 30 hours.
- 4. The provisions of Specification 3.0.4 are not applicable.
- b. With the containment air lock inoperable, except as the result of an inoperable air lock door, maintain at least one air lock door closed; restore the inoperable air lock to OPERAELE status witnin 24 hours or be in at least HOT STANDEY within the next 6 nours anc in COLD SHUTDOWN within the following 30 hours.
w _-5USATMC5PHE:.:: 2 2 5-EC EF ~ ? "S~
CONTAIN NT SYSTEMS SURVEILLA REQU EMENTS 4.6.1.3 Ea co tainment air lock shall be demonstrated OPERABLE:
- a. ithin 72 ours following each closing, except when the air lock is l being used r multiple entries, then at least once per 72 hours, by verifying no tectable seal leakage by pressure decay when the volume between he door seals is pressurized to greater than or equal to P, (50 psig) for at least 15 minutes, l
- b. By conducting overall air lock leakage tests at not less than P ,
(50 psig), and verifying the overall air lock leakage rate is within its limit:
- 1. At least once per 6 months,# and
- 2. Prior to establishing CONTAINMENT INTEGRITY when maintenance has been performed on the air lock that could affect the air lock sealing capability.*
- c. At least once per 6 months by verifying that only one door in each air lock can be opened at a time.
o 1 - l
\
l s x The provisions of Specification 4.0.2 are not applicable. ,
- Exemption to Appendix J of 10 CFR 50. '
\
~
-W-SU8 ATMOSPHERIC 3/4 6-6C SEP 2 81981 l .
CONTbNMENTSYSTEMS CONTAI ENT ISOLAT ON VALVE AND CHANNEL WELD PRESSURIZATION SYSTEMS (OPTIONAL) LIMITING
/
NDITION FOR OPERATION he c 3.6.1.4 system 's , hall b tainment isolation valve and channel weld pressurization OPERABLE. APPL ABILITY: M0 JS 1, 2, 3 and 4. ACTION: With the containment isolation valve or channel weld pressurization system inoperable, restore the inoperable system to OPERABLE status within 7 days or be in at least HOT STANDBY within the next 6 hours and in COLD SHUTDOWN within the following 30 hours. l SURVEILLANCE REQUIREMENTS 4.6.1.4.1 The containment isoiation valve pressurization system shall be demonstrated OPERABLE at least once per 31 days by verifying that the system is pressurized to greater than or equal to 1.10 P (55 psig) and has adequate capacity to maintain system pressure for at least,30 days. 4.6.1.4.2 The containment channel weld pressurization system shall be demonstrated OPERABLE at least once per 31 days by verifying that the system' is pressurized to greater than or equal to P capacitytomaintainsystempressureforatTea(50psig)andhasadequate st 30 days. 1 W-SUBATMOSPHERIC 3/4 6-7C MAR 15 E78
CONTAINME.T SYSTEM INTERNAL P SSUR LIMITING CON ION FOR OPERATION 3.6.1.5 Primary ntainment internal pressure shall be maintained greater than or equ to p a and within the acceptable operation range (below and to the 1 t of the RWS water temperature limit lines) shown on Figure 3.6-1 as a fu ction of RWST water temperature and service water temperature. APPLICA8ILITY: MODES 1, 2, 3 and 4. ACTION: With the containment internal pressure less than psia or above the applicable RWST water temperature limit line shown on Figure 3.6-1, restore the internal pressure to within the limits within 1 hour or be in at least HOT STANDBY within the next 6 hours and in COLD SHUTDOWN within the following 30 hours. SURVEILLANCE REOUIREMENTS 4.6.1.5 The primary containment internal pressure shall be determined to be within the limits at least once per 12 hours. l W-SUBATMOSPHERIC _ 3/4 6-8C SEP 15 573
tC
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l
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hl! E 10.8 l' . .:! !!! %'!ri !i;! THESE OPERATING CURVES REQUIRE THAT Tile
- hM -
.t;l !:.,j AVERAGE CONTAINMENT TEMPERATURE DOES m . ;'; .;: :::: l' ;
y , .t. . . - s c m % L2 '2 M. . ;' " i% NOT LIE BELOW Tile MINIMUM TEMPERA 1URE t' M E D i!!! .!.. lfli !! ! Ith SHOWN IN FIGURE 3.6 2 / l 'l' 8 10.6
'ii! n!! pp! I!! T litil: Dil:ntliliil;u;lis:ll;inl:::ililllliilliltll;i;;l';j o =
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- a jn: :. : i Tis j; ilIl ;N "~ ii jiii n ! ji !lI l i' F
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li Q i 8 u; ? RWST .ji! 'jii j5 k f%dli is in; il ih : .i !!. i i!! i M TEMPERATURE N g E T-THIS FIGURE FOR ILLUSTRATION ONLY , a 88
- iii fi!! i 45 p t'itM ?!il :ii Mk l DO NOT USE FOR OPERATION 9
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- n b M 40 45 W 55 60 65 70 75 80 85 M l M RIVER WATER TEMPER ATURE (F) en Gi FIGURE 3.6-1 MAXIMUM ALLOWABLE PRIMARY CONTAINMENT AIR PRESSURE VERSUS w
oo RIVER WATER TEMPERATURE AND RWST WATER TEMPERATURE
CONTAIN T SYSTEMS AIR TEMPERATURE LIMITING COND N FOR OPERATION
, s
- 3. 6.1. 6 rimary con inment average air temperature shall be maintained less than o equal to and above the temperature limit line shown on Figure 3.6- as a function of rvice water temperature.
PLICABILITY: MODES 1, 2, 3 and 4. ACTION: With the containment average air temperature greater than *F or below the limit line shown on Figure 3.6-2, restore the average air temperature to within the limit shown within 8 hours or be in at least HOT STANOBY within the next 6 hours and in COLD SHUTDOWN within the following 30 hours. SURVEILLANCE REQUIREMENTS 4.6.1.6 The primary containment average air temperature shall be the arithmetical average of the temperatures at the following locations and shall be determined at least once per 24 hours: Location a. b. c.
- d.
- e.
i W-SudATMOSPHERIC 3/4 6-10C SEP 151979
IT E - 105 i . u u . . . u ua u u u u . u s . u . u . a . o u s g, h i-i
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.b ['
i
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-} CONJUNCTION WIT 11 FIG. 3.6-1 F,'
b/ h $ 100 ! f I' b l [ ';I-bf fiI
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l jj DO NOT USE FOR RATION
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i j!!! l; i, ;y . [ t-l 7 l vt r:h't ;t+ t+ri - t 1 - so i;I ll!! iij l: ! ! l "!i +1c Y.. .. l I i ! . l 35 40 45 50 55 60 65 70 75 80 85 90 RIVER WATER TEMPERATURE (*F) m FIGURE 3.6-2 MINIMUM ALLOWABLE PRIMARY CONTAINMENT AVERAGE AIR TEMPERATURE en VERSUS RIVER WATER TEMPERATURE to O
CONTAIN T SYSTEMS CONTAINMEN TRUCTURAL EGRITY (Prestressed concrete containment with ungrouted ten, ns anc pical come.) 1 LIMITING CONDITIO OR OPERATION
, s 3.6.1.7 The ructura integrity of the containment shall be maintained at a 1 level consi ent with th acceptance criteria in Specification 4.6.1.7.
l l APPLICA LITY: MODES 1, 2, and 4. ACT . h the structural integrity of the containment not conforming to the above requirements, restore the structural integrity to within the limits within 24 hours or be in at least HOT STANOBY within the next 6 hours and in COLD SHUT 00dN within the following 30 hours. SURVEILLANCE REQUIRENENTS 4.6.1.7.1 Containment Tendons The containment tendons' structural integrity shall be demonstratea at tne end of one, three and five years following the initial containment strucutraf integrity test and at five year intervals thereafter. The tendons' structural integrity shall be demonstrated by:
- a. Determining that a representative sample
- of at least 21 tendons (6 dome, 5 vertical, and 10 hoop) each have a lift off force of between (minimum) and (maximum) pounds at the first year inspection. For subsequent inspections, the maximum allowable lift off force shall be decreased from the value determined at the first year inspection by the amount: '.og t and the minimum allowable lift off force shall be decreased from the value determined at the first year inspection by the amount: log t where t is the time interval in years from initial tensioning of the tendon to the current testing date. This test shall include an unloading cycle in which each of these tendons is detensioned to determine if any wires or strands are broken or damaged. Tendons found acceptable during this test shall be retensioned to their observed lift off force,
+3%. During retensioning of these tendons, the change in load and elongation shall be measured simultaneously. If the lift off force of any one tendon in the total sample population is out of the "For eacn inspection, the tendons shall be selected on a random but representative basis so that the sample group will change somewhat for each inspection; however, to develop a history of tendon perform-ance and to correlate the observed data, one tendon from each group (dome, vertical, and hoop) may be kept unchanged after the initial selection.
'f-SUBATMOSPHERIC 3/4 6-12C MAR 151378
F CONTAIN T SYSTEMS SURVEILLAN REQUIREMENTS _ Continued) . predbedbounds(lessthanminimumorgreaterthanmaximum),an adjaceni Aendon on each side of the defective tendon shall also be checkedhrliftoffforce. If both of these adjacent tendons are found4ccept.able, the surveillance program may proceed considering ficiency as unique and acceptable. This single tendon the/ ingle stgG1 be resd(toted to the required level of integrity.More than one oefectivetendo40utoftheoriginalsamplepopulationisevidence of abnormal degr ation of the containment structure. Unless there is evidence of abn al degradation of the containment tendons during the first th e tests of the tendons, the number of tendons checked for lift off rce and change in elongation during subsequent tests may be reduced to a representative sample of at least 9 tendons (3 dome, 3 vertical and 3 hoop).
- b. Removing one wire or strand from each of a dome, vertical and hoop tendon checked for lift off force and determining that over the entire length of the removed wire or strand that:
- 1. The tendon wires or strands are free of corrosion, cracks and damage.
i
- 2. There are no changes in the presence or physical appearance of the sheathing filler grease.
- 3. A minimum tensile strength value of psi (guaranteed ultimate stNngth of the tendon material) for at least three wire or strand samples (one from each end and one at mid-length) cut from each removed wire or strand. Failure of any one of the wire or strand samples to the meet the minimum tensile strength test is evidence of abnormal degradation of the containment structure. ,
4.6.1.7.2 End Anchorages and Adjacent Concrete Surfaces The structural integrity of the end cnchorages of all tendons inspected pursuant to Specification 4.6.1.7.1 and the adjacent concrete surfaces shall be demonstrated by determining through inspection that no apparent changes have occurred in the visual appearance of the end anchcrage or the concrete crack patterns adjacent ot the end anchorages. Inspections of the concrete shall be performed during the Type A containment leakage rate tests (reference Specification 4.6.1.2) while the containment is at its maximum test pressure. 1 W-SUBATMOSPHERIC 3/4 6-13C A!AR 15 373
. - - _ _ _ . ~ - _ . _ _ _ _ - _ _ _ _ . _ _ _ _ _ _ _ _ . _ . _ _ . . _ _ __ _- _ - _ _ - - -
CONTAIkTSYSTEMS SURVEILLAN REQUIREMENTS (Cont' ued) 4.6.1.7.3 Co ainment Surfa s The structural integrity of the exposed accessible inte ior and ex rior surfaces of the containment, including the liner plate, sha be det ined during the shutdown for each Type A containment leakage rate test fer ce Specification 4.6.1.2) by a visual inspection of these surfaces. Thi ~ spection shall be performed prior to each Type A containment leakage r e test to verify no apparent changes in appearance or other abnormal degr at n. 4.6.1.7.4 Repor Any ab rmal degradation'of the containment structure detected during he above re ired tests and inspections shall be reported to ' the Commission ursuant to Spe ~ ication 6.9.1. This report shall include a description o the tendon conditi the condition of the concrete (especially at tendon an orages), the inspecti procedure, the tolerances on cracking, and the cor ective actions taken. ( W-SUBATMOSPHERIC 3/4 6-14C DEC 151973
CONTAIN NT SYSTEMS CONTAINME STRUCTURAL INTEGR7 Y (Prestressed concrete containment with ungrouted t cons and hemispa'erical dome. ) LIMITING CONDITI FOR ERATION 3.6.1.7 The stru,..ura integrity of the containment shall be maintained at a level consistenVwith th acceptance criteria in Specification 4.6.1.7. ADPLICABILIT MODES 1, 2, , and 4. ACTION: With th structural integrity of t containment not conforming to the above requi ments, restore the structural *ntegrity to within the limits within 24 hour or be in at least HOT STANDBY within the next 6 hours and in COLD SHUTDOWN wit in the following 30 hours. SURVEILLANCE REQUIREMENTS 4.6.1.7.1 Containment Tendons The containment tendens' structural integrity shall be demonstrated at the end of one, three and five years following the initial containment structural integrity test and at five years intervals thereafter. The tendons' structural integrity shall be demonstrated by:
- a. Determining that a representative sample
- of at least 4% but no less than 4, of the U tendons each have a lift off force of between (minimum) and (maximum) pounds at the first year inspection and that a representative sample
- of at least 4%, but no less than 9, of the hoop tendons each have a lift off force of between (minimum) and (maximum) pounds at the first year inspection.
For subsequent inspections, the maximum allowable lift off forces shall be decreased from the value determined at the first year inspection by the amount: log t and the minimum allowable lift off force shall be decreased from the value determined at the first year inspection by the amount: log t where t is the time interval in years from initial tensioning of the tendon to the current testing date. This test shall include an unloading cycle in which each of these tendons is detensioned to determine if any wires or strands are broken or damaged. Tendons found acceptable during this test shall be retensioned to their observed lift off force 13%. During "For eacn inspection, the tendons shall be selected on a random but representative basis so that the sample group will change somewhat for each inspection; however, to develop a history of tendon performance and to correlate the observed data, one tendon from each group (U and hoop) may oe kept unchanged after the initial selection. W-SUBATMOSPHERIC 3/4 6-15C JUL 151979
I l CONTAINMENT SYSTEMS SURVEILLA REQUIREMENTS (Conti ed) retens ning of t e tendons, the change in load and elongation shall be asure simultaneously. If the lift off force of any one tendon in tal sample population is out of the predicted bounds (less than a or greater than maximus), an adjacent tendon on each side o the efective tendon shall also be checked for lift off force. I both of_ ese adjacent tendons are found acceptable, the surveill nce program y proceed considering the single deficiency as uni e and acceptab This single tendon.shall be restored to the quired level of in rity. More than one defective tendon out of e original _ sample pop ation is evidence of abnormal degradation o the containment structure. Unless there is evidence of abnormal gradation of the containment tendons 'during the first three tests of the tendons, the number of t dons checked for lift off force and I change in elongation during subsequent tests may be reduced to a representative sample of at least 2%, but no less than 2, of the U tendons and a representative sample of at least 2%, but no less than 3, of the hoop tendons.
- b. Removing one wire or strand from one U tendon and one hoop tendon checked for lift off force and determining that over the entire length of the removed wire or strand that: -
- 1. The tendon wires or strands are free.of corrosion, cracks and
, damage.
i
- 2. There are no changes in physical appearance of the sheathing filler grease.
- 3. A minimum tensile strength value of _ psi (quaranteed utinate strength of the tendon material) for at least three wire or strand samples (one from each end and one at mid-length) cut from each removed wire or strand. Failure of any one of the wire of strand samples to meet the minimum tensile strength test is evidence of abnormal degradation of the containment structure.
4.6.1.7.2 End Anchorages and Adjacent Concrete Surfaces The structural integrity of the end anchorages of all tendons inspected pursuant to Speci-fication 4.6.1.7.1 and the adjacent concrete surfaces shall be demonstrated by determining through inspection that no apparent changes have occurred in the visual appearance of the end anchorage or the concrete crack patterns adjacent at the end anchorages. Inspections of the concrete shall be performed during the Type A containment leakage rate tests (reference Specification 4.6.1.2) while the containment is at its maximum test pressure. W-SU8 ATMOSPHERIC 3/4 6-16C JUL 15 !s79
CONTAINMENT SYSTEMS SURVEILLANCE REOUIREMENTS (Continued),/ 4.6.1.7.3\ontainmentSurfaces The structural integrity of the exposed accessible 114erior and exterior sy faces of the containment, including the liner plate, sbil be determined c)6 ring the shutdown for each Type A containment leakage rate tes (referenceSpe/ification4.6.1.2)byavisualinspectionof these surfaces. i 'sinspectpi shall be performed prior to each Type A containment leakage te tes to verify no apparent changes in appearance or other abnormal degradat' n 4.6.1.7.4 Reoorts A abn al degradation of the containment structure detected during the/ Dove rehired tests and inspections shall be reported to the Commission puptuant to Spe 'fication 6.9.1. This report shall include a description of 2fie tendon condit'on, the condition of the concrete (especially at tendon anc)t6 rages), the inspec 'on procedure, the tolerances on cracking, and the cor ctive actions taken. W-SUBATMOSPHERIC 3/4 6-17C DEC 151978
CONTAINMEN YSTEMS CONTAINMENT S CTURAL IN GRITY (Reinforced concrete containment) LIMITING CONDITION R OPERATION 3.6.1.7 The st ctural 'ntegrity of the containment shall be maintained at a level consiste with the cceptance criteria in Specification 4.6.1.7. APPLICABILI : MODES 1, 2, nd 4. ACTION: With t e structural integrity of the c tainment not conforming to'the above requi ements, restore the structural integrity to within the limits within 24 hour or be in at least HOT STANDBY within the next 6 hours and in COLD SHUTOOWN within the following 30 hours. SURVEILLANCE REQUIREMENTS 4.6.1.7.1 Containment Surfaces The structural integrity of the exposed accessible interior and exterior surfaces of the containment, including the liner plate, shall be determined during the shutdown for each Type A contain-ment leakage rate test (reference Specification 4.6.1.2) by a visual inspection of these surfaces. This inspection shall be performed prior to the Type A containment leakage rate test to verify no apparent changes in appearance or other abnormal degradation. 4.6.1.7.2 Reports Any abnormal degradation of the containment structure detected during the above required inspections shall be reported to the Commission pursuant to Specification 6.9.1. This report shall include a description of the condition of the concrete, the inspection procedure, the tolerances on cracking, and the corrective actions taken. I ( W-SUBATMOSPHERIC 3/4 6-18C DEC 15 378 l ___ - - -- - - ~
ONTA NT SYSTEMS-CONTAIN VENTILATION STEM
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LIMITING CONDITI F R OPERATION l / 3.6.1.8 The (42, nch) c tainment purge supply and exhaust isolation valves shall be sealed / closed. O eration with the (8 inch) purge supply and/or exhaust isolat4cn valves op shall be limited to less than or equal to ef 365 days. (90) hours p/ APPLICABILITY: MODES 1, 2, 3, a 4. ACTION: With e (42 inch) containment purge supply and/or exhaust isolation valve (s) ope, , or with the (8 inch) purge supply and/or exhaust isolation valve (s) open for more than (90) hours per 365 days, close the open valve (s) within 1 hour or be in at least HOT STANDBY within the next 6 hours and in COLD SHUTDOWN within the following 30 hours. I
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SURVEILLANCE RE0UUIREMENTS 4 4.6.1.8.1 The containment purge supply and exhaust isolation valves shall be 1 g verified to be:
- a. Closed at least once per 24 hours,
- b. Sealed - closed at least once per 31 days.
4.6.1.8.2 The cumulative time that the (8 inch) purge supply and exhaust isolation valves have been open during the past 365 days shall be determined at least once per 7 days. 4.6.1.8.3 At least once per 6 months on a STAGGERED TEST BASIS each sealed closed (42 inch) containment purge supply and exhaust isolation valve shall be demonstrated OPERABLE by verifying that the measured leakage rate is less than or equal to (0.05) L,. 4.6.1.8.4 At least once per 3 months each (8 inch) containment purge supply and exhaust isolation valve shall be demonstrated OPERABLE by verifying that the measured leakage rate is less than or equal to (0.05) L,. W-SUBATMOSPHERIC 3/4 6-19C np 2 81981
CONT MNMENT SYSTEMS 3/4.6.2 EPRESSURIZATION AN COOLING SYSTEMS CONTAINMENT ENCH SPRAY S TEM LIMITING CONDITIO OPERATION m 3.6.2.1 Two in pendent antainment quench spray subsystems shall be OPERABLE. APPLICABILI . MODES 1, 2, and 4. ACTION: With on containment quench spra subsystem inoperable, restore the inoperable subsys m to OPERABLE status with1 72 hours or be in at least HOT STANDBY withi the next 6 hours and in COLD HUTDOWN within the following 30 hours. SURVEILLANCE REQUIREMENTS 4.6.2.1 Each containment quench spray subsystem shall be demonstrated OPERABLE:
- a. At least once per 31 days by:
, 1. Verifying that each valve (manual, power operated or automatic) l in the flow path that is not locked, sealed or otherwise secured in position, is in its correct position.
- 2. Verifying the temperature of the barated water in the refueling water storage tank is within the limits shown on Figure 3.6-1.
- b. By verifying, that on recirculation flow, each pump develops a i discharge pressure of greater than or equal to psig when tested pursuant to Specification 4.0.5.
- c. At least once per 18 months during shutdown, by:
- 1. Verifying that each automatic valve in the flow path actuates to its correct position on a test signal.
- 2. Verifying that each spray pump starts automatically on a test signal.
l d. At least once per 5 years by performing an air or smoke flow test through each spray header and verifying each spray nozzle is unobstructed. W-SU8 ATMOSPHERIC 3/4 6-20C MAR 151978
l l CO INMENT SYSTEMS CONTA ENT RECIRCULATION SP SYSTEM LIMITING C0 TION FOR EPERATION
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3.6.2.2 Two indepanoent containment recirculation spray subsystems shall be OPERABLE. ,/
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APPLICABILITY: MODES 1, 2, 3 and 4. ACTION: With pne containment recircul 'on spray subsystem inoperable, restore the inop6rable subsystem to OPERABLE status within 72 hours or be in at least HOT STA/IDBY within the next 6 hours; restore the inoperable spray system to OPfRABLE status within the next 48 hours or be in COLD SHUTDOWN within the following 30 hours. SURVEILLANCE RE0VIREMENTS 4.6.2.2 Each containment recirculation spray subsystem shall be demonstrated OPERABLE:
- a. At least once per 31 days by verifying that each valve (manual,
, power operated or automatic) in the flow path is not locked, sealed cr otherwise secured in position, is in its correct position. , b. By verifying, that on recirculation flow, each pump develops a l discharge pressure of greater than or equal to psig when l tested pursuant to Specification 4.0.5.
~
- c. At least once per 18 months by verifying that on a Containment Pressure --High-High test signal, each recirculation spray pump starts automatically after a (350 + 50) second delay.
- d. At least once per 18 months during shutdown, by verifying that each automatic valve in the flow path actuates to its correct position on a test signal.
- e. At least once per 5 years by performing an air or smoke flow test through each spray header and verifying each spray nozzle is unobstructed.
I i l W-SUBATMOSPHERIC 3/4 6-21C MAR 1510 I
CONTAINM T SYSTEMS SPRAY ADDI SYST (OPTIONAL) LIMITING CONDI FOR OPERATION 3.6.2.3 e spray addi 've system shall be OPERABLE with: a A spray additive nk containing a volume of between and gallons of tween and percent by weight NaOH solution, and
- b. Two spray additive eductors each capable of adding NaOH solution from the chemical additive tank to a containment spray system pump i flow.
APPLICABILITY: MODES 1, 2, 3 and 4. ACTION: With the spray additive system inoperable, restore the system to OPERABLE status within 72 hours or be in at least HOT STAMOBY within the next 6 hours; restore the spray additive system to CPERABLE status within the next 48 hours or be in COLD SHUTDOWN within the following 30 hours. 1 SURVEILLANCE REOUIREMENTS t 4.6.2.3 The spray additive system shall be demonstrated OPERABLE: -
- a. At least once per 31 days by verifying that each valve (manual, '
power operated or automatic) in the flow path that is not locked, sealed or otherwise secured in position, is in its correct position.
- b. At least once per 6 months by:
1 Verifying the contained solution volume in the tank, and
- 2. Verifying the concentration of the NaOH solution by chemical analysis,
- c. At least once per 18 months, during shutdown, by verifying that each automatic valve in the flow path actuates to its correct position on a test signal.
- d. At least once per 5 years by verifying each solution flow rate (to be determined during pre operational tests) from the following drain connections in the spray additive system:
- 1. (Drain line location) 2 gpm l 2. (Drain line location) 2 gpm W-SUBATHOSPHERIC 3/4 6-22C MAR 151978 l
i
l CONTAINME SYSTEMS 3/4.6.3 CO AINMENT ISD ATION VALVES
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LIMITING CONDITI 'FOR OPERATION
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3.6.3 The containment isolation valves specified in Table 3.6-1 shall be OPERABLE with isolation imes as shown in Table 3.6-1.
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APPLICABILITY: MODES 1, 2, and 4. ACTI : W' h one or more of the isolation valve (s) specified in Table 3.6-1 noperable, maintain at least one isolation valve OPERABLE in each affected penetration that is open and either:
- a. Restore the inoperable valve (s) to OPERABLE status within 4 hours, or
- b. Isolate each affected penetration within 4 hours by use of at least one deactivated automatic valve secured in the isolation position, or
- c. Isolate each affected penetration within 4 hours by use of at least l one closed manual valve or blind flange; or 1
- d. Be in at least HOT STANDBY within the next 6 hours and in COLD SHUTDOWN within the following 30 hours.
SURVEILLANCE REQUIREMENTS 4.6.3.1 The isolation valves specified in Table 3.6-1 shall be demonstrated OPERABLE:
- a. At least once per 92 days by cycling each weight or spring loaded check valve testable during plant operation, through one complete cycle of full travel and verifying that each check valve remains closed when the differential pressure in the direction of flow is less than or equal to (1.2) psid and opens when the differential pressure in the direction of flow is greater than or equal to (1.2) psid but less than (5.0) psid.
1 l b. Prior to returning the valve to service after maintenance, repair or replacement work is performed on the valve or its associated actuator, control or power circuit by performance of a cycling test and verification of isolation time. W-SUBATMOSPHERIC 3/4 6-23C MAR 151978
CON NMENT SYSTEMS SURVEIL E REQUIREM TS (Continued) 4.6.3.2 Each is ation valve specified in Table 3.6-1 shall be demonstrated PPERABLE during h COLD SHUTDOWN or REFUELING MODE at least once per 18 months by:
- a. V ifying that n a Phase A containment iso: . tion test signal, each ase A isolatio valve actuates to its isolation position.
- b. Verifying that on a ase B containment isolation test signal, each Phare B isolation val actuates to its isolation position.
. Verifying that on a Containment Purge and Exhaust isolation test signal, each Purge and Exhaust valve actuates to its isolation position.
- d. Cycling each weight or spring-loaded check valve not testable during plant operation, through one complete cycle of full travel and verifying that each check valve remains closed when the differential pressure in the direction of flow is less than (1.2) psid and opens when the differential pressure in the direction of flow is greater than or equal to (1.2) psid but less than (5.0) psid.
4.6.3.3 The isolation time of each power-operated or automatic valve of Table 3.6-1 shall be determined to be within its limit when tested pursuant to Specification 4.0.5. t i i l r W-SUBATMOSPHERIC 3/4 6-24C SEP 3 81981
TABLE 3.6-1
- CONTAINMEN sISOLATION, LVES 5 MAXIMUM E VALVE NUMBER .
FUNCTI \ ISOLATION TIME (Seconds) li A. PHASE "A" ISOLATION o 5 1. 2. B. PHASE "B" ISOLATION 1. 2. C. CONTAINMENT PURGE AND EXHAUST 1. 2.
?
0? D. MANUAL o 1. 2. E. OTHER 1. 2.
"May be opened on an intermittent basis under administrative control.
#Not subject to Type C leakage tests.
t N May be opened under administrative control in MODE 4 pursuant to Fi Specification 3.6.5.1. o **The provisions of Specification 3.0.4 are not applicable. co 00 a
I CONTA NT SYSTEMS 3/4.6.4\COMBUSTIB GAS CONTROL ! HYOROGEN ITOR LIMITING C0 FOR OPERATION 3.6.4.1 Two independ t containment hydrogen monitors shall be OPERABLE. APPL ABILITY: MODES 1 a 2. Ar N: ith one hydrogen monitor inoperable, restore the inoperable monitor to OPERABLE status within 30 days or be in at least HOT STANOBY within the next 6 hours. SURVEILLANCE REQUIREMENTS 4.6.4.1 Each hydrogen monitor shall be demonstrated OPERABLE by the perfor: nance of a CHANNEL CHECK at least once per 12 hours, a ANALOG CHANNEL OPERATIONAL TEST at least once per 31 days, and at least once per 92 days on a STAGGERED TEST BASIS by performing a CHANNEL CALIBRATION using sample gas containing:
- a. One volume percent hydrogen, balance nitrogen.
j b. Four volume percent hydrogen, balance nitrogen.
-W-SUBATMOSPHERIC 3/4 6-26C stP i 51981
i i CONTA T SYSTEMS ELECTRIC H OGEN RECOMBINERS - ,. )
! l LIMITING CONDITI FOR OP ATION 3.6.4.2 Two indeper t containment hydrogen recombiner systems shall be OPERABLE. /
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APPLICABILITY: " MODES 1 an 2. ACTION: With one/ hydrogen recombiner sys e inoperable, restore the inoperable system to OPERABLE status within 30 days r be in at least HOT STANDBY within the next 6 hours. RVEILLANCE REQUIREMENTS 4.6.4.2 Each hydrogen recombiner system shall be demonstrated OPERABLE:
- a. At least once per 6 months by verifying during a recombiner system functional test that the minimum heater sheath temperature increases to greater than (700)'F within (90) minutes. Upon reaching 700*F, increase the power setting to maximum power for 2 minutes and verify that the power meter reads greater than or equal to 60 Kw.
- b. At least once per 18 months by:
- 1. Performing a CHANNEL CALIBRATION of all recombiner instrumentation and control circuits,
- 2. Verifying through a visual examination that there is no evidence of abnormal conditions within the recombiner enclosure (i.e., loose wiring or structural connections, deposits of foreign materials, etc.), and
- 3. Verifying the integrity of all heater electrical circuits by performing a resistance to ground test following the above required functional test. The resistance to ground for any heater phase shall be greater than 10,000 ohns.
0 W-SUBATMOSPHERIC 3/4 6-27C AUG
i DENTAINMENT SYSTEMS HYD EN PURGE CLE P SYSTEM (If less than two hydrogen recombiners available) , i f LIMITING C 0 , ON FOR OPERATION l 3.6.4.3 cont 'nment hydrogen purge cleanup system shall be OPERA 8LE and , capabl of being ered from a minimum of one OPERABLE emergency bus. APPL ABILITY: MOD .1 and 2. A ON: With the containment hydrogen purge cleanup system inoperable, restore the hydrogen purge cleanup system to OPERABLE status within 30 days or be in at least HOT STANOBY within 6 hours. SURVEILLANCE REQUIREMENTS 4.6.4.3 The hydrogen purge cleanup system shall be demonstrated OPERA 8LE:
- a. At least once per 31 days by initiating, from the control room, flow through the HEPA filters and charcoal adsorbers and verifying that the system operates for at least 10 hours with the heaters on.
- b. At least once per 18 months or (1) after any structural maintenance on the HEPA filter or charcoal absorcer housings, or (2) following painting, fire, or chemical release in any ventilation zone communicating with the system by:
- 1. Verifying that the cleanup system satisfies the in place
- testing acceptance criteria and uses the test procedures of Regulatory Positions C.5.a, C.S.c and C.S.d of Regulatory Guide 1.52, Revision 2, March 1978, and the system flow rate is cfm 10L
- 2. Verifying within 31 days after removal that a laboratory analysis of a representative carbon sample obtained in accordance with Regulatory Position C.6.b of Regulatory Guide 1.52, Revision 2, March 1978, meets the laboratory testing criteria of Regulatory Position C.6.a of Regulatory Guide 1.52, Revision 2, March 1978.
l 6
. W-SUBATMOSPHERIC 3/4 6-28C S3G l
MNTAINMENTSYSTEMS SU LLANCE REOUI _MENTS (Continued) c.
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A er every 720 hours of charcoal adsorber operation by verifying y1t 'n 30 days after removal that a laboratory analysis of a repre tative carbon sample obtained in accordance with Regulatory Positio .6.b of Regulatory Guide 1.52, Revision 2, March 1978, meets the boratory testing criteria of Regulatory Position C.6.a of Regulatory Guide 1.52, Revision 2, March 1978.
- d. At least once p 18 months oy:
- 1. Verifying that 'he pressure drop across the combined HEPA filters and char al adsorber banks is less than (6) inches Water Gauge while operating the system at a flow rate of cfm 1 10%.
- 2. Verifying that the filter cooling bypass valves can be manually opened.
- 3. Verifying that the heaters dissipate +
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kw when tested in accoraance with ASNI N510-1575. i
- e. After each complete or partial replacement of a HEPA filter bank by verifying that the HEPA filter banks remove greater than or equal to (99.95)%" of the DOP when they are tested in place in accordance with ANSI N510-1975 while operating the system at a flow rate of cfm 1 10%.
- f. After each complete or partial replacement of a charcoal adsorber i
bank by verifying that the charcoal adsorbers remove greater than or equal to 99.95% of a balogenated hydrocarbon refrigerant test gas when they are tested in place in accordance with ANSI N510-1975 while operating the system at a flow rate of cfm 1 10%. 99.95% applicable when a filter efficiency of 99% is assumed in the safety analyses; 99% when a filter efficiency of 90% is assumed. f W-SUBATMOSPHERIC 3/4 6-29C APR 15 E78
CONTAINMEN SYSTEMS HYOROGENMIXIhGSYSTEM( fonal) LIMITING CONDITION R OPERATION 1 x 3.6.4.4 Two dependent drogen mixing systems shall be OPERABLE. APPLICABI Y: MODES 1 and . ACTION: With ne hydrogen mixing system 1 operable, restore the inoperable system to OPE ABLE status within 30 days or be in at least HOT STANOBY within the next 6 hours. SURVEILLANCE REOUIREMENTS 4.6.4.4 Each hydrogen mixing system shall be demonstrated OPERABLE:
- a. At least once per 92 days on a STAGGERED TEST BASIS by starting each system from the control room and verifying that the system operates for at least 15 minutes.
- b. At least once per 18 months by verifying a system flow rate of at least cfm.
u-43tRATMOSPHERIC 3/4 6-30C AUG S 1981
CONTAINMENT SYSTEMS 3/4.6.5 S ATMOSPHERIC PRE _^ URE CONTROL SYSTEM STEAM JET AI JECTOR LIMITING CONDIT FER OPERATION
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3.6.5.1 Thejn/ side and utside manual isolation valves in the steam jet air ejector suction line shal be closed.
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APPLICABIfITY: MODES 1, 2 an 3.
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ACTIONi With the inside or outside manual isolation valve in the steam jet air ejector swi: tion line not closed, restore the valve to the closed position within 1 our or be in HOT SHUTDOWN within the next 12 hours. SURVEILLANCE REQUIREMENTS 4.6.5.1.1 The steam jet air ejector suction line outside manual isolation valve shall be determined to be in the closed position by a visual inspection prior to increasing the Reactor Coolant System temperature above 350*F and at least once per 31 days thereaf,ter. 4.6.5.1.2 The steam jet air ejector suction line inside manual isolation valve shall be determined to be sealed or locked in the closed position by a visual inspection prior to increasing the Reactor Coolant System temperature above 350*F. l l W-SUBATMOSPHERIC 3/4 6-31C 5 W8 l
l l Cb4TAINMENT SYSTEMS MEC CAL VACUUM PUMPS LIMITING C OITION F R OPERATION x , 3.6.5.2 Two a h ical vacuum pumps shall be OPERABLE. APPLICABILI : MODES , 2 and 3. ACTION: With e mechanical vacuum pu inoperable, restore the inoperable pump to OPE LE status within 30 days r be in at least HOT STANDBY within the next 6 ho s and in COLD SHUTDOWN within the following 30 hours. SURVEILLANCE RECUIREMENTS 4.6.5.2 Each mechanical vacuum pump shall be demonstrated OPERABLE at least once per 31 days on a STAGGERED TEST BASIS by:
- a. Starting (unless already operating) each pump from the control room.
- b. Verifying that each pump develops a pumping capacity of greater than or equal to scfm and discharges to the gaseous radwaste disposal
- system.
- c. Verifying that each pump operates for at least 15 minutes.
t I W-SUBATMOSPHERIC 3/4 6-32C MAR 151978 I 1
CONTAINM: T SYSTEMS 3/4 6.6 VA UM RELIEF ALVES (OPTIONAL) LIMITING CONDIT
/ ' FOR OPERATION
/
3.6.6 The primary cont 'nment to atmosphere vacuum relief valves shall be OPERAB with an actuatio set point of less than or equal to psid. APPLICABILITY: MODES 1, 2, and 4. AC ON: pthoneprimarycontainmenttoatm phere vacuum relief valve inoperable, restore the valve to OPERABLE status thin 4 hours or be in at least HOT STANDBY within the next 6 hours and in OLD SHUTDOWN withir. the following 30 hours. SURVEILLANCE REQUIREMENTS l 4.6.6 No additional Surevillance Requirements other than those required by Specification 4.0.5. { l l l W-SUBATMOSPHERIC 3/4 6-33C
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w e N SE ION 3/4.6D CONTAINMENT SYS 'MS SPECIFICATIONS F0 WEST ~ GHOU DUAL PE CONTAI :NT x I l s
i 3/4.6 CD TAINMENT SYSTE. 3/4.6.1 P MARY CONT NMENT CONTAINMENT EGRf Y Y LIMITING CONDITIBN FOR OPERATION
/
3.6.1.1 frimary CON INMENT INTEGRITY shall be maintained.
/
APPLIC/BILITY: MODES 1, , 3 and 4. ACTI N: Wit out primary CONTAINMENT INTEGRITY, restore CONTAINMENT INTEGRI1Y within one hour or be in at least HOT STANDBY within the next 6 hours and in COLD t SHUTDOWN within the following 30 hours. SURVEILLANCE REQUIREMENTS 4.6.1.1 Primary CONTAINMENT INTEGRITY shall be demonstrated:
- a. At least once per 31 days by verifying that all penetrations
- not capable of being closed by OPERABLE containment automatic isolation valves and required to be closed during accident conditions are closed by valves, blind flanges, or deactivated automatic ' valves secured in their positions except as provided in Table 3.6-2 of
. Specification 3.6.4.1.
- b. By verifying that each containment air lock is OPERABLE per l Specification 3.6.1.3.
l l c. After each closing of each penetration subject to Type B testing, except the containment air locks, if opened following a Type A or B test, by leak rate testing the seal with gas at P, (50 psig) and verifying that when the measured leakage rate for these seals is l added to the leakage rates determined pursuant to Specifica-tion 4.6.1.2.d for all other Type B and C penetrations, the combined leakage rate is less than or equal to 0.60 L,. Except valves, blind flanges, and deactivated automatic valves which are located insioe the containment and are locked, sealed or otherwise secured in the closed position. These penetrations shall be verified closed during each COLD SHUTDOWN except that such verification need not be performed l more often than once per 92 days. l W-DUAL
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3/4 6-1D
. - : E . _ " .
CON INMENT SYSTEMS CONTA NT LEAKAGE LIMITING C0 TION R OPERATION x 3.6.1.2 Cont nm t leakage rates shall be limited to:
- a. overall ~ tegrated leakage rate of:
! 1.
, Less than r equal to L,, (0.20) percent by weight of the con-tainment air er 24 hours at P,, (50 psig), or 1
- 2. Less than or equal o Lt, (0.10) percent by weight of the con-tainment air per 24 hours at a reduced pressure of Pg , (25 psig).
b. A conabinea leakage rate of less than or equal to 0.60 L, for all penetrations and valves subject to Type B and C tests, when pressurized to P3.
- c. A combined bypass leakage rate of less than or equal to (0.10) La#"
all penetrations identified in Table 3.6-1 as secondary containment bypass leakage paths when pressurized to P - a APPLICA8ILITY: MODES 1, 2, 3 and 4. l ACTION: With either (a) the measured overall integrated containment leakage rate exceeding 0.75 L, or 0.75 Lt, as applicable, or (b) with the measured ccmbined leakage rate for all penetrations and valves subject to Types B and C tests exceeding 0.60 L,, or (c) with the combined bypass leakage rate exceeding (0.10) L,, restore the overall integrated leakage rate to less than or equal to 0.75 L, or less than or equal to 0.75 L ,t as applicable, the combined leakage rate for all penetrations and valves subject to Type 8 and C tests to less than or equal to 0.60 L ,a and the combined bypass leakage rate to less than or equal to (0.10) L apri r to increasing the Reactor Coolant System temperature above 200 F. W-DUAL 3/4 6-20 OCT 1 1979
l N CONTAINMENT SYSTEMS
\
SURVEILL E REQUIRC NTS 1 i N/ 4.6.1.2 The to ainment leakage rates shall be demonstrated at the following nd testschedule/of10 in Appendix J hallFRbe50determined in conformance using the methods with the and provisions criteria of ANSI specified N45.4-(1972):
- a. hree Type A t ts (Overall Integrated Containment Leakage Rate) shall be conduct at 40 + 10 month intervals during shutdown at either P, (50 psig) at Pt (25 psig) during each 10 year sarvice
- period. The third test of each set shall be conducted during the shutdown for the 10 year plant inservice inspection.
- b. If any periodic Type A fails to meet either .75 L, or .75 Lt , the test schedule for subsequent Type A tests shall be reviewed and approved by the Commission. If two consecutive Type A tests fail to meet either .75 L, or .75 L t, a Type A test shall be performed at least every 18 months until two consecutive Type A tests meet either
.75 L, or .75 Lt at which time the above test schedule may be resumed.
- c. The accuracy of each Type A test shall be verified by a supplemental test which:
- 1. Confirms the accuracy of the Type A test by verifying that the difference between supplemental and Type A test data is within 0.25 L,, or 0.25 Lt*
- 2. Has a duration sufficient to establish accurately the change in leakage rate between the Type A test and the supplemental test.
- 3. Requires the quantity of gas injected into the containment or bled from the containment during the supplemental test to be equivalent to at least 25 percent of the total measured leakage at P, (50 psig) or Pt (25 psig).
- d. Type B and C tests shall be conducted with ga? at P, (50 psig) at intervals no greater than 24 months except for tests involving:
- 1. Air locks,
- 2. Penetrations using continuous leakage monitoring systems, and W-DUAL 3/4 6-30 % 15 577
CONTAJNMENT SYSTEMS SURVEILLA E REQUIREMENT (Continued)
- 3. alv s pressurized with fluid from a seal system.
- e. The pombi bypass leakage rate shall be determined to be less than or equal to 10) L, by applicable Type B and C tests at least once er 24 months ex t for penetrations which are not individually testable; penetratio not individually testable shall be determined to have no detectable le ge when tested with soap bubbles while the containment is pressurized to Pa (50 psig) during each Type A test.
- f. Air Locks shall be tested and demonstrated OPERABLE per Surveillance Requirement 4.6.1.3.
- g. Type B periodic tests are not required for penetrations continuously monitored by the Containment Isolation Valve and Channel Weld Pressur-ization Systems provided the systems are OPERABLE per Surveillance Requirement 4.6.1.4.
- h. Leakage from isolation valves that are sealed with fluid from a seal system may be excluded, subject to the provisions of Appendix J, Section III.C.3, when determining the combined leakage rate provided the seal system and valves are* pressurized to at least 1.10 Pa (55 psig) and the seal system capacity is adequate to maintain system pressure for at least 30 days,
- i. Type B tests for penetrations employing a continuous leakage monitoring system shall be conducted at Pa (50 psig) at intervals no greater than once per 3 years.
- j. The provisions of Specification 4.0.2 are not applicable.
W-00AL 3/4 6-40 E "
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CONTAINMENT SYSTEMS COSTAINMENT AIR LOC LIMITING DI ON FOR OPERATION
~1 3.6.1.3 ach con inment air lock shall be OPERABLE with:
- a. Both doors losed except when the air lock is being used for normal transit entr and exit through the containment, then at least one air lock door all be closed, and
- b. An overall air lo leakage rate of less than or equal to 0.05 L, at P,, (50 psig).
APPLICA8ILITY: MODES 1, 2, 3 and 4. ACTION:
- a. With one containment air lock door inoperable: '
- l. Maintain at least the OPERABLE air lock door closed and either restore the inoperable air lock door to OPERABLE status within 24 hours or lock the OPERABLE air lack door clos'ed.
- 2. Operation may then continue until performance of the next required overall air lock leakage test provided that the OPERABLE air lock door is verified to be locked closed at least once per 31 days.
- 3. Otherwise, be in at least HOT STANDBY within the next 6 hours and in COLD SHUTDOWN within the following 30 hours.
- 4. The provisions of Specification 3.0.4 are not applicable.
- b. With the containment air lack inoperable, except as the result of an inoperable air lock door, maintain at least one air lock door closed; restore the inoperable air lock to OPERA 8LE status within 24 hours or be in at least HOT STAN08Y within the next 6 hours and in COLD SHUTDOWN within the following 30 hours.
W-DUAL 3/4 6-60 MAR 15 7978
CONTAINMENT SYSTEMS SURVEILLA E REQUIREM 'TS 4.6.1.3
/
Each c tainment air lock shall be demonstrated OPERABLE:
/
- a. Within 7 shours following each closing, except when the air lock is bejngusedsformultipleentries,thenatleastonceper72 hours,by v,erifyingnoyetectablesealleakagebypressuredecaywhenthe olume betwee the door seals is pressurized to greater than or
/equaltoP,(50 sig) for at least 15 minutes, b By conducting over 11 air lock leakage tests at not less than P ,
(50 psig), and veri ying the overall air lock leakage rate is within its limit:
- 1. At least once per 6 months,# and
- 2. Prior te establishing CONTAINMENT INTEGRITY when maintenance has been performed on the air lock that could affect the air lock sealing capability.*
- c. At least once per 6 months by verifying that only one door in each
~
air lock can be opened at a time. 1 The provisions of Specification 4.0.2 are not applicable.
- Exemption to Appendix J of 10 CFR 50.
W-DUAL 3/4 6-7D SEP 151981
I CONTAINMEN SYSTEMS CONTAINMENT LATION vat E AND CHANNEL WELD PRESSURIZATION SYSTEMS (OPTIONAL) LIMITING CONDITIO R OPERATION _ .1 3.6.1.4 The ontainme isolation valve and channel weld pressurization systems sha be OPERABL . APPLICAB ITY: MODES 1, 2, and 4.
. ACTIO Wit the containment isolation valve or channel weld pressurization system in perable, restore the inoperable system to OPERABLE status within 7 days or in at least HOT STANDBY within the next 6 hours and in COLD SHUTDOWN within e following 30 hours.
SURVEILLANCE REQUIREMENTS ] 4.6.1.4.1 The containment isolation valve pressurization system shall be i demonstrated OPERABLE at least once per 31 days by verifying that the system is pressurized to greater than or equal to 1.10 P,(55 psig) and has adequate capacity to maintain system pressure for at least 30 days. 4.6.1.4.2 The containment channel weld pressurization system shall be demon-strated OPERABLE at least once per 31 days by verifying that the system is pressurized to greater than or equal to P, (50 psig) and has' adequate capacity to maintain system pressure for at least 30 days.
'f-DUAL 3/4 6-80
l CONTA NT SYSTEMS INTERNAL SSURE
\
LIMITING CONDITION FOR OPERATION t
^
3.6.1.5 Primary coh,tainment internal pressure shall be maintained between and /psig. ' APPLICABI Y: MODES 1 2, 3 and 4. ACTION-With he containment interna pressure outside of the limits above, restore the internal pressure to with1 the limits within 1 hour or be in at least HOT STANDBY within the next 6 hours and in COLD SHUTDOWN within the following 30 hours. I t SURVEILLANCE REQUIREMENTS 4.6.1.5 The primary containment internal pressure shall be determined to be within the limits at least once per 12 hours. l
)
1 W-DUAL 3/4 6-9D MAR 15 1976
CONTAIhMENT SYSTEMS AIRTEMPEhATURE LIMITING CONO ION FOR PERATION 1 , 3.6.1.6 Primary ntainment average air temperature shall not exceed 'F APPLICABILITY: MODE 1, 2, 3 and 4. ACTION: With the ntainment avera e air temperature greater than F, reduce the average r temperature to ' thin the limit within 8 hours, or be in at least HOT STAP BY within the next ours and in COLD SHUTDOWN within the following 30 hou . SURVEILLANCE REOUIREMENTS 4.6.1.6 The primary containment average air temperature shall be the arithmetical average of the temperatures at the following locations and shall be determined at least once per 24 hours: Location
, a.
b. C. d. e. l l l W-DUAL 3/4 6-100 JUL 151979
CONT NMENT SYSTEMS CONTAIN T VESSEL STRUCfTURAL INTEGRITY N FOR OPERATION LIMITINGCONDI(I 3.6.1.7
/
The struct al integrity of the containment vessel shall be maintained at a le e1 consistent h the acceptance criteria in Specification 4.6.1.7. APPLICABILITY: MODES 1, A 3 and 4.
/
ACT40N: l W'ith the structural integrity of e containment vessel not conforming to the
/above requirements, restore the structural integrity to within the limits prior to increasing the Reactor Coolant System temperature above 200'F.
SURVEILLANCE REQUIREMENTS 4.6.1.7 The structural integrity of the containment vessel shall be determined during the shutdown for each Type A containment leakage rate test (reference Specification 4.6.1.2) by a visual inspection of the exposed accessible interior and exterior surfaces of the vessel. This inspection shall be performed prior to the Type A containment leakage rate test to verify no apparent changes in appearance of the surfaces or other abnormal degradation. Any abnormal degrada-tion of the containment vessel detected during the above required inspections shall be reported to the Commission pursuant to Specification 6.9.1. { l W-DUAL 3/4 6-11D DEC 15 578
I CONTAJNMENT SYSTEMS CONTAI T VENTILATION SYS M LIMITING CON TION FO OPERATION s z 3.6.1.8 The i h) containment purge supply and exhaust isolation valves shall be se ed clos . Operation with the (8 inch) purge supply and/or exhaust i ation valv open shall be limited to less than or equal to (90) ho s per 365 days. APPL ABILITY: MODES 1, 2, and 4. . A CN:
/
With the (42 inch) containment purge supply and/or exhaust isolation valve (s) open, or with the (8 inch) purge supply and/or exhaust isolation valve (s) open for more than (90) hours per 365 days, close the open valve (s) within 1 hour ' or be in at least HOT STANDBY within the next 6 hours and in COLD SHUTDOWN within the following 30 hours. SURVEILLANCE REQUIREMENTS 4.6.1.8.1 The containment purge supply and exhaust isolation valves shall be verified to be:
- a. Closed at least once per 24 hours.
- b. Sealed - closed at least once per 31 days.
4.6.1.8.2 The cumulative time that the (8 inch) purge supply and exhaust isolation valves have been open during the past 365 days shall be determined at least once per 7 days. 4.6.1.8.3 At least once per 6 months on a STAGGERED TEST BASIS each sealed closed (42 inch) containment purge supply and exhaust isolation valve shall be demonstrated OPERABLE by verifying that the measured leakage rate is less than j or equal to (0.05) L,. 4.6.1.8.4 At least once per 3 months each (8 inch) containment purge supply and exhaust isolation valve shall be demonstrated OPERABLE by verifying that the measured leakage rate is less than or equal to (0.05) L,. W-DUAL 3/4 6-120 gp . 3g jag; I -. .
l CONTAI SYSTEMS 3/4.6.2 0 ESSURIZATIO ' ND COOLING SYSTEMS CONTAINMENT S Y SYST (credit taken for iodine removal) LIMITING CONDITldN R OPERATION s l 3.6.2.1 Iwo independent co ainment spray systems shall be OPERABLE with each spray system capable of takin suction from the RWST and transferring suction to the/ containment sump.
/
APPf1CAEILITY: MODES 1, 2, 3 and i /
- ACTION
With one containment spray system inoperable, restore the inoperable spray system to OPERABLE status within 72 hours or be in at least HOT STANDBY within the next 6 hours; restore the inoperable spray system to OPERABLE status within the next 48 hours or be in COLD SHUTDOWN within the following'30 hours. 4 i SURVEILLANCE REQUIREMENTS I [ 4.6.2.1 Each containment spray system shall be demonstrated OPERABLE:
- a. At least once per 31 days by verifying that each valve (manual, power operated or automatic) in the flow path that is not locked, sealed, or otherwise secured in position, is in its correct position.
- b. By verifying, that on recirculation flow, each pump develops a discharge pressure of greater than or equal to psig when tested pursuant to Specification 4.0.5.
- c. At least once per 18 months during shutdown, by:
- 1. Verifying that each automatic valve in the flow path actuates to its correct position on a test signal.
- 2. Verifying that each spray pump starts automatically on a test signal.
- d. At least once per 5 years by performing an air or smoke flow test through each spray header and verifying each spray nozzle is unobstructed.
JAN 151979 W-DUAL 3/4 6-13D
CONTAINMENT-SYSTEMS 3/4.6.2 PRESSURIZATI AND COOLING SYSTEMS CONTAINMENT YS EM (No credit taken for iodine removal) i LIMITING CONDIT N R OPERATION 3.6.2.1 Tpo ndependent ntainment spray systems shall be OPERA 8LE with each spray sy tem capable of ta g suction from the RWST and transferring suction , to the antainment sump. APP ABILITY: MODES 1, 2, 3 an 4. A ION: ' I
- a. With one containvent spray system inoperable and at least (four) containment cooling fans OPERABLE, restore the inoperable spray system to OPERABLE status within 7 days or be in at least HOT STANOBY within the next 6 hours and in COLD SHUTDOWN within the following 30 hours.
i
- b. With two containment spray systems inoperable and at least (four) containment cooling fans OPERABLE, restore at least one spray system to OPERABLE status within 72 hours or be in at least HOT STAN08Y within the next 6 hours and in COLD SHUTDOWN within the following 30 hours. Restore both spray systems to OPERABLE status within 7 days of initial loss or be in at least HOT STAN08Y within the neXt 6 hours and in COLD SHUTDOWN within the following 30 hours. I
- c. With one containment spray system inoperable and one group of required containment cooling fans inoperable, restore either the inoperable spray system or the inoperable group of cooling fans to OPERABLE status within 72 hours or be in at least HOT STANOBY within the next 6 hours and in COLD SHUTDOWN within the following 30 hours. Restore both the inoperable spray system and the inoperable group of cooling fans to OPERABLE status within 7 days of initial loss or be in at least HOT STANOBY within the next 6 hours and in COLD SHUTDOWN within the following 30 hours.
SURVEILLANCE REQUIREMENTS 4.6.2.1 Each containment spray system shall be demonstrated OPERA 8LE:
- a. At least once per 31 days by verifying that each valve (manual, power operated or automatic) in the flow path that is not locked sealed or otherwise secured in position, is in its correct position.
W-DUAL 3/4 6-140 MAR 151978
CONbiNMENTSYSTEMS SURVEILLANCE 9 EQUIREMENTS K ontinued) b. N/ ByverifMg,thatonrecirculationflow,eachpumpdevelopsa discharge p%Mssure of greater than or equal to psig when tested pursuant to . specification 4.0.5.
- c. A east once per 8 months, during shutdown, by:
- 1. Verifying that e h automatic valve in the flow path actuates to its correct pos ion on a test signal, and
- 2. Verifying that each s ay pump starts automatically on a
/d.
test signal. At least once per 5 years by perfdraing on air or smoke flow test through each spray header and verifying each spray nozzle is unobstructed. ' t l l l i W-DUAL 3/4 6-15D JUL 15 379
1 ! l i l CONTAIN T SYSTEMS ' ! SPRAY ADDI E SYSTEM (OPT AL) LIMITING CONDIT F0 PERATION
\ /
1 3.6.2.2 The spr ad ive system shall be OPERABLE with:
- a. As ay additiv tank containing a volume of between __ and gallons of tween and percent by weight NaOH lution, and
- b. Two spray additive edu ors each capable of adding NaOH solution 1
from the chemical additi e tank to a containment spray system pump ' fTow. APP ICABILITY: MODES 1, 2, 3 and 4. TION: With the spray additive system inoperable, restore the system to OPERABLE status within 72 hours or be in at least HOT STAND 8Y within the next 6 hours; restore the spray additive system to OPERA 8LE status within tne next 48 hours or be in COLD SHUTDOWN within the following 30 hours. SURVEILLANCE REQUIREMENTS 4.6.2.2 The spray additive system shall be demonstrated OPERABLE:
- a. At least once per 31 days by verifying that each valve (manual, power operated or automatic) in the flow path that is not locked, sealed, or otherwise secured in position, is in its correct position.
- b. At least once per 6 months by:
- 1. Verifying the contained solution volume in the tank, and
- 2. Verifying the concentration of the NaOH solution by chemical analysis.
- c. At least once per 18 months, during shutcown, by verifying that each automatic valve in the flow path actuates to its correct position on )
a test signal.
- d. At least once per 5 years by verifying each solution flow rate (to be determined during pre-operational tests) from the following drain connections in the spray additive system:
- 1. (Drain line location) 1 gpm
- 2. (Drain line location) 1 gpm W-0UAL 3/4 6-160 5M l
l _.
CONTAINkNTSYSTEMS CONTAINMEN\COOLINGSYSTEN (OPTIONAL) (Credit taken for iodine removal oy spray systems) /
\ /
LIMITINGCONDIf(ON'FOROPERATION i 3.6.2.3 (Two[inde ndent groups of containment cooling fans shall be OPERABLE with(two)pfan system to each group. (Equivalent to 100% cooling capacity.) APPLICABILITY: MODES 1, , 3 and 4.
/
ACTION:
/
, / a. With one group of the bove required containment cooling fans inoperable
/ and both containment sp y systems OPERABLE, restore the inoperable / group of cooling fans to OPERABLE status within 7 days or be in at least HOT STANDBY within the next 6 hours and in COLD SHUTDOWN within the following 30 hours.
- b. With two groups of the above required containment cooling fans inoperable, and both containment spray systems OPERABLE, restore at least one group of cooling fans to OPERABLE status within 72 hours or be in at least HOT STANDBY within the next 6 hours and in COLD SHUTDOWN within the following 30 hours. Restore both above required groups of cooling fans to OPERABLE status within 7 days of initial loss or be in at least HOT STANDBY within the next 6 hours and in COLD SHUTDOWN within the following 30 hours.
- c. With one group of the above required containment cooling fans inoperable and one containment spray system inoperable, restore the inoperable spray system to OPERABLE status within 72 hours or be in at least HOT STANDBY within the next 6 hours and in COLD SHUTDOWN within the following 30 hours. Restore the inoperable group of containment cooling fans to OPERABLE status within 7 days of initial loss or be in at least HOT STANDBY within the next 6 hours and in COLD SHUTDOWN within the following 30 hours.
SURVEILLANCE REQUIREMENTS 4.6.2.3 Each group of containment cooling fans shall be demonstrated OPERABLE:
- a. At least once per 31 days by:
- 1. Starting each fan group from the control room and verifying that each fan group operates for at least 15 minutes.
- 2. Verifying a cooling water flow rate of greater than or equal to gpm to each cooler.
- b. At least once per 18 months by verifying that each fan group starts automatically on a test signal.
W-DUAL 3/4 6-17D AIAR 151979
CONTAINM T SYSTEMS
\
CONTAINMEN1\ COOLING SYfr EM (OPTIONAL) (No credit taken fer iodine removal by spray syste ) LIMITING CONCI O FOR OPERATION 3.6.2.3 (Tw inde dent groups of containment cooling fans shall be OPERABLE with (two) an system to each grcup. (Equivalent to 100% cooling capacity.) APPLICA ITY: MODES 1, 3 and 4. ACTIO -
- a. With one group of the bove required containment cooling fans inoperable and both containment spray systems OPERABl.E, restore the inoperable group of cooling fans to OPERAELE status within 7 days or be in at
' least HOT STANOBY within the next 6 hours and in COLD SHUTDGWN within the following 30 hours.
- b. With two groups of the above required containment cooling fans incperable, and both containstent spray systems OPERABLE, restore at least one group of cooling fans to OPERABLE status within 72 hours or be in at least HOT STANDBY within the next 6 hours and in COLD SHUTDOWN within the following 30 hours. Restore both above required groups of cooling fans to OPERABLE status within 7 days of initial loss or be in at least HOT STANDBY within the next 6 hours and in COLD SHUTDOWN within the following 30 hours.
- c. With one group of the above required containment cooling fans inoperable and one containment spray system inoperable, restore either the inoperable group of containment cooling fans or the inoperable spray system to OPERABLE status within 72 hours or be in at least HOT STANDBY within the next 6 hours and in COLD SHUTDOWN within the following 30 hours. Restore both the inoperable group of containment cooling fans and the inoperable spray system to OPERABLE status within 7 days of initial loss or be in at least HOT STANDBY within the next 6 hours and in COLD SHUTDOWN within the following 30 hours.
SURVEILLANCE REQUIREMENTS 4.6.2.3 Each group of containment cooling fans shall be demonstrated OPERABLE:
- a. At least once per 31 days by:
- 1. Starting each fan group from the control room verifying that each fan group operates for at least 15 minutes.
- 2. Verifying a cooling water ficw rate of greater than or equal to gpm to each cooler.
- b. At least once per 18 months by verifying that each fan group starts automatically on a test signal.
W-0UAL 3/4 6-180 MAR 151979
l CONTA ENT SYSTEMS 3/4.6.3 ODINE CLEANUP SY iEM (OPTIONAL)
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LIMITING CONDITION FOR OPERATION 3.6.3 Two \ indepe/ ndent containment iodine cleanup systems shall be OPERABLE. , /\ l APPLICABILITY ( MODES 1, 2, 3 and 4.
/
ACTION: With one iodine cleanup estem inoperable, restore the inoperable system to OPERABfE status within 7 dbys or be in at least NOT STANDBY within the next 6 hourr/and in COLD SHUTDOWN w n the following 30 hours. SURVEILLANCE REOUIREMENTS 4.6.3 Each iodine cleanup system shall be demonstrated OPERABLE:
- a. At least once per 31 days on a STAGGERED TEST BASIS by initiating, from the control room, flow through the HEPA filters and charcoal adsorbers and verifying that the system operates for at least 10 .
hours with the heaters on. l b. At least once per 18 months or (1) after any structural maintenance i on the HEPA filter or charcoal adsorber housings, or (2) following painting, fire or chemical release in any ventilation zone communicating with the system by:
- 1. Verifying that the cleanup system satisfies the in place testing acceptance criteria and uses the test procedures of Regulatory Positions C.5.a, C.S.c and C.5.d of Regulatory Guide 1.52, Revision 2, March 1978, and the system flow rate is cfm
+ 10L
- 2. Verifying within 31 days after removal that a laboratory analysis of a representative carbon sample obtained in accordance with Regulatory Position C.6.b of Regulatory Guide 1.52, Revision 2, March 1978, meets the laboratory testing criteria of Regulatory Position C.6.a of Regulatory Guide 1.52, Revision 2, March 1978.
- 3. Verifying a system flow rate of cfm + 10% during system operation when tested in accordance with ANSI N510-1975.
W-DUAL 3/4 6-19D JUN 1 1979
CON \NMENTSYSTEMS SURVEILLA REQUIREMENTS ontinued)
- c. After ev 20 hours of charcoal adsorber operation by verifying within 31 s after removal that a laboratory analysis of a'repre-sentativ ca n sample obtained in accordance with Regulatory Positi C.6.b Regulatory Guide 1.52, Revision 2, March 1978, meets the laborat y testing criteria of Regulatory Position C.6.a of gulatory Guide .52, Revision 2, March 1978.
- d. A least once per 18 mo s by:
- 1. Verifying that the pres ure drop across the combined HEPA filters and charcoal adsorber banks is less than (6) inches Water Gauge while operating the system at a flow rate of cfm 1 10%.
- 2. Verifying that the system starts on either a Safety Injection Test Signal or on a Containment Pressure -High Test Signal.
- 3. Verifying that the filter cooling bypass valves can be opened by operator action.
- 4. Verifying that the heaters dissipate 1 kw when tested in accordance with ANSI N510-1975.
- e. After each complete or partial replacement of a HEPA filter bank by verifying that the HEPA filter banks remove greater than or equal to (99.95)%* of the DOP when they are tested in place in accordance with ANSI N510-1975 while operating the system at a flow rate of cfm 1 10%.
- f. After each complete or partial replacement of a charcoal adsorber l
bank by verifying that the charcoal adsorbers remove greater than or equal to 99.95% of a halogenated hydrocarbon refrigerant test gas wnen they are tested in place in accordance with ANSI N510-1975 while operating the system at a flow rate of cfm 1 10%. A 99.95% applicable when a filter efficiency of 99% assumed in the safety analyses; 99% when a filter efficiency of 90% is assumed. APR 151978
'd-0UAL 3/4 6-200
CONTA h NT SYSTEMS 3/4.6.4 C AINMENT ISO ATION VALVES N ,- LIMITING CONDITIGE FOR OPERATION
/ \
3.6.4 The containment isolation valves specified in Table 3.6-2 shall be OPERABLEp[ithisolationtimesasshowninTable3.6-2.
/
APPLICABILITY: MODES 1, 3Nand 2, \ 4.
/
ACTION: ylthoneormoreoftheisolationvalve(s)specifiedinTable3.6-2 inoperable,
/ maintain at least one isolation valve OPERABLE in each affected penetration / that is open and either:
- a. Restore the inoperable valve (s) te OPERABLE status within 4 hours, or
- b. Isolate each affected penetration within 4 hours by use of at least one deactivated automatic valve secured in the isolation position, or ,
- c. Isolate each affected penetration within 4 hours by use of at least one closed manual valve or blind flange; or
- d. Be in at least HOT STANDBY within the next 6 hours and in COLD SHUTDOWN within the following 30 hours.
SURVEILLANCE REQUIREMENTS 4.6.4.1 The isolation valves specified in Table 3.6-2 shall be demonstrated OPERABLE prior to returning the valve to service after maintenance, repair or l replacement work is performed on the valve or its associated actuator, control or power circuit by performance of a cycling test and verification of isolation time. I r W-DUAL 3/4 6-21D JUN 1 1979 L
CO AI M NT SYSTEMS SURVEIL E REQU S (Continued) 4.6.4.2 Eac isolation valva specified in Table 3.6-2 shall be demonstrated OPERABLE du the COLD SHUTDOWN or REFUELING MODE at least once per 18 months by:
- a. Verifying hat on a Phase A containment isolation test signal, each Phase A iso ation valve actuates to its isolation position.
- b. Verifying that n a Phase B containment isolation test signal, each
. Phase B isolatio valve actuates to its isolation position.
- c. Verifying that on a ontainment Purge and Exhaust isolation test
/
signal, each Purge and Exhaust valve actuates to its isolation position. 4.6.4.3 The isolation time of each pcwer operated or automatic valve of Table .1.6-2 shall be determined to be within its limit when tested pursuant to Specification 4.0.5. l l ! W-DUAL 3/4 6-22D l SEP 2 81981 l l
~' " ' '
C f jj TABLE 3.6-CONTAINMEFsISQtITIONVALVES I
. MAXIMUM ; VALVE NUMBER FUNCTIO ISOLATION TIME (Seconds) ! Ns l A. PHASE "A" ISOLATION 1.
2. i 8. PHASE "B" ISOLATION 1. 2. R *' C. CONTAINMENT PURGE AND
- T EXHAUST O
a 1. ! 2. D. HANUAL 1. 2. E. OTHER 1. 2. se E to (( u>
"May be opened on an intermittent basis under administrative control.
y E3 Not subject to Type C' leakage tests.
**The provisions of Specification 3.0.4 are not appilcable.
CON NMENT SYSTEMS 3/4.6. COMBUSTIBL GAS CONTROL HYOROGEN ITOR LIMITING CO N FOR OPERATION 3.6.5. Two indepen nt containment hydrogen monitors shall be OPERABLE. APP CABILITY: MODES 1 nd 2. ION: . With one hydrogen nonitor inop able, restore the inoperable monitor to OPERABLE status within 30 days or be in at least HOT STANDBY within the next 6 hours. 4 SURVEILLANCE REQUIREMENTS 4.6.5.1 Each hydrogen monitor shall be demonstrated OPERABLE by the performance of a CHANNEL CHECK at least once per 12 hours, a ANALOG CHANNEL OPERATIONAL TEST at least once per 31 days, and at least once per 92 days on a STAGGERED TEST BASIS by performing a CHANNEL CALIBRATION using sample gas containing:
- a. One volume percent hydrogen, balance nitrogen.
i
- b. Four volume percent hydrogen, balance nitrogen.
l l l W-00AL 3/4 6-240 SEP 15 G81
1 C0 TAINMENT SYSTEMS ELEC IC HYDROGE RECOMBINERS - W LIMITING
/
NDITION FOR OPERATION
/
/
3.6.5[2 Two in endent containment hydrogen recombiner systems shall be OPERABLE.
/
APPLICABILITY: MODE 1 and 2. ACTION:
- With one hydrogen recombiner system inoperable, restore the inoperable system to OPERABLE status within 30 days or be in at least HOT STANDBY within the next 6 hours.
/
, SURVEILLANCE F.EQUIREMENTS 4.6.5.2 Each hydrogen recombiner system shall be demonstrated OPERABL5:
- a. At least once per 6 months by verifying during a recombiner system functional test that the minimum heater sheath temperature increases to greater than or equal 700*F within 90 minutes. Upon reaching 700*F, increase the power setting to maximum power for 2 minutes and verify that the power meter reads grecter than or equal to 60 kw.
- b. At least once per 18 months by:
- 1. Performing a CHANhEL CALIBRATION of all recombiner instrumentation and control circuits,
- 2. Verifying through a visual examination that there is no .
evidence of abnormal conditions within the recombiner enclosure (i.e., loose wiring or structural connections, deposits of foreign materials, etc.), and
- 3. Verifying the integrity of all heater electt ical circuits by performing a resistance to ground test following the above required functional test. The resistance to ground for any heater phase shall be greater than or equal to 10,000 ohms.
W-DUAL 3/4 6-25D AUG 6@
i CONTAkNMENTSYSTEMS HYOROG PURGE CLEAN SYSTEM (If less than two hydrogen recombiners available) LIMITING C OITI FOR OPERATION s , 3.6.5.3 A c nt inment hydrogen purge cleanup system shall be OPERABLE and capable of eing owered from a minimum of cne OPERABLE emergency bus. APPLICA ITY: M0 S 1 and 2. ACTI Wi the containment hyd gen purge cleanup system inoperable, restore the drogen purge cleanup sy em to OPERABLE status within 30 days or be in at east HOT STANOBY within 6 ours. SURVEILLANCE REQUIREMENTS
/
4.6.5.3 The hydrogen purge cleanup system shall be demonstrated OPERABLE:
- a. At least once per 31 days by initiating, from the control room, flow through the HEPA filters and charcoal adsorbers and verifying that the system operates for at least 10 hours with the heaters on.
- b. At least once per 18 months or (1) after any structural maintenance on the HEPA filter or charcoal adsorber housings, or (2) following painting, fire, or chemical release in any ventilation zone communicating with the system by:
- 1. Verifying that the cleanup system satisfies the in place testing acceptance criteria and uses the test procedures of Regulatory Positions C.5.a, C.S.c and C.5.d of Regulatory Guide 1.52, Revision 2, March 1978, and the system flow rate is cfm 10%.
- 2. Verifying within 31 days after removal that a laboratory
, analysis of a representative carbon sample obtained in accordance with Regulatory Position C.6.b of Regulatory Guide 1.52, Revision 2, March 1978, meets the laboratory testing criteria of Regulatory Position C.6.a of Regulatory Guide 1.52, Revision 2, March 1978.
- 3. Verifying a system flow rate of cfm 10% during system operation when tested in accordance with ANSI N510-1975.
l AUG G 1C81 l W-0UAL 3/4 6-26D l l
<SNTAINMENT SYSTEMS SURVEI ANCE REQUIREMENTS tinued)
N
- c. After ev y 720 hours of charcoal adsorber operation by verifying withi' 1 days after removal that a laboratory analysis of a repre-sent i'94 carbon sample obtained in accordance with Regulatory Pos) ion bg6.b of Regulatory Guide 1.52, Revision 2, March 1978, medits the laboratory testing criteria of Regulatory Position C.6.a f Regulatory'1uide 1.52, Revision 2, March 1978.
- d. At least once per 8 months by:
- 1. Verifying that t pressure drop across the combined HEPA filters and charco adsorber banks is less than (6) inches Water Gauge while op ating the system at a flow rate of cfm 1 10%.
- 2. Verifying that the filter cooling bypass valves can be manually opened.
- 3. Verifying that the heaters dissipate 1 kw when tested in accordance with ANSI N510-1975.
- e. After each complete or partial replacement of a HEPA filter bank by verifying that the HEPA filter banks remove greater than or equal to (99.95)%" of the DOP when they are tested in place in accordance with ANSI N510-1975 while operating the system at a flow rate of cfm 1 10%.
- f. After each complete or partial replacement of a charcoal adsorber bank by verifying that the charcoal adsorbers remove greater than or equal to 99.95% of a halogenated hydrocarbon refrigerant test gas l when they are tested in place in accordance with ANSI N510-1975 while operating the system at a flow rate of cfm 1 10%.
A l 99.95% applicable when a filter efficiency of 99% is assumed in the l safety analyses; 99% when a filter efficiency of 90% is assumed. W-DUAL 3/4 6-27D
s
's
, .-CONTA ENT SYSTEMS
, HYDROGEN ING SYSTE (Optional)
~w
\
c LIMITING CONDITI _ FOR OPERATION o N
., ' 3.6.5.4 Tw independe hydrogen mixing systems shall be OPERABLE.
APPLICABk[ITY: MODES 1 an 2. ACTION- 't s 1 With one hydrogen mixing system inoperable, restore the inoperable system to OPERABLE status'within 30 days or be in at least HOT STANDBY within the next 6 hours. m
~
SURVEILLANCE REQUIREMENTS 5 s
,. '4.6.5.4 Each hydrogen mixing system shall be demonstrated OPERABLE:
- a. At least once per 92 days on a STAGGERED TEST BASIS by starting each system frem the control room and verifying that the system operates for at idast 15 minutes.
- b. At least once per 18 months by verifying a system flow rate of at least cfm.
N i ..' i ',
\
\
s 4 9 l h[-00AL 3/4 6-280 AUG 6 1981
.. _ U - _ _ - _ _ _ _ _ .
CONTAINMENT SYSTEMS
.6.6 PENETRATION R00 EXHAUST AIR CLEANUP SYSTEM (OPTIONAL)
LIMITI
/
CONDITION /0R OPERATION s 3.6.6 TwoA ndependent containment penetration room exhaust air cleanup systems,shall beg 0PERABLE.
/ \
APPLICABILITY: MODES , 2, 3 and 4. ACTION: ith one containment penetra ~ n room exhaust air cleanup system inoperable,
/ restore the inoperable system t OPERABLE status within 7 days or be in at /leastHOTSTANDBYwithinthenext6hoursandinCOLDSHUTDOWNwithinthe following 30 hours.
SURVEILLANCE REQUIREMENTS 4.6.6 Each containment penetration room exhaust air cleanup system shall be demonstrated OPERABLE:
- a. At least once per 31 days on a STAGGERED TEST BASIS by initiating, from the control room, flow through the HEPA filters and charcoal
, adsorbers and verifying that the system operates for at least 10 hours with the heaters on.
- b. At least once per 18 months or (1) after any structural maintenance on the HEPA filter or charcoal adsorber housings, or (2) following painting, fire or chemical release in any ventilation zone communicating with the system by: .
- 1. Verifying that with the system operating at a flow rate of cfm + 10% and exhausting through the HEPA filters and charcoal adsorbers, the total bypass flow of the system to the facility vent, including leakage through the system diverting valves, is less than or equal to 1% when the system is tested by admitting cold DOP at the system intake. (For systems with diverting l valves.)
- 2. Verifying that the cleanup system satisfies the in place testing acceptance criteria and uses the test procedures of Regulatory Positions C.5.a, C.S.c and C.S.d of Regulatory Guide 1.52, Revision 2, March 1978, and the system flow rate is cfm + 10%.
W-DUAL 3/4 6-29D JUN I jg79
M INMENT SYSTEMS 1 SURVEILLAN E REQUIREMElfrS (Continued) j N
- 3. Vr1 ing within 31 days after removal that a laboratory analysis resentative carbon sample obtained in accordance with
[dfar Regulato
- Position C.6.b of Regulatory Guide 1.52, Revision 2, March 197 , meets the laboratory testing criteria of Regulatory Position C. a of Regulatory Guide 1.52, Revision 2, March 1978.
- 4. Verifying a sys flow rate of cfm 1 10% during system operation when tes in accordance with ANSI N510-1975.
- c. After every 720 hours of charcoal adsorber operation by verifying within 31 days after removal that a laboratory analysis of a repre-sentative carbon sample obtained in accordance with Regulatory Position C.6.b of Regulatory Guide 1.52, Revision 2, March 1978, meets the laboratory testing criteria of Regulatory Position C.6.a of Regulatory Guide 1.52, Revision 2, March 1978.
- d. At least once per 18 months by:
- 1. Verifying that the pressure drop across the combined HEPA filters and charcoal adsorber banks is less than (6) inches Water Gauge while operating the system at a ficw rate of cfm 1 10%.
- 2. Verifying that the system starts on a Safety Injection Test Signal.
- 3. Verifying that the filter cooling bypass valves can be manually opened.
- 4. Verifying that the heaters dissipate + kw when tested in accordance with ANSI N510-1975"- -
- e. After each complete or partial replacement of HEPA filter bank by verifying that the HEPA filter banks remove greater than or equal to (99.95)%* of the DOP when they are tested in place in accordance with ANSI N510-1975 while operating the system at a flow rate of cfm 1 10%.
- f. After each complete or partial replacement of a charcoal adsorber bank by verifying that the charcoal adsorbers remove greater than or equal to 99.95% of a halogenated hydrocarbon refrigerant test gas when they are tested in place in accordance with ANSI N510-1975 while operating the system at a flow rate of cfm 1 10%.
99.95% applicable when a filter efficiency of 99% is assumed in the safety analyses; 99% when a filter efficiency of 90% is assumed. 'f-00AL 3/4 6-300
C0hTAINMENT SYSTEMS 3/4 VACUUM RELIEF VAL
\ /
LIMITING CON 9JTION FOR OPERATION
/
3.6.7 The pr,fbry ntainment to atmosphere vacuum relief valves shall be OPERABLE wi,tt an actu ion set point of less than or equal to psid.
/
APPLIC BILITY: MODES 1, 3 and 4. ACTION: i' With one primary containment to tmosphere vacuum relief valve inoperable, l
/ restore the valve to OPERABLE sta s within 4 hours or be in at least HOT f' STANDBY with the next 6 hours and in COLD SHUTDOWN within the following i / 30 hours. /
I SURVEILLANCE REQUIREMENTS l 4.6.7 No additional Surveillance Requirements other than those required by Specification 4.0.5. l I 1 l l l l W-DUAL 3/4 6-31D JUN I gyg
CONTAINMENT SYSTEMS 3/4.6.8 SECONDARY CONTAINM SHIELD M G AIR CLE SYSTEM LIMITING CONDITIO OR OPERATION x 3.6.8.1 Two dependen shield building air cleanup systems shall be OPERABLE. APPLICABILI_ : MODES 1, 3 and 4. ACTION: With on shield building air el nup system inoperable, restore the inoperable system /t o OPERABLE status within days or be in at least HOT STAN0BY'within the next 6 hours and in COLD SHUTD0 within the following 30 hours. SURVE LLANCE REQUIREMENTS 4.6.8.1 Each shield building air cleanup system shall be demonstrated OPERABLE:
- a. At least once per 31 days on a STAGGERED TEST BASIS by initiating, from the control room, flow through the HEPA filters and charcoal adsorbers and verifying that the system operates for at least 10 hours with the heaters on.
- b. At least once per 18 months or (1) after any structural maintenance on the HEPA filter or charcoal adsorber housings, or (2) following painting, fire or chemical release in any ventilation zone communicating l with the system by:
1
- 1. Verifying that with the system operating at a flow rate of cfm 110% and exhausting through the HEPA filters and charcoal adsorbers, the total bypass flow of the system to the facility vent, including leakage through the system diverting valves, is less than or equal to 1% when the system is tested by admitting l cold 00P at the s, stem intake. (For systems with diverting
! valves).
- 2. Verifying that the cleanup system satisfies the in place testing acceptance criteria and uses the test procedures of Regulatory l Positions C.S.a, C.S.c and C.S.d of Regulatory Guide 1.52, l Revision 2, March 1978, and the system flow rate is cfm 1 10%.
i t W-DUAL 3/4 6-320 MAR I 51978
t CO INMENT SYSTEMS SURVEILL NCE REQUIREMc 5 (Continued)
- 3. Vpr'if ing within 31 days after removal that a laboratory analysis of a representative carbon sample obtained in accordance with
,- Regulatory Position C.6.b of Regulatory Guide 1.52, Revision 2,
~
,- March 1978, meets the laboratory testing criteria of Regulatory Pos + ion C.6.a of Regulatory Guide 1.52, Revision 2, March
/ 1978.
j
- 4. Verifyi a system flew rate of cfm + 10% during system 7 operation hen tested in accordance with XNSI N510-1975.
/ c. After every 720 urs of charcoal adsorber operation by verifying within 31 days after removal that a laboratory analysis of a repre-sentative carbon sample obtained in accordance with Regulatory Position C.6.b of Regulatory Guide 1.52, Revision 2, March 1978, meets the laboratory testing criteria of Regulatory Position C.6.a of Regulatory Guide 1.52, Revision 2, March 1978.
- d. At least once per 18 months by:
- 1. Verifying that the pressure drop across the combined HEPA 4
filters and charcoal adsorber banks is less than (6) inches Water Gauge while operating the system at a flow rate of cfm + 10%.
- 2. Verifying that the system starts on a Safety Injection Test Signal.
- 3. Verifying that the filter cooling bypass valves can be manually opened.
l 4. Verifying that each system produces a negative pressure of l greater than or equal to (0.25) inches W.G. in the annulus within (1) minute after a start signal.
- 5. Verifying that the heaters dissipate + kw when tested in accordance with ANSI N510-l W ~ .
- e. After each complete or partial replacement of a HEPA filter bank by verifying that the HEPA filter banks remove greater than or equal to (99.95)%* of the DOP when they are tested in place in accordance with AN5I N510-1975 while operating the system at a flow rate of cfm + 10%.
- f. After each complete or partial replacement of a charcoal adsorber bank by verifying that the charcoal adsorbers remove greater than or equal to 99.95% of a halogenated hydrocarbon refrigerant test gas when they are tested in place in accordance with ANSI N510-1975 while operating the system at a flow rate of cfm + 10%.
x 99.95% applicable when a filter efficiency of 99% is assumed in the safety analyses; 99% when a filter efficiency of 90% is assumed. 1 W-DUAL 3/4 6-33D JUL 151979
CON ENT SYSTEMS SHIELD ILDINGINTEdITY
\
LIMITING CON,DIT, N FOR OPERATION 3.6.8.2 S EL UILDING INTEGRITY shall be maintained. APPLICAMLITY: ES 1, 2, 3 and 4. l ,' l ACTION: Without SHIELD BUILDING NTEGRITY, restore SHIELD BUILDING INTEGRITY within 24 hours or be in at least H STANOBY within the next 6 hours and in COLD SHUTDOWN
-within the following 30 hou .
SURVEILLANCE REQUIREMENTS l 4.6.8.2 SHIELD BUILDING INTEGRITY shall be demonstrated at least once per 31 days by verifying that each door in each access opening is closed except when the access opening is being used for normal transit entry and exit, then at least one door shall be closed. 1 W-0UAL 3/4 6-340 SEP 1 1979 l
l CONTAINME T SYSTEMS SHIELD BUI ING STRUCTU L INTEGRITY
\ /
LIMITING CONDhTION 40R OPERATION 3.6.8.3 The atalevelco,druc ral integrity of the shield building shall be maintained nsisten with the acceptance criteria in Specification 4.6.8.3.
- l. . /
l APPLICABII'ITY: MODES 1, 2, 3 and 4. ACTION;!
/
With the structural integrity f the shield building not conforming to the above requirements, restore the structural integrity to within the limits within 24 hours or be in at least HOT STANDBY within the next 6 hours and in COLD SHUTDOWN within the following 30 hours. SURVEILLANCE REQUIREMENTS 4.6.8.3 The structural integrity of the shield building shall be determined during the shutdown for each Type A containment leakage rate test (reference Specification 4.6.1.2) by a visual inspection of the exposed accessible interior and exterior surfaces of the shield building and verifying no apparent changes in appearance of the concrete surfaces or other abnormal degradation. Any abnormal degradation of the shield building detected during the above required inspections shall be reported to the Commission pursuant to Specification 6.9.1. l W-DUAL 3/4 6-35D ApR 30 7979
3/4.7 PLANT SYSTEMS 3 /4. 7.1 TURBINE CYCLE SAFETY VALVES LIMITING CONDITION FOR OPERATION 3.7.1.1 All main steam line code safety valves associated with each steam
^ -
generator ;f r ...~.owsm ..v. www m.. ,ver shall be OPERABLE with lift settingsasspecifiedinTable3.7-%. L APPLICABILITY: MODES 1, 2 and 3. ACTION: 4
- a. With 4n7 reactor coolant loops and associated steam generators in operation and with one or more main steam line code safety valves inoperable, operation in MODES 1, 2 and 3 may proceed provided, that within 4 hours, either the inoperable valve is restored to OPERABLE status or the Power Range Neutron Flux High Trip Setpoint is reduced l
per Table 3.7-1; otherwise, be in at least HOT STANDBY within the l next 6 hours and in COLD SHUTDOWN within the following 30 hours. h (n-1) reactor coolant loops and associated steam gene in opera, with one or more main steam line code 6 valves associated witn . ting loop inoperable
~
ation in MODES 1, 2 and 3 may proceed provi m, + nours, either the inoperable valve is resto e .~ tus or the Power Range Neutron Flux Hic etpoint is reduced p 3.7-2; otherwise, OT STANDBY within the next 6 hours an .
. N within the following 30 hours.
b\ The provisions of Specification 3.0.4 are not applicable. - l l l l ( SURVEILLANCE RE0VIREMENTS i 4.7.1.1 No additional Surveillance Requirements other than those required by l Specification 4.0.5.
-W-STS 3/4 7-1 MAR 151979
TABLE 3.7-1 MAXIMUM ALLOWABLE POWER RANGE NEUTRON FLUX HIGH SETPOINT WITH INOPERABLE STEAM LINE SAFETY VALVES OURING # LOOP OPERATION 4 Maximum Number of Inoperable Maximum Allowable Power Range Safety Valves on Any Neutron Flux High Setpoint Operating Steam Generator (Percent of RATED THERMAL POWER) l 1 (87) 2 .(JNJlof 3 44tY '$3 TABLE 3.7-2 MAXIMU ABLE POWER RANGE NEUTRON FL HIGH SET 00 INT WITH INOPERABLE STEM LINE SAFETY VALVES 00 RING N-l LOOP OPERATION Maximum Number of Inoperable aximum Allowable Power Range Safety Valves on Any Neutron Flux High Setpoint Ooerating Steam Generator * (Percent of RATED THERMAL POWER) 1 (52) 2 (38) 3 (25) l l
"At least
- o safety valves shall be OPERABLE on the non-op ating steam genera .
'-STS f 3/4 7-2 MAR 151973
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PLANT SYSTEMS AUXILIARY FEEDWATER SYSTEM LIMITING CONDITION FOR OPERATION 3.7.1.2 At least three independent steam generator auxiliary feedwater , pumps and associated flow paths shall be OPERABLE with:
- a. Two motor-driven auxiliary feedwater pumps, each capable of being powered from separate emergency busses, and b.
One steam turbine-driven auxiliary feedwater p* ump capable of being powered from an OPERABLE steam supply system. APPLICA8ILITY: MODES 1, 2, and 3. ACTION:
- a. With one auxiliary feedwater pump inoperable, restore the required auxiliary feedwater pumps to OPERABLE status within 72 hours or be in at least HOT STANDBY within the next 6 hours and in HOT SHUTDOWN within the following u 6 hours.
- b. With two auxiliary feedwater pumps inoperable, be in at least HOT STANOBY witin 6 hours and in HOT SHUTOOWN within the following 6 hours.
( c. With three auxiliary feedwater pumps inoperable, immediately initiate corrective action to restore at least one auxiliary feedwater pump to OPERABLE status as soon as possible. SURVEILLANCE REQUIREMENTS
- 4.7.1.2 Each auxiliary feedwater pump shall be demonstrated OPERABLE:
- a. At least once per 31 days by:
- 1. Verifying that each motor driven pump develops a m _J- :- to4d wc Wad poseemme of greater than or equal to Mso 964, at a flow of greater than or equal to 400 gpm. y
- 2. Verifying that the steam turbine driven purr.p developsNd af- yneichead 9eseeemen of greater than or equal to 39509ete at a flow of greater than or equal to 400 gpm when the secondary steam supply pressure is greater than h psig The provisions of Specification 4.0.4 are not applicaole for entry into MODE 3.
W *('*U GS s% ressue f less k,, 900 f,'O , & Ot CA F w l W-STS 3/4 7-4 g 8cas, % ,f, a pY'" al n, u" oo'f'rp m. g 7 jeg
PLANT SYSTEMS SURVEILLANCE REOUIREMENTS (Continued)
- 3. Verifying that each non-automatic valve in the flow path that is not locked, sealed, or otherwise secured in position is in its correct position.
( 4. Verifying that each automatic valve in the flow path is in the l fully open position whenever the auxiliary feedwater system is ! placed in automatic control or when above 10% RATED THERMAL POWER.
- b. At least once per 18 months during shutdown by:
- 1. Verifying that each automatic valve in the flow path actuates to its correct position upon receipt of an auxiliary feedwater actuation test signal.
- 2. Verifying that each auxiliary feedwater pump starts as designed automatically upon receipt of an auxiliary feedwater actuation test signal.
- 5. Verdsing kh4e vbe sa de sufin pne ,{each auuitary 6La/equ-f L -L pula., Sece,en OJaeSyde , aa+=~hady aduales b ifs WI To y*si+nn ui4k:n to.ss h an or egual lo 10 se&z on a /sga/sw:%
fesfsignal.
- 5. Jer&ng fd-lhe wa(c.l;*n << \vec in +he anih**y -[<</wolre y rue / san U se s ar< epa ad $d poer is somove4 4 n +L. va.\ve ofera.+ves on alus cA 94 ~M, cd- % as cA- 114 W-STS 3/4 7-5 JUL 2 31960
M SYSTEMS C0 SATE STORAGE TANK LIMITING OITION FOR OPERATION x , 3.7.1.3 The con nsate storage tank (CST) shall be OPERA with a contained water volume of a least gallons of water. APPLICABILITY: MODE , 2, and 3. ACTION: With the condensate storage k inoperable, hin 4 hours either:
- a. Restore the CST to OPE LE stat or be in at least HOT STANDBY within the next 6 hours d in T SHUTDOWN within the following 6 hours, or
- b. Demonstrate the OPERABILI o the (alternate water source) as a backup supply to the a liary edwater pumps and restore the condensate storage ta to OPERA E status within 7 days or be in at least HOT STANOBY w hin the next hours and in HOT SHUTDOWN within the following 6 h rs.
SURVEILLANCE REQUIREME S 4.7.1.3.1 The e sate storage tank shall be demonstra d OPERABLE at least once per 12 ho s by verifying the contained water volume within its limits when the tan is the supply source for the auxiliary feedwat r pumps. 4.7.1.3. The (alternate water source) shall be demonstrated ERABLE at least o e per 12 hours by (method dependent upon alternate sour ) when,ever the ( ternate water source) is the supply source for the auxilia feedwater p . , e l l l l PSTS 3/4 7-6 JUL 2 31980
PLANT SYSTEMS ffcirar- ACTIVITY LIMITING CONDITION FOR OPERATION 3 )s 3.7.1.4 The specific activity of the secondary; coolant system shall be less than or equal to 0.10 microcuries/ gram DOSE EQUIVALENT I-131. APPLICABILITY: MODES 1, 2, 3, and 4. ACTION: Je With the specific activity of the secondary 2' coolant system greater than 0.10 microcuries/ gram DOSE EQUIVALENT I-131, be in at least HOT STANDBY within 6 hours and in COLD SHUTDOWN within the following 30 hours. SURVEILLANCE REQUIREMENTS 3 sbs-4.7.1.4 The specific activity of the secondaryAccolant system shall be determined to be within the limit by performance of the sampling and analysis program of Table 4.7-1. l l PSTS 3/4 7 7 JUL 15 $79
TABLE 4.7-1 SECONDARY i C00LANT SYSTEM SPECIFIC ACTIVITY SAMPLE AND ANALYSIS PROGRAM TYPE OF MEASUREMENT SAMPLE AND ANALYSIS AND ANALYSIS FREQUENCY l 1. Gross Activity Determination At least once per 72 hours. ffed{ts
- 2. Isotopic Analysis for DOSE a) I per 31 days, when-EQUIVALENT I-131 Concentration ever the gross activity determination indicates wMi+ne concentrations greater than 10% of the allowable limity g;g,sta ydfis b) I per 6 mon when-ever the gross activity determination indicates W concentrations below 10% of the allow-ablelimig
.beradistolhe t
l l l l t
'f-STS 3/4 7-8 MAY 151976
PLANT SYSTEMS MAIN STEAM LINE ISOLATION VALVES LIMITING CONDITION FOR OPERATION 4 3.7.1.$ Each main steam line isolation valve shall be OPERABLE. APPLICABILITY: MODES 1, 2, and 3. ACTION: MODE 1 - With one main steam line isolation valve inoperable but open, POWER OPERATION may continue provided the inoperable valve is restored to OPERABLE status within 4 hours; otherwise reduce power to less than or equal to 5 percent of RATED THERMAL POWER within 2 hours. MODES 2 - With one main steam line isolation valve inoperable, subsequent and 3 operation in MODES 2 or 3 may proceed provided: i
- a. The isolation valve is maintained closed.
- b. The provisions of Specification 3.0.4 are not applicable.
Otherwise, be in HOT STANDBY within the next 6 hours and in HOT SHUTDOWN within the following 6 hours. SURVEILLANCE REQUIREMENTS i 4.7.1.$ Each main steam line isolation valve shall be demonstrated OPERABLE by verifying full closure within 85 seconds when tested pursuant to
- Specification 4.0.5.
l W-STS 3/4 7-9 AUG 6 561
l PLANT SYSTEMS 3/4.7.2 STEAM GENERATOR PRESSURE / TEMPERATURE LIMITATION LIMITING CONDITION FOR OPERATION 3.7.2 The temperatures of both the primary and secondary coolants in the steam generators shall be greater than (70)*F when the pressure of either coolant in the steam generator is greater than (200) psig. APPLICABILITY: At all times. ACTION: ' With the requirements of the above specification not satisfied:
- a. Reduce the steam generator pressure of the applicable side to less than or equal to (200) psig within 30 minutes, and
- b. Perform an engineering evaluation to determine the effect of tne overpressurization on the structural integrity of the steam generator.
Determine that the steam generator remains acceptable for continued i operation prior to increasing its temperatures above 200*F. SURVEILLANCE REOUIREMENTS 4.7.2 The pressure in each side of the steam generator shall be determined to be less than 200 psig at least once per hour when the temperature of either the primary or secondary coolant is less than 70*F. 1 1 l W-STS 3/4 7-10 JUN 1 1979
PLANT SYSTEMS 3/0.7.3 COMPONENT COOLING WATER SYSTEM LIMITING CONDITION FOR OPERATION 3.7.3 At least two independent component cooling water loops shall be OPERABLE. APPLICABILITY: H3 DES 1, 2, 3 and 4. ! ACTION: With only one component cooling water loop OPERABLE, restore at least two loops to OPERABLE status within 72 hours or be in at least HOT STANDBY within the next 6 hours and in COLD SHUTDOWN within the following 30 hours. SURVEILLANCE REQUIREMENTS 4.7.3 At least two component cooling water loops shall be demonstrated OPERABLE:
- a. At least once per 31 days by verifying that each valve (manual, power operated or automatic) servicing safety related equipment that is not locked, sealed, or otherwise secured in position, is in its correct position.
- b. At least once per 18 months during shutdown, by verifying that each automatic valve servicing safety related equipment actuates to its correct position on a . test signal.
\
l Sddy Lgu.h (Sy i l l l l l W-STS 3/4 7-11
PLANT SYSTEMS gucte4A 3/4.7.4 SERVICE WATER SYSTEM 3 LIMITING CONDITION FOR OPERATION wlue 3.7.4 At least two independent service g water loops shall be OPERABLE. APPLICABILITY: MODES 1, 2, 3 and 4. ACTION: m \aar With only oneAservice water loop OPERABLE, restore at least two loops to OPERA 8LE status within 72 hours or be in at least HOT STAN08Y within the next 6 hours and in COLD SHUTDOWN within the following 30 hours. SURVEILLANCE REQUIREMENTS
# 6 .
4.7.4 At least two$ service water loops shall be demonstrated OPERABLE:
- a. At least once per 31 days by verifying that each valve (manual, power operated or automatic) servicing safety related equipment that is not locked, sealed, or otherwise secured in position, is in its correct position,
- b. At least once per 18 months during shutdown, by verifying that each automatic valve servicing safety related equioment actuates to its correct position on a . test signal. .
I Sa[ely hjee/M Og) W-STS 3/4 7-12 MAY 151975
PLANT SYSTEMS Sr428V MUL f(tvact QA14t. bfA 3/4.7.5 s_ ~:"' ~: "I' ~ !!'" ' ^ ~'! ?"i' } LIMITING CONDITION FOR OPERATION sMg Maestrwa uM&M 3.7.5 The4. ^.:.~. :.u: :'" shall be OPERABLE with: 57o. [ed
- a. A minimum water level at or above elevation (j ) Mean Sea Level,
( USGS datum, and Elev. 54* 'io L-
- b. Anaveragewatertemperatureoflessthanorequalto(2s.C) Fd, ~
inkkesftw;fure. APPLICABILITY: MODES 1, 2, 3 and 4. ACTION: With the requirements of the above specification not satisfied, be in at least HOT STANDBY within 6 hours and in COLD SHUTDOWN within the following 30 hours. SURVEILLANCE REQUIRMENTS slaS tucI' Stercce "N'V"l 4;7.5 Theftig : * :: shall be determined OPERABLE: g .:.:- st .._,._a
',_---+ ---- --
. 7. . . , . 7 , , _... = =;; 21:- . - ;: :t=
1
- -1... was 4 i ...,m
- a. A4 Last once pr 24 bars 6g ve6fy/g A, ,.de Wel 4 (e c.,;)4;n (b Dmr4
- h. A4. leas-I onen pr 1H hours he'*f Ne W"fkt of LL Augus4 / andSep+ea,tec b) yectff /$ O c eafee femperdure h b Jin b I'"" p
- c. A4 \ess4 enee gee n *=^4Ls E8 visually psfechq Awh a4 ger;.f.ying u ahvermd Lagruidn', cresu% ar excassive seapp, s
W-STS 3/4 7-13 SEP I 51978
NT SYSTEMS 3/ .6 FLOOD PROTECTION (OPTIONAL *), LIMIT CONDITION FOR OPERATION 1 I 3.7.6 Floo rotection shall be provided for all safety relate systems, components an structures when the water level of the sually the ultimate heat nk) exceeds Mean Sea Level USGS datu , at . j APPLICABILITY: A all times. l ACTION: l With the water level at above elevation Mean Sea Level USGS datum:
- a. (Be in at least HO STANDBY within 6 urs and in at least COLD SHUTDOWN within the ollowing 30 ho s) and
- b. Initiate and complete ithin hours, the following flocu protection measures:
- 1. (Plant dependent)
- 2. (Plant dependent) i SURVEILLANCE REQUIREMENTS i
4.7.6 The water level at shall be dete ned to be within the limits by:
- a. Measurement at 1 st once per 24 hours hen the water level is below elevation ean Sea Level USGS dat , and
- b. Measurement least once per 2 hours when he water level is equal to or abov elevation Mean Sea Level GS datum.
l
- This speci 1 cation not required if the facility design has adequate passive flood co rolprotectionfeaturessufficienttoaccommodatetkDesignBasis Flood i entified in Regulatory Guide 1.59, August 1973. A
\
W-STS 3/4 7-14 NOV 151977
l l l i 1 ( l l l PLANT SYSTEMS AOSA %m s.A-rros! 3/4.7.D CONTROL C" OCRGO4C" AIR CLEA;4UP SYSTEM LIMITING CONDITION FOR OPERATION AceaVen4.%hea 1 3. 7. )fo Two independent control i n r: ;: n _. '
...,, systems shall be OPERABLE.
l APPLICABILITY: ALL MODES ACTION: MODES 1, 2, 3 and 4: With one control A mx; Ve*b;:-SN" ". c':: r; system inoperable, restore the inoperable system to OPERABLE status within 7 days or be in at least HOT STANDBY within the next 6 hours and in COLD SHUTDOWN within the following 30 hours. MODES 5 and 6: l a. With one control::Ana : r Ve8*W.
; r:; - -
-'- - "r system inoperable, restore the inoperable system to OPERABLE status within 7 days or initiate and maintain operation of the remaining OPERABLE control room ;-.: ;r:; :' c' r system in the recirculation mode.
l l b. 2 L .4 = 6 W fa n p '- "- I With bot.h with the control c: OPERABLE r x ;;;-^^ control r;,:-i ; n:',: "::. systems
- inoperable,
.'.m.., system, or required to be in the recirculation mode by ACTION (a), not capable of being powered by an OPERABLE emergency power source, suspend all operations involving CORE ALTERATIONS or positive reactivity changes.
- c. .Secebuben Lo.4 cloes nk <eel y. .
SURVEILLANCE REQUIREMENTS 1
- 4. 7. '!f o Each control, Area Ve Rlohonm..
.~.....r.., i.. r system shall be demonstrated OPERABLE:
- a. At least once per 12 hours by verifying that the control room air temperature is less than or equal to (120) F.
- b. At least once per 31 days on a STAGGERED TEST BASIS by initiating, l
from the control room, flow through the HEPA filters and charcoal adsorbers and verifying that the system operates for at least 10 hours with the heaters ea.oge W i g l l l W-STS 3/4 7-15 JUL 2 71981
l l PLANT SYSTEMS l SURVEILLANCE REOUIREMENTS (Continued) i I
- c. At least once per 18 months or (1) after any structural maintenance i
on the HEPA filter or charcoal adsorber housings, or (2) following painting, fire or chemical release in any ventilation zone communicating with the system by: I h i'..lT,.u3 ..u;. ith th; g:': g.....us . T:-- . '.- eT -- , c' _ ;wa ouu muo . . uw ... . 3u .. uun i . ; wm . onw wn .-w.' l
, ' , . . , ,'-- t.. ' ,,.- T w.m ay a sem a T.. : ' i t, 4 .o2,:::, .a 4th;
- s. . .
,,,, ,-u-_ T '_ m
.u - . . . . . _ a t. . - -
)),,
~
- - .. ..,3 1'W {" {,,_
- . . _. . .... .,..... .... --. s. . ,,.....o o... . . . . , ...._ ,
i./. Verifying that the_ ': w system satisfies the in place testing acceptance criteria and uses the test procedures of Regulatory Positions C.S.a, C.S.c and C.S.d of Regulatory Guide 1.52, Revision 2, March 1978 and the system flow rate is Gooo cfm + 10%. ~ eagi Se k Z . [. Ve(rifying, hin wi(mtuses k M57 31 days after removal, gio that soskoas a 4a J9), laborator I of a representative carbon sample obtained in accordance with l Regulatory Position C.6.b of Regulatory Guide 1.52, Revision 2, March 1978, meets the laboratory testing criteria of Regulatory Position C.6.a of Regulatory Guide 1.52 Revision 2, March 1978,4ee a.aA y I tebla pwtedian a P len ,% 1 %.
- 3. /. Verifying a system flow rate of beoo cfm + 10% during system operation when tested in accordance with ANSI N510-1975.
- d. After every 720 hours of charcoal adsorber operation by verifying within 31 days after removal, that a laboratory analysis of a represen-tative carbon sample obtained in accordance with Regulatory Position C.6.b of Regulatory Guide 1.52, Revision 2, March 1978, meets the laboratory testing criteria of Regulatory Position C.6.a of Regulatory Guide 1.52, Revision 2, March 1978,foro m,A y l ;. 4 l, puhku / /cs 4.1 %.
- e. At least once per 18 months by:
- 1. Verifying that the pressure drop across the combined HEPA filters and charcoal adsorber banks is less than (6) inches Water Gauge while operating the system at a flow rate of 4dco cfm ,+ 10%.
- 2. Verifying that on a containment phase A isolation test signal, the system automatically switches into a recirculation mode of operation with flow through the HEPA filters and charcoal adsorber banks.
g/,
- 3. Verifying that the system maintains the control room at a positive pressure of greater than or equal to ' inch W.G. relative to the outside atmosphere during system operation.
- 4. Verifying that the heaters dissipate 25.o +25 kw when tested in accordance with ANSI N51G-1975.
W-STS 3/4 7-16 MAY la 560
PLANT SYSTEMS SURVEILLANCE REQUIREMENTS (Continued)
- f. After each complete or partial replacement of a HEPA filter bank by l verifying that the HEPA filter banks remove greater than or equal to '
(99.95)%K of the DOP when they are tested in place in accordance i with ANSI N510-1975 while operating the system at a flow rate of ! I, coo efm + 10%.
- g. After each complete or partial replacement of a charcoal adsorber bank by verifying that the charcoal adsorbers remove greater than or equal to 99.95% of a halogenated hydrocarbon refrigerant test gas when they are tested in place in accordance with ANSI N510-1975 while operating the system at a flow rate of 40c0 cfm + 10%.
l 1 l l l l h .: n _ a :... : -.... . ::: 1 . : : . ... , v. _ .; : : : c- ' - + t . n, -
- n
- j: ; , 0 ^^' - , , . . . . ' # ' + ^ - " ' : ' : :. :, : ' ^ ^*' 4 e nee"--d W-STS 3/4 7-17 MAY 151980
PLANT SYSTEMS Adonuac 80stbw4 88'mD "*"" #N 3/4.7. (ECCS PUMP ROOM EXHAUST AIR "" ~J.^27 SYSTFM _ k FILTRAT/04 LIMITING CONDITION FOR OPERATION
'} m kgliary Sidig 9ked E44ust Svska.
- 3. 7. k ": ' n f y . .,". . . '_
,_ .m _! ..t :! :!x.._,_ ,... shall be OPERABLE.
APPLICABILITY: MODES 1, 2, 3 and 4. ACTION:
% Au;l:ary 64%- Vikrol Edaus# $yshm Cy gy With -- o""'
r- - : t -:t :!- '-- g _,, ^.. inoperable, restore the inoperable system to OPERA 8LE status within " " ;: or be in at least HOT STANDBY within the next 6 hours and in COLD SHUTDOWN within the following 30 hours. SURVEILLANCE REQUIREMENTS T m" -hilt.,g s
" " " " alky~.Wr.t EWuM'sh 4.7.h ~
- t . _ _ ^. :y .:._..g :y:t: shall be demonstrated OPERABLE:
- a. At least once per 31 days 6 by initiating,
._....ow...: .. ._,. flow through the HEPA filters and charcoal adsorbers and verifying that the system operates for at least %= 6 minde.r.
- b. At least once per 18 months or (1) after any structural maintenance on the HEPA filter or charcoal adsorber housings, or (2) following painting, fire or chemical release in any ventilation zone communicating with the system by:
- t. '. . . : T.; ' : +" t _:;t. t.'. _,;t-- --- :.., . . .^;. ..:.. ;' ,
..'.. _ 1,^,~ .nu wm m.. 4 us .o o,.. .... ;;C.-^. T: .... --f -" ~ a=1
"- - - - - _ , .. ;. ; uy r . ii v- vi wo. .,. .m ^. ., . . . .' . : ;,
J ;. .t , .uwluviuy I. ! y __;I. II. ,;^^- di ~^ ^' .3 ..l..., . '.- M:: t' - ;- ;,_:: t: i f . .. . . . . .. ,, L i : t::t:d b " 'tt'--
. ,. we a i. suu .y.... . . . . . . trur ay . . .. i t 25....... .;I :: }
l 1/. Verifying that the e.leanup system satisfies the in place testing acceptance criteria and uses the test procedures of Regulatory Positions C.5.a. C.S.c and C.S.d of Regulatory Guide 1.52, Revision 2, March 1978, and the system flow rate is 2tece cfm 4
+ 10%'
~
Whe k a*Itions f A M.s: Ns'so Sea:au 8 and 9) W _-STS 3/4 7-18 MAY 151980
PLANT SYSTEPjS SURVEILLANCE REQUIREMENTS (Continued) - l
'2. . /. Verifying within 31 days after removal that a laboratory analysis of a representative carbon sample obtained in accordanca with Regulatory Position C.6.b of Regulatory Guide 1.52, Revision 2, March 1978, meets the laboratory testing criteria of Regulatory Position C.6.a of Regulatory Guide 1.52, Revision 2, March 1978; lor a mck f f ieJt44- pubb ef less ha 1%.
- 3. /. Verifying a system flow rate ofg cfm 110% during system operation when tested in accordance with ANSI N510-1975.
- c. After every 720 hours of charcoal adsorber operation by verifying within 31 days after removal that a laboratory analysis of a representative carbon sample obtained in accordance with Regulatory Position C.6.b of Regulatory Guide 1.52, Revision 2, March 1978, meets the laboratory testing criteria of Regulatory Position C.6.a of Regulatory Guide 1.52, Revision 2, March 19783 6r a methyl n.lile pnefra/m of leu 44a 1 %.
- d. At least once per 18 months by:
- 1. Verifying that the pressure drop across the combined HEPA filters and charcoal adsorber banks of less than (6) inches Water Gauge while operating the system at a flow rate of 29,000 cfm 1 10%.
- 2. Verifying that the system startsson a Safety Injection Test Signal,mLarects Hr c La,f. b Ar4.Ac WM 4/br a=l c/wetas/ aclue&ce.r.
m ,,__.,.,__m . .... .. < _ _ _ _ , ___ _ m - _ _ , , _
.,.. 4 .
": 'O' ;; 'tt it: t :12 : - " - - ' - " ,' L t:-
- e. After each complete or partial replacement of a HEPA filter bank by verifyin that the HEPA filter banks remove greater than or equal to (99.95). of the DOP when they are tested in place in accordance with ANSI N510-1975 while operating the system at a flow rate of 29,ocD cfm + 10%.
- f. After each complete or partial replacement of a charcoal adsorber bank by verifying that the charcoal adsorbers remove greater than or equal to 99.95% of a halogenated hydrocarbon refrigerant test gas when they are tested in place in accordance with ANSI N510-1975 while operating the system at a flow rate of 29.08 cfm 1 10%.
1
^ 3 pp[,-m - "
~ 2: . ::;. . ..3., _ .j. g .. . . A '- ' " --*-'y
__. _ _ -..... . .. n.er en m......, _. ._ _ _ , l W-STS 3/4 7-19 MAY 151980
NT SYSTEMS 3/ .9 SNUBBERS LIMIT CONDITION FOR OPERATION l s , 3.7.9 All .nubbers listed in Tables 3.7-ta and 3.7- b shall be OPERAB . APPLICABILITY: MODES 1, 2, 3, and 4. (MODES 5 and 6 for snubbers ocated on systems require OPERABLE in those MODES.) ACTION: With one or more snub rs inoperable, within 72 hours rep 1 e or restore the inoperabre snubber (s) gineering evaluation per Specification 4.7.% 9. OPERABLE status on the supported and perform component anthe supported or eclare system inoperable and foi ow the appropriate ACTION s tement for that system. SURVEILLANCE REQUIREMENTS 4.7.9 Each snubber shall be nstrated OPERA E by performance of the following augmented inservice in ection progr and the requirements of Specification 4.0.5.
~
- a. Visual Insoections 1, The first inservice visual i pection of snubbers hall be pe formed after 4 months but within 1 m nths of commencing WER OPERATION and shall include all snub ers isted in Tables 3.7- a and 3.7-Vb.
If less then two snubber are fo d inoperable during the first inservice visual inspec on, the shall be performed 12 onths t 25%gcond Trom the inservice date of visual inspection the first l inspection. Otherwi .,subsequentv\sualinspectionsshallbe performed in accord ce with the fall wing schedule: No. I:topera e Snubbers \SubsequentVisual oer Insoec on Period Inspection Period *# 0 18 onths + 25% 1 12 nths 7 25% 2 6m hs 7 25% 3,4 124 ys T 25% 5,6,7 62 da' s T 25% 8 or more 31 day i25% The nubbers may be categorized into two groups: ose accessible an those inaccessible during reactor operation. E h group may be spected independently in accordance with the above chedule.
"The i pection interval shall not be lengthened more than one step at a timeg #The ovisions of Specification 4.0.2 are not applicable.
aa < L be oss h.%, m%+ te~weus been iden+diel and carmted; ~t
% ne and 4ue r+epr Ae:,e(+ee if ne innferaiole un %+ evea4 snablos
- A*d he tarpah Sls 3/4 7-20 SEP 1 '980 l
I
x.s q
?
_P_LANT SYSTEM 5
~ SURVEIL CE RE0VIREMENTS (Continued)
- b. ksualInspectionAcceptanceCriteria h Vis'oal inspections shall verify (1) that there are no visible W indic'ations of damage or impaired OPERABILITY, (2) attachments to
- i ,
the fohndation or supporting structure are secure, and (3) in those locationg where snubber movement can be manually induced ithout disconnecting the snubber, that the snubber has freedom . movement and is not\ frozen up. Snubbers which appear inoperable s a result of visual i'nspections may be determined OPERABLE for t purpose of establishing \thenextvisualinspectioninterval,pr ding that (1)thecause\oftherejectionisclearlyestablish and remedied for that particular( snubber and for other snubbers tna may be generically s susceptible; any (2) the affected snubber is func Aonally tested in the ,. n as found conditi4n and determined OPERABLE per Sp)ecifications 4.7.9.d U V licable. However, when a fluid port of a ,h ~ or 4.7.9.e, hydraulic as ap'p\'s found to be uncovered the/ snubber shall be snubber N declared inoperable \and cannot be determineFDPERABLE via functional testing for the purp'ase of establishing the'next visual inspection
, interval. Allsnubbehsconnectedtoanigoperablecommonhydraulic fluid reservoir shall be counted as inoperable snubbers.
- c. Functional Tests
, At least once per 18 mont during,4hutdown, a representative sample 3
ofat_least(10%ofthetoQ1ofeachtypeofsnubberinuseinthe plant shall be functionally \ tested either in place or in a bench test. For each snubber that does ng,t meet the functional test acceptance criteria of Specification 4.7* .d or 4.7.9.e, an additional 10% of that type of snubber shall be nctionally tested until no more failures are found or untiT all nubbers have been functionally tested). of l \ (thatnumberofsnubbers*whichfoTowstheexpression35(1+f), where c* is the allowable number o snubbers not meeting the
, i The value c will be arbitrarDy chosen by the plicant and incorporated into
; the expressions for the representative sample a for the resample prior to the. issuance of the Technical Spe'cifications. The expressions are intended for use in plants with la'rger numbers of safety-re\ated snubbers (>500) and I
provide a confidence le4el of approximately 95% tha 90% to 100% of the snuboers in the plant pill be OPERABLE within accept le limits. That is,
,the confidence levelpill be provided no matter what v lue is chosen for c.
< It is advised, however, that discretion be used when in tially choosing the l
value for c because'the lower the value of c (the lower he amount of snubbers in the representative sample), the higher the unt of snubbers required in the ne-sample will be. To illustrate: If c = 2 and 3 snubbers are found not tg>' meet the functional test acceptance crite 'a, there will be 70 snubbers in/.he t representative sample and 31 snubbers re ired for testing in the re sampie; If c = 2 and 4 snubbers fail the functiona test, there l% will be 70 snubbers in the representative sample and 62 snubbe s required for testing in (he re-sample; If c = 0 and 1 snubber fails the functional test, there will be 35 snubbers in the representative sample and 140 snubbers required for testing in the re-sample; If c = 0 and 2 snubbers fail the functions test, there will be 35 snubbers in the representative sample and l, ~~ 280 snubbers requirec for testing in the re-sample. W-STS 3/4 7-21 Jip; , ; g
PLANT SYSTEMS PLANT SYSTEMS SURVEILLANEN(REQUIREMENTS (Continued) accep nce criteria selected by the operator, shall be functionally tested 'ther in place or in a bench test. For each number of snubbers bove c which does not meet the functional test acceptance criteria o Specifications 4.7.9.d. or 4.7.9.e, an additional sample selected ac rdinototheexpression35(1+f) c 1) (a - c) shall be func ionally tested, where a is the otal number of snubbers found inoperable during the functi al testing of the representative ample. t Functional testi shall continue accord' g to the expression b[35(1+j)(c+)]wherebisthe ber of snubbers found inoperable in the p evious re-sample until no additional inoperable snubbers are found ' thin a sample until all snubbers in Table 3.7-4a and 3.7 b have been unctionally tested). i The representative sa gle sele ed for functional testing shall include the various configuratAons,t operating environments and the range of size and capacity of snubbers. At least 25% of the snubbers in the representative sam k' shall include snubbers from the following three categories:
- 1. The first sn ber way from each reactor vessel nozzle,
- 2. Snubbers thin 5 fe t of heavy equipment (valve, pump,tur6ine, motor,etc.),
/
- 3. Snubbe/s within 10 feet of the siischarge from a safety j reli valve.
Snubbers ide tified in Tables 3.7-4a\and 3.7-4b as "Especially Difficult Remove" or in "High Radiation Zones During Shutdown" l shall als be included in the represerrtative sample.* Tables 3.7-4a 'd 3.7-4b may be used jointly ' separately as the basis for the s ling plan. In dition to the regular sample, snubbe which failed the pr vious functional test shall be reteste uring the next test riod. If a spare snubber has been instal ed in place of a failed snubber, then both the failed snubber (if it is repaired and installed in another position) and the spare nubber shall be retested. Test results of these snubbers may ot be included for the re-sampling. Permanent or other exemptions from functional testing fo individual snubbers in these categories may be granted by the Commission only if a justifiable basis for exemption is presented and/or snubber life destructive testing was performed to qualify snubber operability for all design conditions at either tne completion of their fabrication or at a subsequent date. , W-STS 3/4 7-22 SEp 16 MB9
PLANT SYSTEMS SURVEILLANCE R50VIREMENTS (Continued) 1 I If any nubber selected for functional testing ei er fails to lockup fails to nove, i.e.,-frozen in place, Ahe cause will be evaluate andifcausedbymanufacturerordes%ndeficiency,all snubbers the same design subject to the same defect shall be functional tested. This testing requiremepf. shall be independent of the requi ements stated above for snubbe s not meeting the l functional teit acceptance criteria. For the snubber ) found inoperable, an ngineering evaluation shall be performed on e components which a supported by the snubber (s). Thepurposeofth1%engineeringeval ion shall be to determine if the components supported by the snu r(s) were adversely affected bytheinoperability\ofthesnubbe s) in order to ensure that the supportad component rgmains capa of meeting the designed service.
- d. Hydraulic Snubbers Fun ctional \ st Acceptance Criteria
\ /
The hydraulic snubber fu ' tional test shall verify that:
- 1. Activation (restraini action) is achieved within the specified range of velocity on#ac'celeration in both tension and compression.
- - 2. Snubber bleed, o eleas rate, where required, is within the specified range compresi on or tensisn. For snubbers specifically required to no displace under continuous load, the ability of/the snubber to' withstand load without displacement shall be verffied.
- e. Mechanical Snubbe/rs Functional Test AEceptance Criteria The mechanica,1 snubber functional test 11 verify that:
, / \ i 1. The force that initiates free. movement of the snubber rod in ! eithe[ tension or compression is less han the specified maximum drag / force. Drag force shall not have creased more than 50% sine'e the last surveillance test.
- 2. Ac ivation (restraining action) it, achieve within the specified
'ange of velocity or acceleration in both t nsion and compression.
- 3. Snubber release rate, where required, is wit 'n the specified range in compression or tension. For snubber specifically required not to displace under continuous load, the ability of the snubber to withstand load without displacement shall be verified.
W-STS 3/4 7-23 *NOV 2 01950
--.g u-- ,
- - - . - 9
PLANT SYSTEMS I SURVEILLANCE REQUIRE TS (Continued)
- f. Snubber Service (ife Monitoring
' A record of the ser ce life of ea snubber, the date at which the designated service 11 e commences and the installation and mainte-nance records on which he desi ated service life is based shall be maintained as required b Spec' ication 6.10.2.
Concurrent with the first i ervice visual inspection and at least once per 18 months thereaf e the installation and maintenance records for each snubber iste in Tables 3.7-4a and 3.7-4b shall be reviewed to verify tha the indi ted service life has not been exceeded or will not exceeded f or to the next scheduled snubber service life review. If the indica d service life will be exceeded prior to the next heduled snubber s vice life review, the snubber service life shal be reevaluated or t snubber shall be replaced or reconditione so as to extend its ser 'ce life beyond the date of the next sched ed service life review. is reevaluation, replacement o reconditioning shall be indi ted in the records. l W-STS 3/4 7-24 NOV 2 01980
PLANT SYSTEMS 3/4.7.8 SNUBBERS LIMITING CONDITION FOR OPERATION 3.7.8 All snubbers listed in Tables 3.7 a and 3.7- b shall be OPERABLE. APPLICABILITY: MODES 1, 2, 3, and 4. ' MODES 5 and 6 for snubbers loce*ed on systems required OPERABLE in those MODES. ACTION: With one or more snubbers inoperable, within 72 hours replace or restore the inoperable snubber (s) to OPERABLE status and perform an engineering evaluation per Specification 4.7.8g. on the attached coc'ponent or declare the attached system inoperable and follow the appropriate ACTION statement for that system. SURVEILLANCE REQUIREMENTS 4.7.8 Each snubber shall be demonstrated OPERABLE by performance of the following augmented inservice inspection program and the requirements of Specification 4.0.5.
- a. Inspection Types -
As used in this specification, type of snubber shall mean snubbers of the same design and manufacturer, irrespective of capacity.
- b. Visual Inspections f.
y Snubbers are categorized as inaccessible or accessible during reactor operation and may be treated independently. The accessibility of j ' each snubber shall be determined and approved by the Station Health Physicist or qualified designee prior to performing each visual inspection. The determination shall be based upon the then existing radiation levels in each snubber location and the expected time to perform the visual inspection and shall be in accordance with the recommendations of Regulatory Guides 8.8 and 8.10. The first inservice visual inspection of each type of snubber shall ' be performed after 4 months but within 10 months of commencing POWER OPERATION 3.7-10. If less and shall include all snubbers listed in Tables 3.7-/h and ~ 3 3 _ than two snubbers of each type are found inoperable during the first inservice visual inspection, the second inservice visual inspection shall be performed 12 months 25% from the date of the first inspection. Otherwise, subsequent visual inspections shall be performed in accordance with the following schedule: l l McGUIRE - UNITS 1 and 2 3/4 7-18
~ ~~
PLANT SYSTEMS ( SURVEILLANCE REOUIREMENTS (Continued) No. Inoperable Snubbers of Each Time Until Subsequent Type Found During Inspection Visual Inspection *# 0 la months i 25% 1 12 months 25% 2 6 months 2 25% 3,4 124 days i 25% 5,6,7 62 days i 25% 8 or more 31 days 25%
- c. Refueling Outage Inspections At each refueling, the systems which have the potential for a severe dynamic event, specifically, the main steam system (upstream of the main steam isolation valves) the main steam safety and power-operated relief valves and piping, auxiliary feedwater system, main steam supply to the auxiliary feedwater pump turbine, and the letdown and charging portion of the CVCS system shall be inspected to determine if there has been a severe dynamic event. In case of a severe dynamic event, mechanical snubbers in that system which experienced the event shall be inspected during the refueling outage to assure that the mechanical snubbers have freedom of movement and are not frozen up. The inspection shall consist of verifying freedom of motion using one of the followin;: (1) manually induced snubber movement;
, (2) evaluation of in place snubber piston setting; (3) stroking the
( , mechanical snubber through its full range of travel. If one or more mechanical snubbers are found to bs' frozen up during this inspection, those snubbers shall be replaced or repaired before returning to power. The requirements of Specification 4.7.8b. are independendent of the. requirements of this specification.
- d. Visual Inspection Acceptance Criteria-Visual inspections shall verify: (1) that there are no visible
' indications of damage or impaired OPERABILITY, and (2) attachments to the foundation or supporting structure are secure. Snubbers which appear inoperable as a result of visual inspections may be determined OPERABLE for the purpose of establishing the next visual inspection interval, provided that: (1) the cause of the rejection is clearly established and remedied for that particular snubber and for other snubbers irrespective of type that may be generically susceptible;
- The inspection interval for each type of snubber shall not be lengethened more than one step at a time unless a generic problem has been identified and corrected; in that event the inspection interval may be lengthened one I
step the first time and two steps thereafter if no inoperable snubbers of that type are found.
# The provisions of Specification 4.0.2 are not applicable.
k, McGUIRE - UNITS 1 and 2 3/4 7-19
PLANT SYSTEMS SURVEILLANCE REQUIREMENTS (Continued)
- d. Visual Inspection Acceptance Criteria (Continued) and (2) the affected snubber is functionally testeo in the as found condition and determined OPERABLE per Specification 4.7.8f. When a fluid pcrt of a hydraulic snubber is found to be uncovered the snubber shall be declared inoperable and shall not be determined OPERABLE via functional testing unless the test is started with the piston in the as-found setting, extending the piston rod in the tension mode direction. All snubbers connected to an inoperable common hydraulic fluid reservoir shall be counted as inoperable snubbers.
- e. Functional Tests During the first refueling shutdown and at least once per refueling thereafter, a representative sample of snubbers shall be tested using one of the following sample plans. The sample plan shall be selected prior to the test period and cannot be changed during the test period. The NRC shall be nctified of the sample plan selected prior to the test period. _._
- 1) At least 10% of the snubbers required by Specification 3.7.8 shall be functionally tested either in place or in a bench test.
For each snubber that does not meet the functional test acceptance criteria of Specification 4.7.Sf., an additional 10% h of the snubbers shall be functionally tested until no more failures are found or until all snubbers have been functionally tested; or
- 2) A representative sample of the snubbers required by Specifica-tion 3.7.8 shall be functionally tested in accordance with Figure 4.7-1. "C" is the total number of snubbers found not meeting the acceptance requirements of Specification 4.7.8f.
The cumulative number of snubbers tested is denoted by "N." At the end of each day's testing, the new values of "N" and "C" (previous day's total plus current day's increments) shall be plotted on Figure 4.7-1. If at any time the point plotted falls in the " Reject" region all snubbers shall be functionally tested. If at any time the point plotted falls in the " Accept" region, testing of snubbers may be terminated. When the point plotted lies in the " Continue Testing" region, additional snubbers shall be tested until the point falls in the " Accept" region or the " Reject" region, or all the snubbers required by Specification 3.7.8 have been tested. Testing equipment failure during functienal testing may invalidate that day's testing and allow that day's testing to resume anew at a later time, provid-ing all snubbers tested with the failed equipment during the day of equipment failure are retested; or
- 3) An initial representative sample of fifty-five (55) snubbers shall be functionally tested. For each snubber which does not 'M meet the functional test acceptance criteria, another sample of McGUIRE,- UNITS 1 anri ? 3/4 7-20
. - - .g_ . 7 . - - . = . _ .
/
sqg , PLANT SYSTEMS SURVEILLANCE REQUIREMENTS (Continued)
- e. Functional Tests (Continued) at least one-half the size of the initial sample shall be tested until the total number tested is equal to the initial sample size multiplied by the factor,1 + C/2, where "C" is the numoer of snubbers found which do not meet the functional test acceptance criteria. This plan be plotted using an " Accept" line which follows the equation N = 55(1 + C/2). Each snubber should be plotted as 1
l soon as it is tested. If the point plotted falls on or below the " Accept" line, testing may be discontinued. If the point plotted falls above the " Accept" line, testing must continue unless all snubbers have been tested. The representative samples for the functional test sample plans shall be randomly selected from the snubbers required by Specifi-cation 3.7.8 and reviewed before beginning the testing. The review j shall ensure as far as practical that they are representative of the ' various configurations, operating environments, range of sizes, and ; capacities. Snubbers placed in the same locations as snubbers which ' failed the previous functional test shall be retested at the time of plan.next the functional test but shall not be included in the sample If during the functional testing, additional sampling is gr required due to failure of only one type of snubber, the functional
%ggs testing results shall be reviewed at that time to determine if additional samples should be limited to the type of snubber which has failed the functional testing.
'f. Functional Test Acceptance Criteria The snubber functional test shall verify that:
- 1) Activation (restraining action) is achieved within the specified range in both tension and compression, except that inertia dependent, acceleration limiting mechanical snubbers may be tested to verify only that activation takes place in both directions of travel;
- 2) Snubber bleed, or release rate where required, is present in both tension and compression, within the specified range,
- 3) Where required, the force required to* initiate or maintain motion of the snubber is within the specified range in both direction of travel; and
- 4) For snubbers specifically required not to displace under continuous load, the ability of the snubber to withstand load without displacement.
Testing methods may be used to measure parameters indirectly or parameters other than those specified if those results can be correlated to the specified parameters through established methods.
- g. Functional Test Failure Analysis An engineering evaluation shall be made of each failure to meet the
- z. 1 functional test acceptance criteria to determine the cause of the McGUIRE - UNITS 1 and 2 Amendment No. 1 (Unit 2) 3/4 7-21 Amendment No. 20 (Unit 1) 4/13/83 t
e
-i--,-g w--- ymm--. .- - - - , . , .e , - , , . -- -
. ~ l PLANT SYSTEMS SURVEILLANCE REQUIREMENTS (Continued) 3' '
- g. Functional Test Failure Analysis (Continued) failure. The results of this evaluation shall be used, if applicable, in selecting snubbers to be tested in an effort to determine the OPERABILITY of other snubbers irrespective of type which may be subject to the same failure mode.
For the snubbers found inoperable, an engineering evaluation shall be performed on the components to which the inoperable snubbers are attached. The purpose of this engineering evaluation shall be to determine if the components to which the inoperable snubbers are attached were adversely affected by the inoperability of the snubbers in order to ensure that the component remains capable of meeting the designed service. If any snubber selected for functional testing either fails to activate or fails to move, i.e., frozen-in place, the cause will be evaluated and, if caused by manufacturer or design deficiency, all snubbers of the same type subject to the same defect shall be evaluated in a manner to ensure their OPERABILITY. This testing requirement shall be independent of the requirements stated in Specification 4.7.8e. for snubbers not meeting the functional test acceptance criteria,
- h. Functional Testing of Recaired and Replaced Snubbers
{ Snubbers which fail the visual inspection or the functional test acceptance criteria shall be repaired or replaced. Replacement snubbers and snubbers which have repairs which might affect the functional test result shall be tested to meet the functional test criteria before installation in the unit. Mechanical snubbers shall have met the acceptance criteria subsequent to their most recent service, and freedom-of-motion test must have been performed within 12 months before being installed in the unit.
- i. Snubber Seal Replacement prooram The seal service life of hydraulic snubbers shall be monitored to ensure that the service life is not exceeded between surveillance inspections. The expected service life for the various seals, seal materials, and applications shall be determined and established based on engineering information and the seals shall be replaced so that the expected service life will not be exceeded during a period when the snubber is required to be OPERABLE. The seal replacements shall be documented and the documentation shall be retained in accordance with Specification 6.10.2.
McGUIRE - UNITS 1 and 2 3/4 7-22 m.v*** ~ ~
34 TABLE 3.7-Alf IF SAFETY RELATED HYDRAULIC SNUBBERS
- A w
IIIGil RADIATION SNUBBER SYSTEM SNUBBER INSTALLED ACCESSIBLE OR ZONE ESPECIALLY DIFFICULT NO. ON, LOCATION AND ELEVATION INACCESSIBLE DURING SHUTDOWN ** 10 REMOVE (A or 1) (Yes or No) (Yes or No)
-q, h 5 9A b Lb e*
k [
- Snubbers may be added to safety related systems without prior License Amendment to Table 3.7-%
un provided that a revision to Table 3.7- k is included with the next License Amendment request.
** Modifications to this column due to changes in high radiation areas may be made without prior License Admenment provided that a revision to Table 3.7- % is included with the next License Amendment request. K '
l 4 w (11 o
3h TABLE 3.7-AfI l[a SAFETY RELATED MECilANICAL SNUBBERS
- llIGil RADIATION SNUBBER SYSTEM SNUBBER INSI'ALLED ACCESSIBLE OR ZONE ESPECIALLY DIFFICULT NO. ON,10 CATION AND ELEVATION INACESSIBLE e DURING SiluT00WN** TO REMOVE (A or I) (Yes or No) (Yes or No)
, kc. IcA (Itk W M w p, m
h
- Snubbers may be added to safety related systems without prior License Amendment to Table 3.7-Aff 56 provided that a revision to Table 3.7-4b is included with the next License Amendment request.
4
^^Hodifications to this column due to changes in hi0h radiation areas may be without prior LicenseAmendmentprovidedthatarevisiontoTable3.7ph Amendment request. is included with the next License N
>s CJB O
ca
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_ . . .. ..- . - . . . w~~ ~- I PLANT SYSTEMS
~
10 9 l 8 7 REJECT 6 l , c of CONTINUE 3
' / -
[ 1[ ~ 2 - G ACCEPT - 1 g 0 10 20 30 40 50 60 70 80 90 100 N FIGURE 4.7-1 SAMPLFPLAN 2) FOR SNUBBER FUNCTIONAL TEST r , ( l McGUIRE - UNITS 1 and 2 3/4 7-29
1 PLANT SYSTEMS 9 3/4.7.3AP SEALED SOURCE CONTAMINATION LIMITING CONDITION FOR OPERATION 9 3.7.)6 Each sealed source containing radioactive material. either in excess of 100 microcuries of beta and/or gamma emitting material or 5 microcuries of alpha l emitting material shall be free of greater than or equal to 0.005 microcuries of remavable contamination. APPLICA2ILITY: At all times. - ACTION:
- a. With a sealed source having removable contamination in excess of the above limits, immediately withdraw the sealed source from use and
. either:
[
- 1. Decontaminate and repair the sealed source, or
- 2. Dispose of the sealed source in accordance with Commission Regulations.
- b. The provisions of Specifications 3.0.3 and 3.0.4 are not applicable.
SURVEILLANCE REQUIREMENTS 9 4.7.)d'.1 Test Requirements - Each sealed source shall be tested for leakage and/or contamination by:
- a. The licensee, or
- b. Other persons specifically authorized by the Commission or an Agreement State. ,
l The test method shall have a detection sensitivity of at least 0.005 l microcuries per test sample. I 9 4.7.Lf.2 Test Frequencies - Each category of sealed sources (excluding startup sources and fission detectors previously subjected to core flux) shall be tested at the frequency described below. :
- a. Sources in use - At least once per 6 months for all sealed sources l containing radioactive materials:
- 1. With a half-life greater than 30 days (excluding Hydrogen 3),
and
- 2. In any form other than gas.
W-STS 3/4 7-27 .NOV 2 01930
PLANT SYSTEMS SURVEILLANCE REQUIREMENTS (Continued)
- b. Stored sources not in use - Each sealed source and fission detector shall be tested prior to use or transfer to another licensee unless tested within the previous six months. Sealed sources and fission detectors transferred without a certificate indicating the last test date shall be tested prior to being placed into use.
- c. Startup sources and fission detectors - Each sealed startup source and fission detactor shall be tested within 31 days prior to being subjected to core flux or installed in the core and following repair or maintenance to the source.
i 4.7.)6.3 Reports - A report shall be prepared and submitted to the Commission ! on an annual basis if sealed source or fission datector leakage tests reveal ) the presence of greater than or equal to 0.005 microcuries of removable contamination. 1 .i l l l W-STS 3/4 7-28 NOV 2 01980
l 1 l i PLANT SYSTEMS k 3/4.7.Ff FIRE SUPPRESSION SYSTEMS 1 FIRE SUPPRESSION WATER SYSTEM i LIMITING CONDITION FOR OPERATION 10 3.7.yf.1 The fire suppression water system shall be OPERABLE with: A& lead
- a. 4 (Two) fire suppression pumps, each with a capacity of (2500) gpm, with their discharge aligned to the fire suppression header, W c^-- :t: ^
_.... : ;;i:. , e... ...........omu.. m v. . .. o m .
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__,,___ m b g. An OPERABLE flow path capable of taking suction from 4ho ,
': ' and transferring the water through distribution piping with OPERABLE sectionalizing control h valves de C..,_..,.'._.*-"' . -:' ::, t '. _ .
- t;.
c ' l-- . f..!_; -- ^--' "--' 'l.. ., . . . . , . ___.1 7 -" 7 , _. g . . I . __
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eac.'.h de4 eye g^ or spray system" 3 required to be OPERABLE per Specificakons .' . ^ ,b .- ' .: ..._ :. . " : 3 7.lo.2. .a/ . sgriaMer, besa sfaadf/fc 3.7804 APPLICABILITY: At all times. /gJdi" ylas ACTION fy/didrN**d a.
)he oU W With onegump and/or one water c;;'; inoperable, restore the inoper-able equipment to OPERABLE status within 7 days or, ' 'i:--
ct'r :;;.t -^-J' :f by "r--'.::t':: C . ^ .1, ;- ;;: : _ . .1 : _' . i t . e___,_, ,. - . _ , _ . , _ . , _ , _ _ . _....y. . .. .... ..-.. .... ,.... ... . .,... . . . . . . . .. ...e
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provide af whevosee, backup pump or supply. The provisions of Specifications 3.0.3 and 3.0.4 are not applicable.
- b. With the fire suppression water system otherwise inoperable y 5 kstablish a backup fire suppression water system within 24 hours A
^
. I- :1 c' x., .
.r._ -
7--' ---"i- d 5; :;..:T: '#4- ..:.. :." ', i -:"' 't . r e.:;l ",;;z-t '- x::-f:.x 't' !; '4aa 8 o ?r _,3 n. i_, . --
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! M l l W-STS 3/4 7-29 MAY 15 G80
l ! l l c.% cog eas esa s wo ,a uw,Q 2.+ h.ac, bg ve,.;fing +1,,J. u k v & , H, wAoL411 nof acca.ss M A u<% ' Ma- yI, pe.pamla1, P W codru auhm.hQoin H,e /ku
;r u ih areael.p.,;),w. p/m g /,a,, ,a., ,y, y <.,,' 2 yashd PLANT SYSTEMS X 'Y #
- peut.us l
ACTION: (Continued) G :.. -.:t? ; i+"'a
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uu vrcanu .-- . .... SURVEILLANCE REQUIREMENTS
- to 4.7.h.1/ The fire suppression water system shall be demonstrated OPERABLE
. " ' c::t ;;;; p;r ' d;,: ', . ...f,...,..........-... a upp b ve%me
- 4. g. At least once per 31 days on a STAGGERED TEST BASIS by starting each electric motor driven pump and operating it for at least 15 minutes on recirculation f1ow. 33 ,, ,,,,,,; g(e ja,; plad eye d en
- b. /. At least once per 31 days by verifying (that each valve (manual, power operated or automatic) in the flow pathlis in its correct pos,ition.
E
- g. At 1 ast nce per 6 mo l
.titirilho toeg toversCy leullacksge.
e $ths by performance of a system flushJea[M eu/r/24 JL g. At least once per 12 months by cycling each testable valve in the flow path through at least one complete cycle of full travel. [. f. At least once per 18 months by performing a system functional test which includes simulated-automatic actuation of the system throughout its operating sequence, and:
- 1. Verifying that each automatic valve in the flow path actuates to its correct position, l 2. Verifying that each pump develops at least (2500) gpm at a system t_2 ' G:C . m presswee of nT rsy ,
- 3. Cycling each valve in the flow path that is not testable during
. plant operation through at least one complete cycle of full travel, and ( l
- 4. Verifying that each fire suppression pump starts (sequentially) l to maintain the fire suppression water system pressure greater than or equal to 1:ts' psig.
CI { g. At least once per 3 years by performing a flow test of the system in accordance with ^. w . :, ::ti.. of the Fire Protection Handbook, gsa ->Me Edition, published by the National Fire Protection Association. ch ph ef,5 eden H. , Pa,.4 8 W-STS _ 3/4 7-30 MAY 15 580
PLANT SYSTEMS SURVEILLANCE REQUIREMENTS (Continued) 4.7. 1.1.2 The fire pump diesel engine shall be demonstrated OPERABLE:
- a. t least once per 31 days by verifying:
- 1. The fuel storage tank contains at least gallons f fuel, a
- 2. The d sel starts from ambient conditions and erates for at least 3 inutes on recirculation flow. .
- b. At least once pe 92 days by verifying that a ample of diesel fuel from the fuel stor e tank, obtained in acc ance with ASTM-D270-65, is within the accept le limits specified
- Table 1 of ASTM D975-74 when checked for visco ty, water and se ment.
- c. At least once per 18 month during utdown, by subjecting the diesel to an inspection in accordan with rocedures prepared in conjunction with its manufacturer's rec nd ions for the class of service.
4.7.11.1.3 The fire pump diesel starti 2 volt battery bank and charger shall be demonstrated OPERABLE: 1
- a. At least once per 7 days y verifying t:
- 1. The electrolyte vel of each battery 's above the plates, and
- 2. The overall ttery voltage is greater th or equal to 24 volts.
- b. At icast once r 92 days by verifying that the s cific gravity is appropriate r continued service of the battery.
- c. At least . ce per 18 months by verifying that:
- 1. T e batteries, cell plates and battery racks show no visual ndication of physical damage or abnormal deteriorati , and
. The battery-to-battery and terminal connections are clea tight, free of corrosion and coated with anti-corrosion a terial.
l I i 1 W-STS 3/4 7-31 MAY 151980
PLANT SYSTEMS SPRAY AND/0R SPRINKLER SYSTEMS , LIMITING CONDITION FOR OPERATION to lisW inTaW 3.M
- 3. 7. M. 2 The T.' _ ' ; spray and/or sprinkler systemsjshall be OPERABLE:
roien+ son.n % + - t: :+-s hu nama and locatinn i
.G -
APPLICABILITY: Whenever equipment protected by the spray / sprinkler system is required to be OPERA 8LE. ACTION:
- a. With one or more of the above required spray and/or sprinkler systems inoperable, within one hour establish a continuous fire watch with backup fire suppression equipment for those areas in which redundant systems or components could be damaged; for other areas, establish a hourly fire watch patrol. t : ' : -- * ' - e " e ' - 'a * 'E -' &
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- t' - -- :; : -t :;_. .. ., ;:::--
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- b. The provisions of Specifications 3.0.3 and 3.0.4 are not applicable.
SURVEILLANCE REQUIREMENTS 10 4.7.X.2 Each of the above required spray and/or sprinkler systems shall be demonstrated OPERABLE: g ;, u us, n h ing 9 4.f ,re d a 1
- a. At least once per 31 days by verifying that each valve (manual, power operated, or automatic) in the flow pat is in its correct position.
- c. le. At least once per 12 months by cycling each testable valve in the flow path through at least one complete cycle of full travel.
L, %iq gach psb 594TDowd excubag8 bourr by ver;$,hg heaef ,(yg kiwd, fower ofendeJ,oyWh\ h 8< Auf dA k*ld*N kring planf eferahn it in ik oreeef pos-iAn a lers ds fosiSon cuo.1 \ verikkel w; Min fha frenbus El dys g-STS 3/4 7-32 NOV 2 01980 l l l
PLANT SYSTEMS SURVEILLANCE REQUIREMENTS (Continued) dh. At least on:e per 18 months:
- 1. By performing a system functional test which includes simulated automatic actuation of the system, and:
a) Verifying that the automatic valves in the flow path actuate to their correct positions on a Fire bebdien test signal, and b) Cycling each valve in the flow path that is not testable during plant operation through at least one complete cycle of full travel.
- 2. By a visual inspection of the dry pipe spray and sprinkler headers to verify their integrity, and
- 3. By a visual inspection of each nozzle's spray area to verify the spray pattern is not obstructed.
g g hL At least once per 3 years by performing an air flow test through f each open head spray / sprinkler header and verifying each open head spray / sprinkler nozzle is unobstructed. 1 l l l l l W-STS 3/4 7-33 'NOV 2 01980
i
\
b TABLE 3.7-4 r l ; SPRAY AND/0R SPRINKLER SYSTEMS Elevation 522 + 0 ft. - Auxiliary Building Room No. Ecuipment 100 RHR & Containment Spray Room & Sump Pumps 101 Corridor 104 RHR Pump 1B 105 RHR Pump 1A 106 Corridor 4 ,, - - ,, 1*4* """ ~ r ^l 111 Corridor 112 Corridor Elevation 543 + 0 ft. - Auxiliary Building 230 Cent. Chg. Pump 1A 231 Cent. Chg. Pump 1B M ....:.3
^
...,"1 M .m.... ..3 . , _ _-
'"9b 250 Unit 1 Aux. Feedwater Pump Room ees- .....;.,.. . . _ _ _ Elevation 560 + 0 ft. - Auxiliary Building 300 Component Cooling Pumps lAl, lA2, 1B1 & 182 5' . ..... sii ' . . . . nwA. . j _,'_ ig
.hes-- -f^----- ' :::' ., " ..,. :f.;, ':, _^2: :::
Standby Shutdown Facility Diesel Generator Reactor Buildings Annulus Pipe Chase Reactor Coolant Pumps CATAWSA - UNIT 1 3/4 7-55 Rev. 2 n _. , _ . E m __ : r u-- e
PLANT SYSTEMS r; a Cg SYSTEMS LIMITING CONDITION FOR OPERATION 10 3.7.yf.3 The following high pressure and low pressure CO 2 systems shall be OPERABLE. g { " :- ' 1 : : .-. f : - ' + - t : 'fr_ 2 'y - --d w-t ' _ . ; - A q, L.ou Presset Cds,fysh .-biasel gence4. der coenu.
% h. R;p hssee (A spb - A=r li.ry Feedec game ceoms. .
APPLICABILITY: Whenever equipment protected by the CO 2 systems is required to be OPERABLE. ACTION:
- a. With one or more of the above required C07 systems inoperable, within one hour establish a continuous fire watch with Dackup fire suppression equipment for those areas in which redundant systems or components could be damaged; for other areas, establish an hourly fire watch patrol. Restore the system to OPERABLE status within 14 days or, in lieu of any other report required by Specification 6.9.1, prepare and submit a Special Report to the Commission pursuant 'D'3) to Specification 6.9.2 within the next 30 days outlining the action taken, the cause of the inoperability and the plans and schedule for restoring the system to OPERABLE status.
I i b. The provisions of Specifications 3.0.3 and 3.0.4 are not applicable. SURVEILLANCE REOUIREMENTS 10 l 4.7.)f.3.1 Each of the above required CD, systems shall be demonstrated OPERABLE at least once per 31 days by verTfying, that each valve (manual, power operated or automatic) in the flow path is in its correct position. to
- 4. 7.)f. 3. 2 Each of the above required low pressure CO systems shall be demonstrated OPERABLE: 2
- a. At least once per 7 days by verifying the CO storage tank level to be greater than - '
2
- 1. n. - ' ,and
@AC..Atleastonceper18monthsbyverifying:8N9 l MFi ,o f b. . . _ _ _ _h .
inchMa
- 1. The systemg '-- g -f associated ventilation dampers and-deos-f:::
.: --__ .........___ actuatermanually and automatically, upon receipt of a simulated actuation signal, and
.-s _ , , _
hoy8
._ 2 _ ; ;,,_,--_-
- b. g least once per W-STS 12 moniks3 y
b verik h strfen bd bchr3 ed l ~ MS*ciabd %"i f**4 L e k a/4 7-34 MAY 151o80 gc y ety. l
PLANT SYSTEMS SURVEILLANCE REOUIREMENTS (Continued) 4.7.k.3.3 Each of the above required high pressure CO systems shall be demonstrated OPERABLE: 2 weihd"*, c
- a. At least once per 6 months by verifying thejC0 2 storage
- g. lindee :....
to be at least 90% of full charge weight l C. )(. Atleastonceper18monthsbyp I h h erifying the system, including associated ventilation dampers and -
! fire door release mechanisms, actuates manually and automatically, i, upon receipt of a simulated actuation signal, and i o--+---- : ? ; ' ' .. t . /. . . . .
- 3. . .. ... _.. -- _ ' -- +a
;;; _. . ._ --"y.
fh hech 6nce $ WANT VLtI l'n hegy$hoog h L M toer ud ass.c.: dad ap,pasad Auehan (rapcly. l l l l g-STS 3/4 7-35 MAY 151980
)\ ANT SYSTEMS HALON\6YSTEMS LIMITIN DITION FOR OPERATION s ,
3.7.11.4 The llowing Halon systems shall be OPERABLE.
- a. (Plant pendent - to be listed by name and loca on.)
b. c. APPLICABILITY: Whenever uipment prote'cted by the alon system is required to be OPERABLE. ACTION:
- a. With one or more of t above requir Halon systems inoperable, within 1 hour establis a continuou fire watch with backup fire suppression equipment fo those ar as in which redundant systems or components could be damag ; for ther areas, establish an hourly fire watch patrol. Restor the ystem to OPERABLE status within 14 days or, in lieu of any h r report required by Specifica-tion 6.9.1, prepare and subm a Special Report to the Commission pursuant to Specification 6 . within the next 30 days outlining the action taken, the caus of he inoperability and the plans and schedule for restoring t syst to OPERABLE status.
- b. The provisions of Spec' a ications 3 0.3 and 3.0.4 are not applicable.
SURVEILLANCE REOUIREMENTS
/ \
1
- 7.11.4 Each of the abo required Halon systems shall be demonstrated i OPERABLE:
l
- a. At least one per 31 days by verifying tha each valve (manual, power oper ed, or automatic) in the flow pa h is in its correct position.
- b. At lea once per 6 months by verifying Halon s rage tank weight to be t least 95% of full charge weight (or lev ) and pressure to be at 1 ast 90% of full charge pressure.
- c. A least once per 18 months by:
.. Verifying the system, including associated ventil tion dampers and fire door release mechanisms, actuates manual and auto-l matically, upon receipt of a simulated actuation si nal, and
, 2. Performance of a flow test through headers and nozzi to l assure no blockage. W-STS 3/4 7-36 .NOV 2 0 ;ega (
PLANT SYSTEMS FIRE HOSE STATIONS LIMITING CONDITION FOR OPERATION to . " 3.7. Q The fire hose stations shown in Table 3.7-5 shall be OPERABLE. APPLICABILITY: Whenever equipment in the areas protected by the fire hose stations is required to be OPERABLE. ACTION: 7^
- a. 'it? : : ^- -^ : :f th: -" '^"^ "+=+inne chaw" 4" ' '-5
. .. gm. 2:, ;_t: _ . . ^dd't #
-.^l
..- --t;;;;g ;-- r;) <.- .,- nerery_: 5;;; ;;-ti;_
,..._I: ' 21 2 't; - ',--^ 1: II:
- +w:- g__. ze m 4----
m w m .m : 3,; < ,, ':-- 4,
+ u m.4m .y --- : ;<
+u r 7 3 3 ; ; ,,,; , _ , ; ,,, , ,, g ,,_ , ,,
<4.-
-.7---- - ;
+wm
, -- . 3 7 _;7-55 g r: g5::^+"^ . . --. r--+. v.. wv e .anLE > w us m en u. i, ww..,
14 :;_.. J L., ;::'" --+4-^ co'. ---n=" and e "* 4 +
... .. : .~ ; . . . r . ~ . . . t : I;::i'i::ti .- C.E '
a ?;:.. .k e v . . . . : . t': ..r. :: J.,. . ti' ' ; t': --+'-- t:L:.., *... ..... :' tt: _ p--
#-^
- :b i' i t; , -d
- " :2... . .'.. ...,;..'.; th. _t:t':- t:
94&Eii W eee4ws
- b. The provisions of Specifications 3.0.3 and 3.0.4 are not applicable.
SURVEILLANCE REOUIREMENTS 4.7. Each of the fire hose stations shown in Table 3.7-5 shall be l demonstrated OPERABLE:
- a. At least once per 31 days by a visual inspection of the fire hose stations accessible during plant operations to assure all required equipment is at the station.
- b. At least once per 18 months by:
- 1. Visual inspection of the stations not accessible during plant operations to assure all required equipment is at the station,
- 2. Removing the hose for inspection and re-racking, and
- 3. Inspecting all gaskets and replacing any degraded gaskets in the couplings.
- c. At least once per 3 years by:
- 1. Partially opening each hose station valve to verify valve OPERABILITY and no flow blockage.
Zoo
- 2. Conducting a hose hydrostatic test at a pressure of 46G psig or at least 50 psig above maximum fire main operating pressure, whichever is greater.
l l \ l \
-W-STS 3/4 7-37 4
'NOV 2 1981 1 l l
i I TABLE 3. 5 FI STATIONS LOCATION
- EVATION HOSE RACK #
msELT OJS T48tr 3.7 4 l l l l l l l l
- List all Fire Hose Stations required to ensure the OPERABILITY of safety-related equipment.
l l M-STS 3/4 7-38 WOV ~2 i) '030 l
i 1 DUKE PO.ER COMPANY , Fem 00184 16-81:
- l !: 1 i
ii Dev./ Station Unit File No. Subject
;i l By Date I l
i
- i. l
!I ;1 Sheet Nc _of Problem No. Checked By Date ';
ij i D ' I -(vr 3.h, l 0. Li ' ' ' ' if , i i * ' ' l!
, t !b i 1 !l , i i <
l - ! i i
- i ti ll
- a. With one or more of the fire hose stations shown in Table 3.7-5 -
h inoperable, provide gated wye (s) on the nearest OPERABLE hose ,', l station (s). One outlet of the wye shall be connected to the ll: -- standard length of hose provided for the hose station. The second ;; i l outlet of the wye shall be connected to a length of hose sufficient if to provide coverage for the area left unprotected by the inoperable - .H___ hose station. Where it can be demonstrated that the physical ~~ ll routing cf the fire hose would result in a recognizable hazard to ' Il operating technicians, plant equipment, or the hose itself, the fire ,_ hose shall be stored in a roll at the outlet of the OPERABLE hose .!
- ! ; station. Signs shall be mountet above the gated wye (s) to identify .
the proper hose to use. The above action shall be accomplished t i ?j ,: ! within 1 hour if the inoperable fire hose is the primary means of , , h ll l fire suppression; otherwise route the additional hose within ' ' ' ll
- , i 24 hours. j j ; j i
i:
- l
);j; i t ,
! ! ! i i I ! I i i I L
g i , i , i ; i ; i ; i i
- l i h;! l j ; ! : I ! l , ! ! i i i j '
i ; i !q pil l ; . i i i ! l l l ! i Ii! ! I ! I i di .
- i ; i I
- I ; ! ! ! i I i i i i!,1 1 . 4 i ! !
1 > I i i ! i l ! ! I I l I! i
, I i ! !
4 , i - e
' + l l ;
I ' l { i l I l 5 e ; ' -
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j j j ; ! j ! , l ! i l l i l, i 1 , I l
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i i ' ! ' ! I i i ' ' ' I i i I ' j lll i l ! ! l i I ! l l . l , j l l ! l ; l
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l l l l l i ' l o! l i ,i i 1 l
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I l l l l ! { ! ! j ! ! I I l'
PLANT SYSTEMS TABLE 3.7-5 l FIRE HOSE STATIONS LOCATION ELEVATION HOSE RACK #
-Auxiliary Building-59, FF 522+0 1RF235 55, FF 522+0 1RF248 63-64, KK 543+0 1RF210 63, MM 543+0 1RF211 60, MM 543+0 1RF212 58, PP 543+0 1RF218
- 0, :: 4d454h ;"':::
66 :~., ~~ 20 1NM>m> 11 ;;7
- , .. 644 4 6 57, JJ 543+0 1RF242 54-55, GG 543+0 1RF249 57,FF 543+0 1RF250 52-53, GG 543+0 1RF255 51, CC 543+0 1RF256 50-51, JJ-KK 543+0 1RF262 53, MM 543+0 1RF268 50-51, NN 543+0 1RF271 62, MM-NN 560+0 1RF203
- , ee .m 669=9 4W499-58, PP 560+0 """iRF219 56, NN 560+0 1RF220 00, un 466-4 IP'2'O 57, KK 560+0 1RF243 54-55, FF-GG 560+0 1RF251 51, KK 560+0 1RF263 52, MM-NN 560+0 1RF269
?,^ ss@=e l'c
- , : :: 669*6 4 %i46 0:, ::, &@&*e M 56, BB 644-4 554+o 1RF487
" , " S2., AA 88 560+0 1RF488 49, BB-CC 560+0 1RF489 6@ =69 469=9- iM4G6 45, BB 560+0 1RF997 69;=m 4999!* N st-et -:7 : - + wee +
C2, .. 45& 4 T' :5-44-58, PP 577+0 1RF221 639-9 ;"-_- n_ Z , 22 463=> 1aW@E. 56, KK 577+0 1RF244 54, GG 577+0 1RF252 52-53, KK 577+0 1RF258 51, KK 577+0 1RF264 51-52, NN 577+0 1RF272 CATAWBA - UNIT 1 3/4 7-59 Rev. 2
d PLANT SYSTEMS TABLE 3.7-5 l FIRE HOSE STATIONS LOCATION ELEVATION HOSE RACX# , 1 56, PP 577+0 1RF278 l 6tMfe 4Eiin+ M p ild> C', Z :' @MP N
-':, : si3E4 J.iMiAlla.
C , mm .EEiieG. N
. . 49, BB-CC 577+0 1RF490 l 45, BB 577+0 1RF491 55, 00 Gilii=4= SN+ o 1RF492 54, AA 5O 574+o 1RF493 c', n siiE4 MEGG4 51, AA 577+0 1RF998 "2,- .siM=4 W P999=
57, MM 594+0 1RF222 Gay-e* 5%=4 ' P :'_ -
~7, 7 4M4 WEGAE-57, EE 594+0 1RF253 51, JJ 594+0 1RF259 53, NN 594+0 1RF275 44- 466- & ' ': '
50, BB 594+0 1RF985
-ruel Pools-5.i C , '~ .. 4Ap=6- '
. P:::
i 51, KK ise4=4 I.oS+ io 1RF265 e 48, TT @ 6%=@= Gos c io 1RF2/6
=>_ - ;; . ~ ::. ':T 5b-b1'MM , 53" 3 bass.io iRF533 f:, "" 49e=e _"'::
5/ #p=, MM 631+6 1RF495 -
,,__,,____..,o,
;- ;r ___
-n e,n u, . -- c,_ ,- g
_m, , , , - - . _ . . , , , , .. ,, _--m_- .- ,-,
,,,,. ~~~~ .;' ;;,, ;;;. .
_; : W.:!-
~~~ '
- . ~. i. " --- " ' '. ". . ~ :,' _: :_ ,, ;_ . . : , . :; :::
- s ..- w Nuclear Service Water Pump Structure East Wo.A secf/.o 4G4-6 Geo +e 1RF939 l West # seeh.o 4F-=s= q oo , o 1RF940 l
CATAWBA - UNIT 1 3/4 7-60 Rev. 2
?
l
\
Ph4TSYSTEMS YARD RE HYORANTS AND HYDRANT HOSE HOUSES LIMITING NDITION FOR OPERATION 3.7.11.6 The ard fire hydrants and associated hydrant hose no ses shown in Table 3.7-6 sha be OPERABLE. APPLICABILITY: Wh ever equipment in the areas protected the yard fire hyorants is require o be OPERABLE. ACTION: ]
- a. With one or more f the yard fire hydrant or associated hydrant hose houses shown 'n Table 3.7-6 inoper e, within i hour have sufficient addition lengths of 2 1/2 nch diameter hose located in an adjacent OPERABLE drant hose hou to provide service to the unprotected area (s) i the inoperabl fire hydrant or associated hydrant hose house is t primary ans of fire suppression; otherwise, provide the a itional ose within 24 hours. Restore the hydrant or hose house to RAB status within 14 days or, in lieu of any other report require b Specification 6.9.1, prepare and submit a Special Report to t Commission pursuant to Specifica-tion 6.9.2 within the next ays outlining the action taken, the cause of the inoperability and he plans and schedule for restoring the hydrant or hose house o OPE BLE status.
i b. The provisions of Speci 1 cations 3. 3 and 3.0.4 are not applicable. I SURVEILLANCE REQUIREMENTS , , ) 4.7.11.6 Each of the yard ire hydrants and assoc 1 ted hydrant hose hauses shown in Table 3.7-6 shal be demonstrated OPERABLE:
.a. At least once per 31 days by visual inspecti of the hydrant hose house to ass re all required equipment is at e hose house.
- b. At least o e per 6 months (once during March, ril, or May and once duri g September, October, or November) by 'sually inspecting each yar fire hydrant and verifying that the hyd nt barrel is dry and th the hydrant is not damaged.
- c. At le st once per 12 months by: ,
- 1. Conducting a hose hydrostatic test at a pressure f 150 psig or at least 50 psig above maximum fire main operating ressure, whichever is greater.
. Inspecting all the gaskets and replacing any degrade gaskets in the co'uplings.
- 3. Performing a flow check of each hydrant to verify its OPERABILITY.
W-STS-3/4 7-39 , . 'NOV 2 1981
TA .7-6 YARD FIRE HYDRANTS A SO ED HYDRANT HOSE HOUSES LOCATION
- HYORANT NUMBER i
I l l l 1 i List all Yard Fire Hydrants and Hydran: 'r ;se Houses required to ensure the l OPERABILITY of safety-related equipment. L W-STS 3/4 7-40 NOV 2 01980
PLANT SYSTEMS u SAKWK PeperMToons 3/4.7. FIRE MMbWM@ee(+ LIMITING CONDITION FOR OPERATION 3.7. All fire (walls, floor / ceilings, cable tray enclosures and other fire barriers) separating safety related fire areas or separating
- portions of redundant systems important to safe shutdown within a fire area and all sealing devices in fire rated assembly penetrations (fire doors, fire windows, fire dampers, cable.pt piping penetration seek and ventilation Mpanefnds a seals) shall be OPERABLE.
I APPLICABILITY: At all times. I ACTION: With one or more of the above requiredWee:v-
- a. fire --t-d .peoefMens x;..b1f:: and/or sealing devices inoperable, within one hour either establish a continuous fire watch on at least one side of the affected assembly, ;
or verify the OPERABILITY of fire detectors on at least one side of l the inoperable assembly and establish an hourly fire watch patrol.
" x t;.. tr.. :...;:-d'r " . .;t-d - -- ; .. .: :n? ' ;; '-"4 ~ t:
2nenao, e + .t. - 4ue-7 _, , g. , ,,, ; ; ,,, ,;,,,,_,,,,, ;7 x ;f :f h ?- i.. iun v. .1, ;r.,... ...u . .L... : ; . :; x ' - 1 ^..,~ . - a + u c - <ca nn 7.. : ur,; ;. ;r ,;;;,,,,; ,, ;,;,; tt,i; tr.; 7. ;t 2 d;,, ..t1'-4 ; +" t -: . . . .a.. . , M., . . . ,. ,, . ons n.vy. . . 1. T : . m 7;^..J .... Li, ;c.d/: :. 1 : .,3 .. . : . . . . t ; .. ,,1.. . . - " " ' ' " '
.. .u o m m.;, ... ...;o.w u...
- t r'.; ti.. '-:. . Ci Gi L --
Ste%es
- b. The provisions of Specifications 3.0.3 and 3.0.4 are not applicable.
SURVEILLANCE REQUIREMENTS tl wre:.c
- 4. 7. W.1 At least once per 18 months the above required firected 2::::tif:0
.and-penetration sealing devices shall be verified OPERABLE byrpec4-ag avisuoj inspekoa eh
- a. "- '- ' ; - "'-" ' ' ;;n.:... JThe exposed surfaces of each fire rated assemblies.
- b. "--# r" ; ; .t. .1 !...r. :... T6ach fire window / fire damper /
and assoc'ated hardware.
- c. ";r'- .., . .:...: ' ,___-_- .. M least 10 percent of each type of sealed penetration. If apparent changes in appearance or abnormal degradations are found, a visual inspection of an additional 10 percent of each type of sealed penetration shall be made. This inspection process shall continue until a 10 percent sample with no apparent chan es in appearance or abnormal degradation is found.5@
shnu ke seAe s4 M eask ene4nck.. g s ( vrtl 6 snsgec4./ every f5 yesy.g,
'N OV '> 1M1 W-STS 3/4 7-41
PLANT SYSTEMS SURVEILLANCE REQUIREMENTS (Continued) ll 4.7.M.2 Each of the above required fire doors shall be verified OPERABLE by inspecting the automatic hold-open, release and closing mechanism and latches at least once per 6 months, and by verifying: Tkd eukat.eksikaa wha skeks4gevtsia is el sel
- a. A - - ;i;!.c. :f :::.'. c'-- ' -- ';.. at least once per 24 hours,
- b. That doors with automatic hold-open and relea:e mechanisms are free of obstructions at least once per 24 hoursanA pe4cq abcle.n.14cs+ M Vot ow eac 18 me dhs. a desed bf T:. , .:::... J each locked closed fire decr at 3 least once per 7 days, Q 4 3 . u k e 6 . h lly s y eevis l M re J .
- d. The OPERABILITY of the fire door supervision systengby performing a TRIP ACTUATING DEVICE OPERATIONAL TEST at least once per 31 days.
l l I i W-STS 3/4 7-42 'fiOV 2 1991
1 PLANT SYSTEMS tt-3/A.7.16 AREA TEMPERATURE MONITORING LIMITING CONDITION FOR OPERATION tt- b 3.7.16 The temperature of each area shown in Table 3.7-I shall be maintained within the limits indicated in Table 3.7-T. le APPLICABILITY: Whenever the equipment in an affected area is required to be OPERABLE. ACTION: With one or more areas exceeding the temperature limit (s) shown in Table 3.7-1:
* (,
- a. For more than eight hours, prepare and submit a Special Report to the Commission pursuant to Specification 6.9.2 within the next 30 days providing a record of the amount by which and the cumulative time the temperature in the affected area exceeded its limit and an analysis to demonstrate the continued OPERABILITY of the affected equipment.
- b. By more than 30*F, in addition to the Special Report required above, within 4 hours either restore the area to within its temperature limit or declare the equipment in the affected area inoperable.
SURVEILLANCE REQUIREMENTS 12- 'a 4.7.14 The temperature in each of the areas shown in Table 3.7-h shall be determined to be within its limit at least once per 24 hours. W _-STS 3/4 7-43 "V2 198*
b TABLE 3.7-1 AREA TEMPERATURE MONITORING AREA TEMPERATURE LIMIT (*F)
- 1. .
2.
- 3. TO .
9 t LJu 4. 5. 1 I l
'f-STS 3/4 7-44 .y .3 gegg l
l I i
EW PLANT SYSTEMS 3 /.t . 7.13 GRCUNOWATER LEVEL LIMITING CONDITION FOR OPERATION 1 3.7.13 The groundwater level shall be maintained at or below the top of the I adjacent floor slabs of the Reactor Containment Building and the Auxiliary Building. APPLICABILITY: At all times. I ACTION:
- a. With the groundwater level above the top of the adjacent floor slab by 1 5.0 feet, reduce the groundwater level to or below the top of the affected adjacent floor slab within 7 days or be in at least j HOT STANDBY within the next 6 hours and in COLD SHUTDOWN within the following 30 hours. 1
- b. With the groundwater level above the top of the adjacent floor slab by > 5.0 feet but < 15.0 feet, reduce the groundwater level to i 5.0 feet above the top of the affected adjacent floor slab i within 24 hours and to or below the top of the affected adjacent '
floor slab within 7 days of initially exceeding the above limits or be in at least HOT STANDBY within the next 6 hours and in COLD - SHUTDOWN within the following 30 hours.
- c. With the groundwater level above the top of the adjacent floor slab by > 15.0 feet, be in at least HOT STANDBY within 6 hours and in COLD SHUTDOWN within the next 30 hours. Perform an engineering evaluation to determine the effects of this high groundwater level on the affected building (s) and submit the results of this evalua-I tion and any corrective action determined necessary to the Commission as a Special Report pursuant to Specification 6.9.2 l
prior to increasing T,yg above 200 F.
- d. Z ... ... 3....~ .... l . . . . . . " . 14 : ' t ' : -1"^+-- ;'.i b, ; ^. : ..,-............T L. .' tN; ;-- - " +- '- 9
-- ::........ ..~.... . ., -'---- "~~" -
g * ;;;t
- : _2 . . . .. .
.m.. e6 . con mm , . , . . . - - _ _ hf the rate of rise j of the groundwater level is > 0.3 feet per hour, determine the rate i
of rise at least once per 30 minutes. If the rate of rise exceeds 0.5 feet per hour for more than one hour, be in at least HOT STANDBY within one hour and in COLD SHUTDOWN within the following 30 hours. If the rate of rise is < 0.5 feet per hour, comply with the require-ments of ACTIONS a, b and c above. Dete. mine Oc eafe d rise cr[groundc dhe. chen 4, hve[ u=Aes % % of AeA- stal, CATAWBA - UNIT 1 3/4 7-65
PLANT SYSTEMS SURVEILLANCE REQUIREMENTS 4.7.13 The groundwater level shall be determined at the following frequencies by monitoring the water level and by verifying the absence of alarm in the 6 groundwater monitor wells as shown in FSAR Figure 2.4.13-14 installed around the perimeter of the Unit 1 Reactor and Auxiliary Building.
- a. At least once per 7 days when the groundwater level is at or below the top of the adjacent floor. slab, l
- b. At least once per 24 hours when the grou'ndwater level is above but
< 2.0 feet above the top of the adjacent floor slab.
l I CATAWBA - UNIT 1 3/4 7-66 l l
3/4.8 ELECTRICAL POWER SYSTEMS 3/4.8.1 A.C. SOURCES OPERATING LIMITING CONDITION FOR OPERATION 3.8.1.1 As a minimum, the following A.C. electrical power sources shall be OPERABLE:
- a. Two physically independent circuits between the offsite transmission network and the onsite -" " " ~l'- system, and assu+wl Au;wy Vower
- b. Two separate and independent diesel generators, each with:
- 1. f4 Separate day cr.d engin; :,; .LJ fxi tankt containing a minimum volume of $33, gallons of fuel,
- 2. A separate fuel storage system containing a minimum volume of 32,or,s gallons of fuel, and
- 3. A separate fuel transfer pump. val *.
APPLICABILITY: MODES 1, 2, 3, and 4. ACTION: ,
- a. With either an offsite circuit or diesel generator of the above required A.C. electrical power sources inoperable, demonstrate the OPERABILITY of the remaining A.C. sources by performing Surveillance Requirements 4.8.1.1.1.a and 4.8.1.1.2.a.4 within 1 hour and at least once per 8 hours thereafter; restore at least two offsite circuits and two diesel generators to OPERABLE status within 72 hours or be in at least HOT STANDBY within the next 6 hours and in COLD SHUTDOWN within the following 30 hours.
- b. With one offsite circuit and one diesel generator of the above required A.C. electrical power sources inoperable, demonstrate the OPERABILITY of the remaining A.C. sources by performing Surveillance Requirements 4.8.1.1.1.a and 4.8.1.1.2.n.4 within 1 hour and at least once per 8 hours thereafter; restore at least one of the inoperable sources to OPERABLE status within 12 hours or be in at least HOT STANDBY within the next 6 hours and in COLD SHUTDOWN within the following 30 hours. Restore at least two offsite circuits and two diesel generators to OPERABLE status within 72 hours from the time of initial loss or be in at least HOT STANDBY within the next 6 hours and in COLD SHUTDOWN within the following 30 hours.
Aema
- c. With one diesel generator inoperable in addition toga or b above, verify that:
(1) all required systems, subsystems, trains, components and devi::es that depend on the remaining CPERABLE diesel generator as a source of emergency power are also OPERABLE, and
-W-STS 3/4 8-1 JUL 2 71981
ELECTRICAL POWER SYSTEMS ACTION: (Continued) p 900f**8> uQ skom f(**"" 1 (2) When in MODE 1, 2, or 3,7the steam-driven auxiliary feed, pump is OPERABLE. If these conditions are not satisfied within 2 hours be in at least HOT STANDBY within the next 6 hours and in COLD SHUTDOWN within the following 30 hours.
- d. With two of the above required offsite A.C. circuits inoperable, l demonstrate the OPERABILITY of two diesel generators by performing Surveillance Requirement 4.8.1.1.2.a.4 within 1 hour and at least once per 8 hours thereafter, unless the diesel generators are already operating; restore at least one of the inoperable offsite sources to OPERABLE status within 24 hours or be in at least HOT STANDBY within the next 6 hours. With only one offsite source restored, restore at least two offsite circuits to OPERABLE status within 72 hours from time of initial loss or be in at least HOT STANDBY within the rtxt 6 hours and in COLD SHUTDOWN within the following 30 hours.
- e. With two of the above required diesel generators inoperable, demonstrate the OPERABILITY of two offsite A.C. circuits by perform-ing Surveillance Requirement 4.8.1.1.1.a within 1 hour and at least once per 8 hours thereafter; restore at least one of the inoperable diesel generators to OPERABLE status within 2 hours or be in at least HOT STANDBY within the next 6 hours and in COLD SHUTDOWN within the following 30 hours. Restore at least two diesel gener-ators to OPERABLE status within 72 hours from time of initial loss or be in least HOT STANDBY within the next 6 hours and in COLD SHUTDOWN within the following 30 hours.
SURVEILLANCE REQUIREMENTS 4.8.1.1.1 Each of the above required independent circuits between the offsite transmission network and the onsite.^' _ ' f;tc ii -ti system shall be: Essch( Awu-(suy few:er
- a. Determined OPERABLE at least once per 7 days by verifying correct breaker alignments, indicated power availability, and
- b. Demonstrated OPERABLE at least once per 18 months during shutdown by transferring (manually and autcmatically) unit power supply from the normal circuit to the alternate circuit.
4.8.1.1.2 Each diesel generator shall be demonstrated OPERABLE:
- a. In accordance with the frequency specified in Table 4.8-1 on a STAGGERED TEST BASIS by:
- 1. Verifying the fuel level in the day ...J ... ..~ .. - ' n' tank, W-STS 3/4 8-2 JUL 2 71931
ELECTRICAL POWER SYSTEMS SURVEILLANCE REOUIREMENTS (Continued)
- 2. Verifying the fuel level in the fuel storage tank, val u can %< ndel Mtiwlud t.%edeur[wered
- 3. Verifying the fuel transferg _. ,..^._ y: _ xd ": :';. . ' ..: from the storage system to the day --d W~ - - ""0" 'h k'
.67
- 4. Verifying the' dieselstartsfromambientcondition)andaccelerates to at least40699 rpm in less than or equal to 4M9 seconds.
The generator voltage and frequency shall be (4160) + (420) volts 5? W + (1.2) Hz within 4Hf seconds after the start signal. The dieseT generator shall beistarted for this test by using cae of the following signals: W a) Manual. b) Simulated loss of offsite power by itself. c) Simulated loss of offsite power in conjunction with an ESF actuation test signal. d) An ESF actuation test signal by itself.
-?oco l<ua
- 5. Verifying the generator is synchronized, loaded to greater than or equal to ( ...ti...~ . .:.6 in less than or equal to (60) seconds, and operates _.;. l...J . xt r th: x qxi t.
6......m~ . .-: ;) for at least 60 minutes,
- 6. Verifying the diesel generator is aligned to provide standby power to the associated emergency busses.
- b. At least once per 31 days and after each operation of the diesel where the period of operation was greater than or equal to 1 hour by chx: ' ; #- --d removing accumulated water from the day :-f - ;' . -
, ~-. . .; d 'xl tank /. ,
- c. t once per 92 days and from new fuel oil prior to additio the stora, b verifying that a sample obtained in a ance with ASTM-D270-19 o ter and sediment content *
- ess than or NggT--> equal to .05 volume percent an ematic y @ 40 C of greater than or equal to 1.9 ual to 4.1 when tested in acco M-D975-77, and an im level of less mg. of insolubles per 100 ml. when tested in a
. ASTM-D2274-70.
- d. At least once per 18 months, during shutdown, by:
- 1. Subjecting the diesel to an inspection in accordance with procedures prepared in conjunction with its manufacturer's recommendations for this class of standby service, W-STS 3/4 8-3 .HOV 2 1981
_ - - - - - - - - - - - - - - - - - J
ELECTRICAL POWER SYSTEMS SURVEILLANCE REQUIREMENTS (Continued) 825
- 2. VerifyingthegeneratorTapabilitytorejectaloadofgreater than or equal to -(' _. _1 :' ;' . . ... ...~, L_l; kw while maintaining voltage at (4160) 1 (420) volts and frequency at (60) 1 (1.2) Hz.; L. ;.t.. .
.m_' L 7 2 . T U . J .' f e . . . .. .
m . .. 7 l j.- :)..:;;;f tr'; ::t;;f.t, .. 1%
..um 3..
- 3. Verifying the generator capability to reject a load of (;_..;......
......,) kw without tripping. The generator .. L , shall not exceed ( PC' .:'t; during and following the load rejection.
sooepm
- 4. Simulating a loss of offsite power by itself, and:
a) Verifying de-energization of the emergency busses and load shedding from the emergency busses. 11 b) Verifying theIdiesel starts on the auto-start signal, energizes thel emergency busses with permanently connected loads within 4 Wf seconds, energizes the auto-connected WM4 chutd;u- loads through the load sequencer and operates for koreater than or equal to 5 minutes while its generator is loaded with the ?hutd;r loads. After energization, the steady state voltage and frequency of the emergency busses shall be maintained at (4160) (420) volts and (60) 1 (1.2) Hz during this test.
- 5. Verifying that on an ESF actuation test' signal, without loss of offsite power, the diesel generator starts on the auto-start ,,
signal and operates on standby for greater than or equal to 5 minutes. The generator voltage and frequency shall be n j cA \eas4 (4160) .dmME) volts and (TC' _, 1 : Hz within M conds after the auto-start signal; the steady state generator voltage and frequency shall be main + lined within 6 during this test. into veh act 6011.':. h
- 6. Verifying that on c. simulated loss of the diesel generator, l with offsite power not available, the loads are shed from the
! emergency busses and that subsequent loading of the diesel generator is in accordance with design requirements. ! 7. Simulating a loss of offsite power in conjunction with an ESF l actuation test signal, and I a) Verifying de-energization of the emergency busses and load l shedding from the emergency busses. l l l W-STS 3/4 8-4 OCT 2 31980 l l
I DUKE PO'/.*ER COMPANY Form 00124 46 Bli l
- i. I;lt i
; Dev./ Station Unit File No. : '
Subject d, By Date ti !I i Sheet No of Problem No- Checked By Date N r* - D e N A (.l. 1 .C., i . : i ; l h l
~
h ,
- e o n acc d th A M- 70- 75, nd by verifying that the sample meets the followin ini
- requirements and is tested I ';
ll within the specified time lim t - . l al
! 1) As soon as sample is taken or prior to adding new fuel to l th the tests specified ; ,
l AST - 5- th e a e ha ,
- L a) A water and sediment content of less than or equal to '
ll - 0.05 volume percent, ; ,' j[" A kinertatic viscosity @ 40 C of greater than or equal'to !j' i ,O"' ,
- b) 1.9 centistokes, but less than or equal to 4.1 centistokes, '
,U
^
!j
[ and r I i i l l' + e 1
- ! ' ' c) A spegific gravity as specified by the inanufacturer @
^
60/60Fofgreaterthanorequaltog.83butlessthanor j l equal to 0.89 or an API gravity @ 60 F of greater than or ! i
- ' equal to 27 degrees but less than or equal to 39 degrees.
1
' ! , j i i
- 2) Within 7 days after obtaining the sample, verify an impurity ,
1: II ; level of less than 2 mg of insolubles per 100 m1 when tested in , { accordance with ASTM-D2274-70; and j l l l , f! l . ' 3) Within 14 days of obtaining the sample verify that the other ,
! ! H properties specified in Table 1 of ASTM-0975-77 and Regulatory 'l j j l l Guide 1.137, Revision 1, October 1979, Fosition 2.a. , are met l '
. l , ;
! when tested in accordance with ASTM-0975-77. ' > - i - , i i I i i l i , ,
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