Text

Control of Safety-Related Locked Valves
	ML20129H779
Person / Time
Site:	Vogtle
Issue date:	01/30/1988
From:	Kitchens W; GEORGIA POWER CO.
To:	;
Shared Package
ML082401288	List: 05000424/LER-1950-424, Forwards LER 50-424/1990-08S Re Unsecured Safeguards Info Due to Personnel Error; 05000424/LER-1990-007, S-00:on 900829,safeguards Info Container Observed Unsecured & Unattended in Document File Room.Caused by Safeguards Info Coordinator Failure to Secure Container Before Going to Lunch.Coordinator Counseled & Reprimanded; 05000424/LER-1990-008, S-00:on 901011,eleven Documents Found Unattended & Unsecured in Folder on Desk Being Moved.Caused by Cognitive Personnel Error.Safeguards Documents Returned to Their Approved Storage Container; ELV-01657, Forwards LER Re Personnel Error Leading to Unsecured Safeguards Info.Ler Withheld; ELV-02121, Forwards LER Re Personnel Error Leading to Unsecured Safeguards Info on 900829.Rept Withheld; ELV-03114, Forwards Responses to Sections I-IV of Additional Suppl to 910708 Suppl to 900911 Petition of M Hobby & Mosbaugh; ELV-03148, Requests That Supplemental Response to NRC Demand for Info Be Withheld from Placement in PDR Per 10CFR2.790 Until Decision Is Made in Matter & Responds to Questions Not Previously Addressed; IR 05000424/1990016; IR 05000425/1990027; ML20127B919; ML20127B929; ML20127B932; ML20127B936; ML20127B941; ML20127B945; ML20129H615; ML20129H661; ML20129H664; ML20129H678; ML20129H691; ML20129H696; ML20129H706; ML20129H722; ML20129H733; ML20129H737; ML20129H747; ML20129H753; ML20129H757; ML20129H766; ML20129H776; ML20129H779; ML20129H789; ML20129H792; ML20129H795; ML20129H805; ML20129H814; ML20129H820; ML20129H825; ML20129H830; ML20129H840; ML20129H846; ML20129H851; ML20129H856; ML20129H861; ML20129H872; ML20129H874; ML20129H879; ML20129H882; ML20129H888; ML20129H893; ... further results
References
	FOIA-95-211 10019-C, NUDOCS 9611040041
	Download: ML20129H779 (102)
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.ElffR9L OF SAF577 R5 EAT 50 DkkED VALVES i

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This procedure identifies the administrative controls l

for valves which are tant for safety Related systems that shall be sked in a specified position, j

2.0 gggggg 2.1 LOCKED VALVE A valve chose operation is prevented by a chain and padlook arrangement or other positive lookins device.

2.2 KEY CONTROL l

Keys required for p tation are controlled in accordsase with 000 a, lent Look And 5ey Contro.1".

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3.0 RESPONSIBILITIER p..'-

The Shift or' asintain administrative sentrol e toekina of Safety Rotated vos shift Bunervisor notently 8 staa leasats th h p theUnJ) shift parvisera.d n

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The status of toeked valves shalt not be changed l

without prior autherisation by the shift supervisor.

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$.1 BASIC CONTROL. OF LOGEED VALV58 i

The initial status of Vhvo positions and lockisystemvalvelineupsN 5.1.1 I

devices is estabh&shed n l i

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Performed followhag an estage.

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5.1.2 The valves 11sted 1

" Locked Valve 67.{belockedinthe she Verificatten Cheek a specified_sosition w&

the seestfied sadlocks using lengths of'shain or e y posltive locking devices.

l 5.1.3 Locks should be pissed on the tomota operator for those annual valves that have reeste operators such as reach rede.

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i 5.1.4 in the esses where it is feasible to physically took the apparatus, a Es any be used.

4 5.1.5 When a les 3.is' unlooked for operational i

purposess skala should

&f possible be

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looked to seemtesepensatsseastoprecludeloss.

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5.1.6 If the look esatet be affined at the sosponente.

s geturned to the Shift,

I supervisor spos tsar.,

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.u. r looked valves shall 1l gatuse s la tho g seg e{L I

5.1.7 had Valve J

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tis.ofeehlo.gkedvalvewill

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S.1.9 Padlocks s

' apt normally be removed to a'

verify tem e valves.

If looks must be r

ree tien must be independently

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5.2 MISPOSITIO R D VALVES /INOFERABLE EOCKING DEVICES i

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Valves in position other than the required position due to l

the provisions of sub-subsection i

5.1.5 are not considered 1

sispositiones.

l 5.2.1 If any looked valve is discovered in a position other than the required position or a valve Locking device is i

found inoperable, the operator shall NOTIFY the Shift--

j Supervisor.

4 i

5.2.2 The Shitt Supervisor shall a.

FERFDEN en evaluation to determine if the valves i

current position has resulted in any adverse i

system conditions.

b.

FERFORNenovatushiontodeterminewhether i

repositioning the valve to its correct configuration will result in any adverse system conditions, Based on an secostable evaluation.ffected valve or DIRECT the -

c.

1 re,, positioning an4 Lookina of the a is unesceptable, sha_111RITIATE placing the component / systems affected in a position where the i

valve saa be restored to its correct configuration, d.

ENSURE a Defisioney Card per 00150-C, " Deficiency I Control" has been initiated.

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5.1 FROCEDURES 1

3.1.1 00008 C,

Flent to Control" 5.1.2 00150=C.

"Defistener 1."

5.1.3 00308Os.(

' tion Policy" S';.-I,

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Equipesak And Tagging" 3 - q T>

Ta p."1 3.1.5 11888 1.. "Leeked tion tes" S.t

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3.1.8 11887 0.! "&sehed V tion Cheektist"

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CN-TA-88-71 FR55/CW35 460

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RT50 Fluid, Rediatten 4 Support Systems Pe(ertau 2, ny-wm 234-4317 7"

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February 15, 1987 g a fg seer geren Dilution Event Analysis - RCS Active Volumes WGr/g J. C. Rock, Witt 4-09 Transtant Analysis MECE 4-09 P.A.LeftesI R. K. Stirte sc:

R. R. Etting E. C. Arnold K. P. Slaby R. A. Loose P~. A. Serilla File: DInf-231/2

5. C. Seguin RAN 281/2

References:

1-Letter FR$5/CWBS-455. 2-9-87.

2-Calev1stien FR50/CWB5-C-Op3A, ' Addendum A to FR55/CW 3-cales1stion FR55/CWB5 h 2-12-87.Og3, 'Seren Dilution (Disi, RAM)", J. E. Fix Active Velsmes". J. E. Fiz, 2-2-87.

in Reference 1. Fluids. Radiatten. & Support Systems (PR55) had I

mitted the active sizing volume for use in the FIAR Beren Diluti

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This'1etter is a follow-up letter as FR55 i

has calculated and documented in Referense 2. the active sizi analysis for several plants.

The active L

) and Seabrook Unit M (RAN).

one full Reector Geofant System 1 esp (not for Stever Va11er Unit M (

Meat Asmoval train. The tetel active volume volumes include the volume l

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follows:

[

Istf. Seever Talley Deft N 5239.1 es.ft.

W13.9 se.ft.

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RAN - Seabreak theit M Per your vegvest. the volumes of those segments which ee l

active mining velames fbe these plants transmitted in Referense If there are any questions, please feel i

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tabulated in the Atteefmont.

free to contact the. undersigned.

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cal, ste, & 90P Systems j

suusan./phr Attichment L

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VEGP-FSAR-15 O

15.4.6 CBENICAL AND VOLUME CONTROL SYSTEM MALFUNCTION THAT RESULTS IN A DECREASE IN THE BORON CONCENTRATION IN THE REACTOR COOLANT O

' Identification of causes and Accident Description 15.4.6.1 Reactivity can be added to the core by feeding primary grade l30 water into the reactor coolant system (RCS) via the chemical and volume control system (CVCS).

Boron dilution is a manual O

operation under strict administrative controls with procedures calling for a limit on the rate and duration of dilution.

A boric acid blend system is provided to permit the operator to match the boron concentration of reactor coolant makeup water during normal charging to that in the RCS.

The CVCS is designed to limit the potential rate of dilution to a value which, after indication through alarms and instrumentation, provides the operator sufficient time to correct the situation in a safe and orderly manner.

The opening of the primary water makeup control valve provides makeup to the RCS which can dilute the reactor coolant.

Inadvertent dilution from this source.can.be readily terminated by closing the control valve.

In order for makeup water to be j

added to the RCS at pressure, at least one charging pump must j

be running in addition to a reactor makeup water pump.

l30 l

Normally, only one primary grade water supply pump is operating while the other is on standby.

The beric acid from the boric acid tank is blended with primary l

grade water in the blender, and the composition is determined

'by the preset flowrates of boric acid and primary grade water l30 on the control board.

3 l

Information on the status of the reactor coolant makeup is continuously available to the operator.

Lights are provided on the control board to indicate the operating condition of the j

j pumps in the CVCS.

Alarms are actuated to warn the operator if l

i IO Amend. 3 1/84 15.4.6-1 Amend. 30 12/86

VEGP-FSAR-15 4

boric acid or domineralized water f3cwrates deviate from preset values as a result of system malfunction.

This event is classified as an American Nuclear Society

{

Condition II incident (an incident of moderate frequency) as defined in subsection 15.0.1.

l 15.4.6.2 Analysis of Effects and Consequances

(

15.4.6.2.1 Method of Analysis To cover all phases of'the plant operation, boron dilution startup, cold shutdown, hot standby, and dtiring refueling, power oporation are considered in this analysis.

15.4.6.2 1.1 Dilution During Refueling.

An uncontrolled boron This accident dilution accident cannot occur during refueling.

is prevainted by administrative controls which isolate the RCS from the potential source of unborated water.

177, and 183 in the CVCS will be lo'cked clos'ad 4

g Valves 175, 176, These valves will block the flow during refueling operations.

paths which could allow unborated makeup water to reach the Any makeup which is required dur.ing refueling will be borated water supplied from the refueling water storage tank by RCS.

the low head safety injection pumps.

and Dilution Durine Cold Shutdown, Hot Standby, 15.4.6.2.1.2 An analysis was performed to evaluate boron Hot Shutdown.

dilution events during cold shutdown, hot shutdown, and hot Failure modes and effects analysis, human error analysis, and event tree analysis were used to identify credible standby.

baron dilution initiators and to evaluate the plant response to For the initiators identified, time intervals L

from alarm to loss of shutdown margin were calculated to

(

these events.

g determine the length of time available for operator response.

These calculations depended on dilution flowrates, boron i

and Reactor Coolant-System volumes specific to 1

concentrations, The technique modeled the event,and mode of operation.

' including both realistic plant conditions and responses, l

/

mechanical failure and human errors.

The analysis identified four events which were considered to be

)

the most likely initiators:

1 Domineralizer outlet isolation valve open during resin i

1.

flushing.

Valve 226 open following BTRS domineralizer flushing f

2.

operation.

I 15.4.6-2 Amend. 17 7/85 t

___ - _--- -_ _ A

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VECP-FSAR-15

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i 3.

Failure to secure chemical addition.

Boric acid flow control valve (FV-110A) fails closed

)

4.

17 during make-up.

Initiator 4 was found to be the most limiting event for modes 3, i

The parameters used in the calculation of time 1

4, and 5.

available for operator response are listed in table 15.4.6-1.

l Since the active volumes considered are so small in cold shutdown with the reactor coolant loops drained,'it was determined that the sarie valves locked out in refueling would 30:

need to be locked out in cold shutdown when the reactor coolant loops are drained.

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Amend. 17 7/85 15.4.6-2a Amend. 30 12/86

l VEGP-FSAR-15 ei i

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(This page has intentionally been left blank.)

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VEGP-FSAR-15

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15.' 4. 6. 2.1. 3-Dilution-During Full Power Operation, -

Including Startup.

Conditions at startup Il7 15.4.6.2.1.3.1 Dilution During Startup.

require the reactor to have available at least 1.30-percent The maximum boron concentration Ak/k shutdown margin.

required to meet this shutdown margin is conservativelyThe following coj i (W estimated to be 1704 ppm.

for an uncontrolled boron dilution during startup:.

Dilution flow is assumed to be the combined capacity I

A.'

of the two primary water makeup pumps (approximately 242 gal / min).

A minimum water volume (9757 ft ) in the reactor 8

l B.

This volume corresponds to coolant system is used.

the active volume of the RCS minus the pressurizer

volume, i

l17 15.4.6.2.1'.3.2 Dilution During Power Operation.

During power operation, the plant may be operated two ways, under manual While operator control or under automatic Taq / rod control.the plan be a maximum of 242 gal / min, which is the combined capacity of While in automatic the two primary water makeup pumps.

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control, the dilution flow is limited by the maximus. letdown i

flow (approximately 125 gal / min).

,p Conditions at power operation require the reactor to have The available at least 1.30-percent Ak/k shutdown margin.

maximum boron concentration required to meet this shutdown p'T

%/

margin is very conservatively estimated to be 1704 ppm.

15.4.6-3 Amend. 17 7/85

i,.

l VEGP-FSAR-15 3,

3 A minimum water'. volume (9757 ft ) in the RCS is used.

This volume corresponds to the active volume of the RCS minus the pressurizer volume.

(

15.4.6.2.2 Results The calculated sequence of events is shown in table 15.4.1-1.

l 15.4.6.2.2.1 Dilution Durina Refueline.

Dilution during g

refueling cannot occur due to administrative controls.

(See l

l paragraph 15.4.6.2.1.1).

17 15.4.6.2.2.2 Dilution Durina Cold Shutdown.

For dilution j

i during cold shutdown, the Technical Specifications provide the required shutdown margin as a function of RCS boron 30 concentration.

The specified shutdown margin ensures.that the operator has 15 min from the time of the high flux at shutdown alarm to the total loss of shutdown margin.

15.4.6,2.2.3 Dilution Durina Bot ~ Standby and Hot Shutdown.

For dilution during hot standby and hot shutdown,.the Technical.

k l

Specifications provide the required shutdown margin as a function of RCS boron concentration.

The specified shutdown 30 margin ensures that the operation has 15 min from the time of i

L the high flux at shutdown alarm to the total loss of shutdown margin.

15.4.6.2.2.4 Dilution Durine Startup.

In the event of an unplanned approach to criticality or dilution during power escalation while in the startup moda, the operator is alerted to an unplanned dilution by a rea: tor trip at the power range After reactor trip there is neutron flux high, low setpoint.

at least 19.0 min for operator action prior to loss of shutdown g

margin.

15.4.6.2.2.5 Dilution Durina. Power Operation.

During full-power operation with the reactor in manual control, the is alerted to an uncontrolled dilution by'an

[

operate.

At least 19.0 min are 4

overte.,arature AT reactor trip.

4 L

availr4le from tho' trip for operator action prior to loss of t

shuh cen margin.

I During full-power operation with the reactor in automatic

. control, tho' operator is alerted to an uncontrolled reactivity At least 36.8 min

_g

'insartion~by the rod insertion limit alarms.

1 are available for operator action from the low-low rod

. insertion limit alarm unti.1 a' loss of shutdown margin occurs.

Amend. 17 7/85 L

Amend. 30 12/86 15.4.6-4

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l0 VEGP-FSAR-15 C

l TABLE 15.4.6-1 I

l PARAMETERS

[

l Dilution Flowrates:

Initiator Flowrate (com) j 63 1

'2 120 3.5 3

l30 130 4

Volumes:

Mode Volume (ft3)

Volume (cal)

.3, 4 9972 74593 6346 47466 0

Sa;(filled)

Boron Worth - 14 pcm/ ppm.

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W Amend. 17 7/85 Amend. 30 12/86 I

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'Page b.

12/23/87

+

M IILUTI N IT H TRACKIE NASTR REPORT lien i RESP 11885 NTE telt NTE K50tlPi!ON STATE 80P IDENT IIE RESOLVEB 11 ALL 12!I1/87 11/94/08 // IIDilFY lup0ER AM TYPE OF CONTRETIR esse issued to all departaents.

ASSISTMCE MIulEB.

25 MINT 12:01487 II/H itt./ / KTEMilE UNBEHATER INSPECTIM Mau!EIIENTS, ISBNE MTL. REB. BlWR SEN.

I ENIR 12/11/87 O!!!4!It // KTEMIE SCOPE E Ill P90ERM.

5 CHEM 12/01/87 01/14/80 // NTEMilE INIAT INIPECTiONS 70 K PERFORNE3 m FN MATERS & NM'S 24 ENOR 12!91/I7 01/14/00 ! / SWIIER TElilNB St3PE AIS PLM 15 ENGR 12/01/87 till5/ N / / NTEmilE SCOPE W NITCNVARS t0ILE TEST BY ATLMTA IFMR eil &

TRANIFOR m NIRK sees relay mark.

19 MINT 12ttle87 01/15/M / / KTEmilE IF W MCK-UP TMININ Il lEEBEB.

21 EL 12/01/87 01/20/05 // IIENTIFY OUTAIE SIRUEILLAIEES/CNNIITTIElfl MNIR15 C80LETIN lu 80TAE.

7 MINT 12/01/87 81/38/08 / / 3 CAPE W LIVE LSAS PACKim PRIMAN IF ANT.

8 MINT 12/91/87 91/30/08 // NTERNilE SCWE OF IONTS TE3fl5 FM SOEBIA.E IINCT.

l 14 ABNIN 12/01/87 81/30/00 / / IEVELOP PRIINEL ACCESS 90EB15 AS TMINim PRINAN & EIEME 16 SCIED 12/01/87 01/38/08 / / KTEINilE TEWINARY 1961LR IEEIS AS LOCAflN I

17 MINT 12/01/87 81/38/98 / / ARAME RAtlIWIAPN MEv!CES IF MNIAEB.

IIAIE CONTRid IF IEE3 ARINS.

1 IB HP 12/81/87 SI/38/N / / NVELW PLAN N llAElm 18E5, ENIP.,

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4 23 TRAIN!

12/01/87 81/38/M / / MlulN!!E TRalNIN IIRIN WTE FN PBSOMEL INYEvrst IN WTW I

NG 27 MTERI.

12/01/87 81/30/08 / / MfDIE M ERMTIN, $14815, LICATim

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TV 33 12/01/87 01/30/08 / / ENE BEVELWINIT AM PE-INTE Pull 3 EllGR 12/01/87 81/31/88 // MSIl WIN TOPDFIRRTlWW. ISSE esist mill probably use i

BIS MelESTS7 centracter.

22 SCHED 12/01/07 83/98/W // PMPAE PMLlulNARY SOGEE l

26 EllIR 12/01/87 N/91/98 // CEITRE RN LEAR INIPECTIN. NNAT IS RENIN 97 6 NSAC 12/91/87 //

/ / IETDilllE Am RESEATNT C8MilTTENTS TO l

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12/01/87 //

/ / 1r1115 35 12/01/87./ /

// LESSO E LEAN ES 36 12/01/87 //

/ / IERI Milm W OUTAGE ACTIVITY IN Afi m

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I 12/23/87 ESOLilTION ITH TRACKlus

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.N I kHP NS$$ WTE MTE MTE IDCRIPTim STATUS 30P IIDT BE RESOLVEB 2 D6R 12/01/87 12/17/07 12/17/07 KTEMIE SCOPE OF TW91E-EERATOR resolved per McLeod Itr 6/24/07 NIRK.

4 MINT 12/01/8712/17/0712/17i87 KTEMIE SCOPE OF PM PROIRAN TO E 1R1 sitt include seee 34 & 54 es.

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p.e.'s

? ENGR 12/01/8712/17/8712/17187 REVID AND REVIE PROCOWE FM 815ASSE WLT OF R.V. MAI FOR 6000 COORS.~

II DER 12tII,I? 12/17/I7 12/17/87 KTERNIE TYPE ANI EWlE SOE BA61C MTRIAL PROC. INITIATO UNOGATER Kit!DAL T8ES.

12 ENGR 12/01/I7 12/17!I7 12/17/07 KTDMllE SCOPE F Def CURRENT TDTIM Seecific RFO's for S/6 Et test

& ISSE CNTR. SERVIES WIREST issued.

13 ENIR 12/01/87 12/17/87 12/17/07 !$8 E SLUISE LA E E CONTR ETW SERVICES MOIEST 28CHEN 12/81/8712/17/0712/17/8715 NY9R000 POSIIM A061 Tim TI E ES mill receive hydroges perseide 30E7 treateest.

28 ENGR 12/01/8712/17/9712/17/07 REFIELis GFF LDAS PLAN Nothed will be complete efflead.

29 DGR 12/11/87 12/17/07 12/17/07 STEM IENERATOR NRK OTIER TlWI lisse.

PREVIOUILY IIDTIFID 31 DGR 12/01/8712/17/8712/17/07 BCP FRAGETS Prillaisary frageets prepared by estage & Sched.

34 12/11/8712/17/0712/17/87 P/2 UIEAIE IN PRE-OUTAIE PLAll P/2 mill be used for ere-setage plass.

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CfM(ITNENT TO SAFETY.

4 TRAINING PROGRAM AG6iDA JANUARY 6, 1988 O

PROGRAM OBJECTIVES J. E. SWARTZHELDER - NUCLEAR SXFETY AND COMPLIANCE MANAGER 0

INTRODUCTORY REMARKS G. BOCKHOLD - PLANT GENERAL MANAGER, V0GTLE O

ACHIEVING REGULATORY COMPLIANCE (TAB 1)

W. E. BURNS - NUCLEAR LICENSING MANAGER'- V0GTLE R. D. BAKER - NUCLEAR LICENSING MANAGER - HATCH 0

CURRENT REGULATORY ENVIRONMENT AND CONSEQUENCES FOR GPC (TAB 2)

J. M. PUCKETT - ASSISTANT TO MANAGER, NUCLEAR SAFETY AND LICENSING L. T. GUCHA - MANAGER, NUCLEAR SAFETY AND LICENSING 0

BREAK 0

PRACTICAL GUIDANCE FOR ENHANCING COMPLIANCE (TAB 3)

J. E. SHARTZHELDER - NUCLEAR SAFETY AND COMPLIANCE MANAGER - V0GTLE H. F. KITCHENS - OPERATIONS MANAGER A. L. MOSBAUGH - ASSISTANT PLANT SUPPORT MANAGER M

0 CLOSING REMARKS (TAB 4')

JAMES P. O'REILLY - SENIOR.VICE PRESIDENT - NUCLEAR OPERATIONS 0

QUESTIONS AND ANSMERS - ALL SPEAKERS 6

0 APPENDIX A - REGULATION TO IMPLEMENTATION (TAB 5)

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COMMITMENT TO SAFETY PROGRAM OBJECTIVES

Increase awareness of how noncompliance and compliance with NRC regulations occurs

~

e Increase awareness of consequences of noncompliance i

e Enhance our approach to achieving both nuclear safety and regulatory compliance

- Know how to always act conservatively to meet the Safety Intent of Plant Procedures and Plant Technical Specifications

- Recognize when to get help and what help is available 4

- Know when to write a DC

COMMITMENT TO SAFETY u

VOGTLE OVERVIEW i

e Significant Progress

- Experience i

.~~

- Improvements y

e Continuing Effort

- Attention to detail

- Implementation by every worker

- Plant and industry lessons learned i

e Recent Examples

- Reactor Trip Breaker testing

- Power Reduction - Calorimetric procedure I

i

[~

l REGULATORY PROCESSES 1

1 i

o Commitment to safety throughout our organization j

and teamwork l

- Everyone has responsibility j

- Maintain the highest standards of compliance

- Teamwork e Regulatory and procedural compliance

- Ensures plant and personnel safety

- When in doubt, discontinue activity, seek assistance, and revise procedures as necessary.

e NSAC i

- Provides focus for regulaton interpretations

- Works with departments to achieve consensus j

- Works with Corporate Licensing

7-RECENT EXAMPLES OF NONCOMPLIANCE e incorrect determination of Reactor Trip Breaker operability -

- Failure to recognize that when a RTB is bypassed for maintenance it becomes inoperable resulted m an improper application of the TS action statements

- Violation of Technical Specifications resulted in a Severity Leirel lli Violation and Civil Penalty i

e Contribating Factors to Event

- An ambiguous Technical Specification I

- Insufficient licensing assessment 'of interpretation to assure it reflected the Safely intent of the Technical Specification, not just a literal reading of the words j

- Insufficient emphasis on acting conservatively when confronted with an unclear set of circumstances i.

g RECENT EXAMPLES OF NONCOMPLIANCE

. e Tech Spec Surveillance of Room 110 Temperature Reading not performed within the allowed time interval Access to Room 110 blocked to allow a freshly painted area j

to day, therefore missed reading on day shift

~

- Missed reading not recognized as missed surveillance until night shift l

- DC initiated when access to Room 110 still blocked on L

night shift

- LER required to report missed surveillance

Contributing Factors to Event

- Failure to recognize required Tech Spec surveillance readmgs

- Lack of timely communications concerning deficient conditions

- Lack of planning for required activities of operations in the execution of MWO's

~l

_3_

i RECENT EXAMPLES OF NONCOMPLIANCE o " Drip Leak" not recognized as an Appendix J violation i

l

- Containment. isolation valve on safety injection accumulator j

sample line leaked beyond Appendix J criteria

- Responsible engineer recognized Appendix J violation

- Violation of Technical Specifications and a LER resulted i

e Contributing Factors to Event l

1

- Lack of timely communications concerning deficient conditions t

- Insufficient emphasis on acting conservatively when circumstances unclear (i.e. write DC).

- Insufficient emphasis on using all available resources (i.e. engineering) to assess a possible deficiency m

e

7 SUCCESSFUL EXAMPLES OF MAINTAINING 1

REGULATORY COMPLIANCE Example 1 e Tech Spec Requirement - S/G Sample Isolation Valves

- TS 4.7.1.2.1.B(1) requires that each automatic valve in the

~

auxiliary feedwater flow path actuates to its correct position upon receipt of auxiliary feedwater actuation test signal.

e issue

- Does this requirement apply to steam generator sample line j

isolation valves, which automatically close on an auxiliary feedwater actuation signal?

- What action is required when a steam generator sample line 4

isolation valve will not automatically close on an auxiliary l

feedwater actuation?

i i

I SUCCESSFUL EXAMPLES OF MAINTAINING REGULATORY COMPLIANCE Example 1 e Interpretation

~

- TS 4.7.1.2.1.B(1) applies to the subject valves because, if left open, they would provide a flow path for auxiliary feedwater.

- With a sample line isolation valve incapable of automatically closing, t

the intent of the requirement would be met by closing and tagging out l

the valve. For sampling, an alternate flow path should be used if possible. Opening the inoperable valve would constitute entry into anLCO.

5 l

e Results

- Avoided 72 hour8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months LC0 for inoperability of auxiliary feedwater train.

- Interpretation accepted by NRC

- Permanent TS change to incorporate this interpretation has been initiated.

SUCCESSFUL EXAMPLES OF MAINTAINING' REGULATORY COMPLIANCE i

Example 2 e Tech Spec Requirement - Tendon Surveillance

~

- TS 4.6.1.6.1.E requires that containment tendon sheathing filler grease ~ have less than 5% voids by volume. If this criterion is not met, voiding must be reduced to less than 5% within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months and an engineering evaluation must be performed and submitted to the NRC within 15 days or the unit must be taken to hot standby within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and to cold shutdown within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

e issue

- If a tendon is leaking grease and that tendon is shown by analysis to be unnecessary for containment structural integrity, does the above action need to be applied? -,

w

4 SUCCESSFUL EXAMPLES OF MAINTAINING REGULATORY COMPLIANCE Example 2

Interpretation

- The analysis does not exempt GPC from applying the 72 hour8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months LCO.

~~

In this case the voiding would need to be reduced to less than 5%

within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months and the analysis would need to be submitted to the NRC within 15 days. The analyses-would show that no abnormal degradation of containment integrity could result from loss of the filler grease.

e Results

- The shatdown requirement was judged to be overly conservative since the loss of filler grease was not a direct indication of degradation of containment structural integrity. NSL initiated a permanent TS change to delete the shutdown requirement based on a precedent set by another utility. The NRC has indicated that approval was likely.

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4 WORKING WITHIN THE FRAMEWORK,

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e Adhere to the Safety Intent of Plant Procedures and Technical Specifications

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- Key to how GPC achieves Regulatory Compliance

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and Nuclear Safety

- Link between Tech Specs and Plant Procedures and the Law is Complex e Act to avoid noncompliance

- Act conservatively when circumstances unclear

- Use all organizational resources available at i

Plant Vogtle and General Office I

. l

t GPC STAFF ROLES IN ACHIEVING REGULATORY COMPLIANCE j

Operations:

Front I.ine in achieving compliance

~

- Constantly monitoring plant status relative to regulatory compliance

- Adhering to plant procedures and tech specs, conservatively acting to meet the safety intent e NSAC:

Support for clarification of Gray Areas in

~

Regulatory Compliance 1

- Specialists on Plant Vogtle regulatory commitments and the regulatory framework j

- Coordinate on-site communications with NRC Inspectors f

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GPC STAFF ROLES IN I

ACHIEVING REGULATORY COMPLIANCE 1

NSLD in the General Office:

Coordination of all Communications with the NRC and in-depth regulatory expertise

~

- Provide support to sites on in-depth reviews to resolve regulatory issues

- Constant monitoring of the regulatory environment e Engineering at Site and General Office:

Provide the necessary l

technical expertise to assist in assessments of compliance and nuclear safety

- Specialists on the Plant Vogtle design basis \\

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GPC VS. NRC RESPONSIBILITIES e GPC responsible for:

- Operating Plants Hatch and Vogtle safely and in full compliance with all regulatory commitments.

- Producing electrical power in an efficient and economic manner.

e NRC responsible for:

- Assuring that GPC fulfills its responsibility to operate Plants Hatch and Vogtle without undue risk to the health and safety of the public.

- Performing its functions in a manner that convinces the public that they are adequately protected.

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NRC INSPECTIONS & INVESTIGATIONS i

e Performed to determine whether GPC is meeting its i

commitments to Safety and Regulatory Compliance.

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Sample all aspects of GPC activities.

- Design

- Fabrication and construction

- Testing

- Operations l

e NRC inspections Do N61 take the place of GPC ongoing activitie, s.

j e Inspector's authority derived from the NRC regulations.

- Granted access to plant

- Granted access to accurate, complete, and timely information

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NONCOMPLIANCE = ENFORCEMENT' i

=

CONSEQUENCES e Minor noncompliances generate Severity Level IV and V violations.

Repeat Severity Level IV or Severity level I, ll, or ill violations can lead to escalated enforcement actions.

- Enforcement conferences 1

- Imposition of civil penalties

- Orders i

e Additionally NRC can issue Confirmatory Action Letter (CAL) to assure licensee action on other safety significant issues.

I

NEED TO ADHERE TO THE HIGHEST ' i STANDARDS OF SAFETY AND COMPLIANCE WHY?

i i

a e Fulfill obligation to public health and safety

Consequences to nuclear industry of another accident (TMI, 6

Chernobyl) would be severe.

e Serious consequences to GPC and its employees would result from a prolonged shutdown or accident at Plants Hatch and Vogtle.

l

- Financial impact on GPC

- Severe disruption of employee working environment

a 1

MORE REASONS "WHY" i

4 I

i e NRC recently reorganized to focus more on plant operations.

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- New inspection initiatives

- Augmented Inspection Teams I:AIT's)/

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Incident inspection Teams (llT's?

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- Performance Indicators i

e Don't want to be considered " Problem Plant" i

- Receives increased attention from NRC

- Takes a long time to change image i: couple of SALP cycles e.g. 2 to 3 years) 1 e NRC must appear tougher than ever due to high degree of attention from Congress.

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SOME LESSONS LEARNED IN "HOW" TO ACHIEVE COMPLIANCE j

l e Improved process of technical specification interpretation e Emphasis on improved teamwork & communications l

e Thorough understanding and proper consideration of technical l

specifications prior to taking action I

e Professionalism and personal responsibility are necessary ingredients of compliance and safety e Every employee has a key role to play in achieving compliance t,

COMMON SENSE COMPLIANCE e Know the Plant, Plant Conditions and Procedures i 1

e Use Plant knowledge to recognize situations which require action

~

Comply with SAFETY INTENT of Procedures and Technical Specifications e When unsure, act conservatively e When unsure, get all the help you need 1

e If a deficiency exists, promptly initiate a DC e if you are unsure the nonconformance is a i

deficiency, promptly initiate a DC

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PROCEDURE COMPLIANCE e The act of performing or meeting written requirements of a procedure, recognizing deficiencies in a procedure and stopping work if the procedure can not be safely followed.

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PROCEDURE COMPLIANCE l

e Compliance With Procedures i

- Use current revision of the correct procedure.

- Use any temporary changes applicable to current procedures.

- Follow steps in sequence unless deviations are allowed by procedure.

~

- Have procedure"in hand" or be capable of proper pedormance i.

l of the procedure.

- If the procedure appears to be incorrect, stop and notify your i

immediate supervisor.

- Completion of signoffs after each step. (Prior to starting next step,if appropriate).

- Revise procedures in accordance with 00051-C, " Procedure Review and Approval or 00052-C, " Temporary Changes", when found to be incorrect prior to resuming work.

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PROCEDURE COMPLIANCE

Safe Conditions l

- If a condition or situation exists which is not addressed by a procedure, the plant system or component shall be placed 4

in a safe condition such that normal procedures would apply.

t

- Concurrence of the appropriate Unit Shift Supervisor shall be obtained.

9 i

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i TECHNICAL SPECIFICATION COMPLIANCE I

L e Check / Understand Safety Intent (Bases) i e Verify Condition meets Safety Intent i

e if unsure, obtain all help required-l t

- Operations Department Management

- Plant Staff i

- NSAC

- NSLD e NSAC/NSLD will then initiate actions to modify technical specification to clarify if necessary l

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EVALUATIONS PERFORMED TO IDENTIFY POTENTIAL NON-COMPLIANCES 1

( ~ Sources Of Potential lion-Compliances )

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i COMMON SENSE DEFICIENCY REPORTING i

e Write a DC if the nonconformance occurs in i

or is associated with systems m.

- Containment t

- Auxiliary Building

- Control Building l

- Fuel Handling Building

- Outside Buildings: AFW, DG, NSCW l

e Write a MWO and notify supervisor if noncompliance is associated with:

i

- Turtine Building

- Other outside areas e If you have any doubt if a nonconformance is i

a deficiency, WRITE THE DC i

EVALUATIONS PERFORMED TO IDENTIFY POTENTIAL NON-COMPLIANCES

( Sourcet Of Potential 11on-Compliances )

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4 DEFICIENCY CARD EVALUATION PROCESS

Operations Shift Supervisor / Shift Supervisor i

- Immediate DC review normally within 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months .

- Reportability determination per 50.72, 50.73, 73.71

- System / equipment operability determination

- LCO requirements

~

- Immediate corrective action i

NSAC i

- DC review normally within 1 day

- Evaluate DC for significance and inform management

- Evaluate DC for reportability per 50.73,73.71,21, etc.

- Track DC Status

- Trend DC's

- Notify originator of dispositioning

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I DEFICIENCY CARD PROCESS CONTINUED i

e Plant Department Personnel i

- Aid with evaluation of DC.

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- Determine root cause of SOR

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- Determine / Implement corrective action

- Provide trend attribute codes e PRB

- Review all SOR's for reportability / root cause concurrence l

- Review 'all SOR's for impact on plant operations e OMC

- Aid in determination of reportability / operability e.

GRAY AREAS REQUIRE TEAMWORK t

e Operable / Operability e Reportability e Federal / State Regulatory Requirements e Technical Specification Interpretations e Clarification of Reg. Guides, Codes & Standards, etc.

i e

Licensing Commitments e

Channel Calibrations e

Leakages e

Declaration of NUE's l

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_37_

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l BENEFITS OF TEAMWORK i

Example 1 e Tech Spec Requirement -

i Residual Heat Removal System (RHR) Flow Requirement

- TS 4.5.2.H.3 requires that for RHR pump lines, with a single pump running, the sum of the injection line flow rates is greater than or equal to 3788 GPM. The action requirements for a ECCS subsystem 1

inoperable (i.e., both RHR trains inoperable) is to restore the inoperable subsystem to operable status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months or be in hot standby I

within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in hot shutdown within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

e issue

- If the RHR heat exchanger outlet valves for both train A and B (valves 1-HV-0606 and 1-HV-0607) are at 90% open, is the RHR subsystem of the ECCS inoperable?

l l *

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BENEFITS OF TEAMWORK Example 1 e laterpretation

- Initial interpretation made by operations personnel on shift at 1

the time of occurrence (April 28,1987) resulted in the finding

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that the RHR system was operable in the condition described.

- Subsequent engineering review on May 5,1987, seven days later, j

determined the event reportable based on reducing the RHR system flow rate below the tech spec requirement.

e Results t

- Partial' valve closure problem was fixed.

- Reportabiltiy was determined 7 days after event was discovered.

j

- LER 87-023 was submitted.

4 ;

l BENEFITS OF TEAMWORK Example 2

Tech Spec Requirement - Essential Control Room HVAC

- TS 3/4.7.G requires that two independent trains of control room emergency ventilations systems be operable in modes 1,2,3,4 and when moving irradiated fuel. Actions required when this requirement is not met in modes 1,2,3,4 include restoring the HVAC systems to operable within 7 days or being in hot standby within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and cold shutdown within the next 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

e issue

- Potential failure modes of control room emergency HVAC were not adequately analyzed to ensure system operability requirements met, i.e, maintain a ~ positive 1/8 inch water pressure in the control room.

- Potential effect of Unit 2 construction upon the availability of the redundant HVAC l

t intake for emergency control room with HVAC. The Unit 2 side intake dampers had been closed and a single failure could have closed the Unit 1 dampers resulting in the possible inability of the system to maintain the plus 1/8 inch positive pressure in the Unit 1 control room.

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h BENEFITS OF TEAMWORK Example 2 l

e Interpretation

- Interaction between Engineering, Operations and NSAC determined the reportability and immediate corrective actions for the situation.

Results

- Immediate corrective actions and reports made expeditiously.

- Long term design changes processed.

4

- LER 87-044 issued to report this condition.

i

.l 4

RECOMMITTING TO HIGH STANDARDS OF -

SAFETY AND COMPLIANCE

Consequences of non-conservative actions and non-compliance impact everyone.

e Everyone has a role in achieving compliance.

e Teamwork is essential / no one person or organization knows it all.

e Professionalism at all levels necessary e Guidance has been provided for determining the path to compliance when " Gray" areas arise.

Safety & compliance are not counterproductive to efficient production of power.

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9 YOU SHOULD NOW UNDERSTAND O

HOW NONCOMPLIANCE OCCURS 0

HOW COMPLIANCE IS ACHIEVED 0

CONSEQUENCES 0

ACT CONSERVATIVELY 0

DEFICIENCY CARDS 0

ASK FOR HELP WHEN UNCERTAIN i

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The basic statute deahng with the hcensmg and regulation of atomic energy activities is the Atomic Energy Act of 1954, l

as amended. The Energy Reorganization Act of 1974 left the Atomic Energy Act largely intact but abolished the Atomic Energy Commission and transferred its functions under the Atomic Energy Act to two newly created agencies, the Nuclear Regulatory Commission and the Energy and Research Development Administration.

The Department of Energy Organization Act, approved August 4,1977 transferred all of the functions of the Energy Research and Development' Administration and its Administrator l

to the Department of Energy.

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GENERAL DESIGN CRITERIA i

" Pursuant to the provisions of 10 CFR 50.34, an application for a construction permit must include the principal design criteria for a proposed facility. The principal design critena l

establish the necessary design, fabrication, construction, testing, and performance requirements for structures, systems, L

and components important to safety; that is, provide reasonable assurance that the facility can be operated without i

undue risk to health and safety of the public."

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STANDARD REVIEW PLAN l

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Guidance For NRC. Staff Reviewers i

e Evaluates Information Submitted Per

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Each Section Organized As Follows:

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- Areas Of Review 1

i 1

- Acceptance Criteria

- Review Procedures

- Evaluation Findings

- References l

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t FRAMEWORK FOR COMPLIANCE l

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10 CFR STANDARD REG.

S REVIEW GUIDES PLAN NUREGs And GENERIC LETTERS e

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STANDARD REG.

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ANALYSIS REPORT INCLUDING TECHNICAL m@>

SPECIFICATIONS AND AND OTHER LICENSE DOCUMENTS (ER, EP, SP)

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CRITERION 17 - ELECTRIC POWER SYSTEM'S L

Electric power from the transmission network to the l

onsite electric distribution system shall be supplied by l

two physically independent circuits (not necessarily on separate rights of way) designed and located so as to j

minimize to the extent practical the likelihood of their simultaneous failure under operating and postulated accident and environmental conditions.

i i

l A-10

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l-L REGULATORY GUIDE 1.32 I

A. INTRODUCTION i

1 General Design Criterion 17, " Electric Power Systems,"

i of Appendix A, " General Design Criteria for Nuclear Power i

Plants," to 10 CFR Part 50, " Licensing of Production and Utilization Facilities," requires that an onsite electric I

power system and an offsite electric power system be l

provided.to permit functioning of structures, systems, and

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components important to safety.

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L C. REGULATORY POSITION 1.

For the portion of safety-related electric power systems within its scope, the criteria, requirements, and

~~

recommendations in IEEE Std 308 - 1974 are generally acceptable to the NRC staff and provide an adequate basis for complying with the Commission's General Design Criteria l

17 and 18 of Appendix A to 10 CFR Part 50 with respect l

l to the design, operation, and testing of electric power 1

systems.

1 I

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l A-17 i

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STANDARD REVIEW PLAN I

8.1 ELECTRIC POWER - INTRODUCTION

~

II. ACCEPTANCE CRITERIA i

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Table 8-1 " Acceptance Criteria and Guidelines for Electric Power Systems," lists the acceptance criteria currently 1

applied by the staff to electric power systems. Implementation of these criteria in accordance with applicable guidelines of regulatory guides and Branch Technical Positions will provide assurance that systems will perform their design 1

safety functions when required.

A-13

l TABLE 8-1 s

i Applicability (SAR Section)

Criteria Title 8.2 8.3.1 8.3.2 Remarks 1 d. GDC 17 Electric Power Systems A

A A

2 c. RG 1.32 Use Of IEEE Std 308, " Criteria G

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See IEEE For Class 1E Power Systems For 308 Nuclear Power Generating j

Stations" l

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l-8.1.3 SAFETY-RELATED LOADS

. Safety loads n're defined as those systems and devices that

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require ele ~tric power in order to perform their safety fune-c l

tions.

The ac safety loads are shown in figure 8.3.1-2.

i Tables 8.3.2-1, 8.3.2-2,'8.3.2-3, and 8.3.2-4 list the loads on i

the Class lE 125-V de batteries.

Power supplies for the reactor protection system have sufficient stored energy to

)

remain available through any anticipated switching transients, The power supplies are shown on figures 8.3.1-5 and 8.3.1-6.

t i:

8.1.4 DESIGN BASES 4

8.1.4.1 Offsite Power System 1

A.

Electrical power from the power grid to the plant site is supplied by two physically independent circuits de-signed and located to minimize the likelihood of si-multaneous failure.

B.

Two physically independent reserve auxiliary trans-formers are provided to supply the onsite electrical l

distribution system.

C.

The loss of one of the nuclear units at VEGP or the l-most critical unit on the' grid will not result in the

~

loss of offsite power to the class lE buses.

I D.

The switchyard is designed with duplicate and

[

redundant systems; i.e.,

two independent battery systems, two trip coils per breaker, and protective l

relay schemes.

i 8.1.4.2 Onsite Power System 3

A.

The onsite power system includes a separate and inde--

pendent Class lE electric power system for each unit i

(General Design Criterion (GDC) 17).

)

B.

The onsite Class lE ac electric power systems for each unit are divided into two independent load groups referred 1to as trains, each with its own power supply, buses,. transformers, loads, and associated 125-V dc control power.. Each train is independently capable of maintaining one unit in a safe shutdown condition

.(GDC 17),

i.

4 j

B.1-2

1.

i VEGF-FSAR-8 Surveillance instrumentation is provided in accordance with IEEE 387, as described in subsections 9.5.4 through 9.5.8.

Tests are conducted on each diesel generator unit in accordance with IEEE 387, as listed in paragraph 8.3.1.1.3..

D.

No provisions are made for automatic transfer of j

trains between redundant power sources.

E.

No portion (ac or de) of the onsite standby power systems is shared between units (GDC 5).

F.

The Class 1E electric systems are designed to satisfy the. single failure criterion (CDC 17).

G.

For each of the four protection channels, one inde-pendent 125-V de and at least one 120-V vital ac power source are provided.

Batteries are sized for 165 min

of operation withour the support of battery chargers.

H.

Separate non-Class 1E de systems are provide'd for non-

~

Class 1E controls and de motors.

l-I.

Raceways are not shared by Class 1E and non-Class 1E cables.

4 i -

J.

Special identification criteria are applied for Class 1E equipment, including cabling and raceways.

Refer to paragraph 8.3.1.3.

j l

K.

Separation criteria are applied which establish re-quirements.for preserving the independence of redundant Class 1E electric systems.

Refer to paragraph 8.3.1.4.1.

i L..

Class 1E equipment is designed with the capability of l

being tested periodically (GDC 18).

8.1.4.3 Desien Criteria, Regulacory Guides, and IEEE Standards Compliance to.GDC 17, 18, and 50 is discussed in section 3.1 and paragraphs 8.3.1.2, 8.3.2.2, and 8.3.1.1.12.

The design of the offsite power and onsite Class 1E electric systems l

generally conforms with the regulatory guides and standards listed below as clarified in section 1.9.

Refer to table 8.1-1

- for acceptance criteria and guidelines and their applicability

' to chapter 8.

i 6.1-4

s TABLE 8.1 (SilEET 1 OF - 3) -

[

ACCEPTANCE CRITERIA AND GUIDELINES FOR ELECTRIC POWER SYSTEMS ti App t icat i : i ty ( r SAR

b' cri terJ.a

-1111s Section/Sunsectseni.

amrig RJ RJ.1.

SJJ 1.

GOC Appendim A to I

10 Code of Federst Reges t a & ions - (CFR) SS l

a.

-GSC 2 Design Bases for Protection A

A Against Naturai Phenomena b.

COC b -

Environmental and Missile A

A Design Sases i.

r:. GOC $

Sharing of Structieres.

A A

A Systems, ased e ;;;.;nts Al d.

CDC 17 Electric Power Systeet A

A e.

GOC IS

. Inspection and lesting of.

A A

A Electrical Power Systems Q

.k-r, t;DC See Cositaineetet Design Bases A

A I

P

?.

Stegulatory Geside t RC)

W s

t a.

RC 1.6 Independence Between Redun-C C

I dant Standby (Onsite) Power Sources and Between their Distribution Systems i

b.

RC 1.9 Selection Design. and C

Osse t ification of Diesel-

+

Generator Units Used as i

Standby (Onsite) Elec-tric Power Systems at Isuclear Power Plants c.

'llo 1432 Use of IEEE Standard 300 C

C C

Criteria for Class 1E Power Systems for stuclear Power Generating Stations

)

d.

RG l.an y Bypassed and inoperable C

C G

Status inoication for fluclear Power Plant Sarety Systems e

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3/4.8 ELECTRICAL POWER SYSTEMS 3/4.8.1 A.C. SOURCES i

i OPERATING

{

I LIMITING CONDITION FOR OPERATION j

i 3.8.1.1 As a minimum, the following A.C. electrical power sources shall be OPERA 8LE:

h Two physically independent circuits between the offsite transmission a.

network and the onsite Class 1E Distribution System, and I

b.

Two separate and independent diesel generators, each with:

1)

A day tank containing a minimum volume of 650 gallons (52% of i

l instrument span) of fuel (LI-9018 LI-9019),

i 2)

A separate Fuel Storage System containing a minimum volume of 68,000 gallons of fuel (7EE of instrument span) (LI-9024, LI-9025), and

}:

3)

A separate fuel transfer pump, j

APPLICABILITY:

MODES 1, 2, 3, and 4.

t j

ACTION:

a.

With one offsite circuit of the above-required A.C. electrical power t

i sources inoperable, demonstrate the OPERASILITY of the remaining A.C.

sources by performing Surveillance Requirement 4.8.1.1.1.a within I hour and at least once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months thereafter.

If either diesel generator has not been successfully tested within the past 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months , demonstrate its OPERASILITY by performing Surveillance Requirements 4.8.1.1.2.a.4 and 4.8.1.1.2.a.5 for each such diesel generator, i

separately, within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months unless the diesel generator is already 4

operating.

Restore the offsite circuit to OPERABLE status within j

72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months or be.in at least HOT STAND 8Y within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and i

in COLD SHUTD0WN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

i b.

With either diesel generator inoperable, demonstrate the OPERASILITY i

of the above required A.C. offsite sources by performing Surveillance Requirement 4.8.1.1.1.a within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months and at least once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months i

therwafter.

If the diesel generator became inoperable due to any cause

}

other than peoplanned preventive maintenance or testing, demonstrate 1

the OPERASILITY ef the remaining OPERABLE diesel generator by perform-ing Surveillance Requirements 4.8.1.1.2.a.4 and 4.8.1.1.2.a.5 witnin 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months 4.

Restore the inoperable diesel generator to OPERABLE status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months or be in at least HDT STAND 8Y within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in COLD SHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

"This test is required to be completed regardless of,when the inoperable ciesel generator is restored to OPERASILITY.

IThe diesel shall not be rendered inoperable by activities performed to sunoort testing pursuant to the Action Statement (e.g., an air roll).

ELECTRICAL POWER SYSTEMS LIMITIliG CONDITION FOR OPERATION ACTIONfContinued) on the time of the initial loss of the remaining inoperable offsite a.c. circuit.

A successful test (s) of diesel OPERASILITY per Surveil-lance Requirements 4.8.1.1.2.a.4 and 4.8.1.1.2.a.5 performed under this Action Statement 'for the G7 ERA 8LE diesels satisfies the diesel generator test requirement for Action Statement a.

f.

With two of the above required diesel generators inoperable, demonstrat the OPERA 81LITY of two offsite A.C. circuits by performing the require-ments of Specification 4.8.1.1.1.a. within I hour and at least once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months thereafter; restore at least one of the inoperable diesel generators to 0PERABLE status within 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months or be in at least HOT STAN08Y within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in COLD SHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

Following restoration of one diese'l generator unit, follow Action Statement b with the time requirement of that Action Statement based on the time of initial loss of the remaining inoperable diesel generator.

A successful test of diesel DPERABILITY per Surveillance Requirements 4.8.1.1.2.a.4 and 4.8.1.1.2.a.5 perfornec under this Action Statement for a restored to OPERABLE diesel satisfies the diesel generator test requirements of Action Stateme,nt b.

SURVEILLANCE REQUIREMENTS 4.8.1.1.1 Each of the above required independent circuits betwee*n the offsite j

transmiss' ion network and the Onsite Class IE Distribution System shall be:

l a.

Determined OPERABLE at least once per 7 days by verifying correct l

breaker alignments, and indicated power availability.

l 4.8.1.1.2 EachdieselgeneratorshallbedemonstratedOPERABI.E:

l a.

In accordance with the frequency specified in Table 4.8-1 on a STAGGERED TEST BASIS by:

l I)

Verifying the fuel level in the day tank '(LI-9018, LI-9019),

2)

Verifying the fuel level in the fuel storage tank (LI-9024, LI-9025),

3)

Verifying the fuel transfer pump starts and transfers fuel from j

the storage system to the day tank, i

4)

Verifying the diesel starts and that the generator voltage and frequency are 4160 + 170, -410 volts and 60 + 1.2 Hz within i

11.4 seconds" after the start signal.

The dTesel generator shall be started for this test by usig one of the following signals:

i i

"All diesel generator, starts foithe purpose of surveillance testing as requirec i

by Specification 4.8!1.1.2 may be preceded by an engine prelube period as i

recommended by the manufacturer so that the mechanical stress and wear on the diesel engine is minimized.

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i 15.4.6 CHEMICAL AND VOLUME CONTROL SYSTEM MAIJrDNCTION THAT I

RESULTS IN A DECREASE IN THE BORON CONCENTRATION IN j

THE REACTOR COOLANT 15.4.6.1 Identification of Causes and Accident' Description i

l Reactivity can be added to the core by feeding primary grade water into the reactor coolant system (RCS) via the chemical and i

volume control system (CVCS).

Baron dilutit la a manual 1-operation under strict administrative contrulu with procedures calling for a limit on the rate and duration of dilution.

A boric acid blend system is provided to permit the operator to l

match the boron concentration of reactor coolant makeup water during normal charging to that in the RCS.

The CVCS is designed 4

to limit the potential rate of dilution to a value which, after j

indication through alarms and instrumentation, provides the 4

operator sufficient time to correct the situation in a safe and' l

orderly manner.

i l

The opening of the primary water makeup control valve provides makeup to the RCS which can dilute the reactor coolant.

l Inadvertent dilution from this source can be readily terminated by closing the control valve.

In order for makeup water to be l

l added to the RCS at pressure, at least one charging pump must be running in addition to a reactor makeup water pump.'

Normally, only one primary grade water supply pump is operating while the other is on standby.

1 The boric acid from the boric acid tank is blended with primary j

grade water at the mixing tee, and the composition is determined l

q by the preset flowrates of boric acid and primary grade water on the control board.

i Information on the status of the reactor coolant makeup is 4

continuously available to the operator.

Lights are provided on j

the control board to indicate the operating condition of the pumps in the CVCS.

Alarms are actuated to warn the operator if i

E I

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Amend. 3 1/84 Amend. 30 12/86 15.4.6-1 Amend. 35 3/88 w

w tw

VEGP-FSAR-15 boric acid or domineralized water flowrates deviate from preset values as a result of system malfunction.

This event is classified as an American Nuclear Society condition II incident (an incident of moderate frequency) as defined in subsection 15.0.1.

t 15.4.6.2 Analysis of Effects and consecuences 15.4.6.2.1 Method of Analysis i

To cover all phases of the plant operation, boron dilution ddring refueling, startup, cold shutdown, hot standby, and power operation are considered in this analysis.

15.4.6.2.1.1 Dilution During Refueling.

An uncontrolled boron dilution accident cannot occur during refueling.

This accident is prevented by administrative controls which isolate the RCS from the potential source of unborated water.

Valves 175, 176, 177, and 183 in the CVCS will be locked closed 4

during refueling operations.

These valves will block the flow -

paths which could allow unborated makeup water to reac'h the i

RCS, Any makeup which is required during refueling will be borated water supplied from the refueling water storage tank by the low head safety injection pumps.

15.4.6.2.1.2 Dilution During Cold shutdown, Hot Standby, and Hot shutdown.

An analysis was performed to evaluate boron dilution events during cold shutdown, hot shutdown, and hot standby.

Failure modes and effects analysis, human error analysis,.and event tree analysis were used to identify credible 4

boron dilution initiators and to evaluate the plant response to these events.

For the initiators identified, time intervals from alarm to loss of shutdown margin were calculated to determine the length of time available for operator response.

These calculations depended on dilution flowrates, boron concentrations, and Reactor Coolant System volumes specific to s

the event and mode of operation.

The technique modeled-realistic plant conditions and responses, including both mechanical failure and human errors.

The analysis identified four events which were considered to be the most likely initiators:

1.

Domineralizer outlet isolation valve open during resin flushing.

2.

Valve 226 open following BTRS domineralizer flushing operation.

15.4.6-2 Amend. 17 7/85

P VEGP-ESAR-15 3.

Failure to secure chemical addition.

4.

Boric acid flow control valve (FV-110A) fails closed during make-up.

Initiator 4 was found to be the most limiting event for modes 3, j

4, and 5.

The parameters used in the calculation of time available for operator response are listed in table 15.4.6-1.

Conservative values of boron worth (pcm/ppe), as a function of RCS baron concentration, were assumed in the analysis.

j Since the active volumes considered are so small in cold shutdown with the reactor coolant loops drained, it was determined that the same. valves locked out in refueling would need to be locked out in cold shutdown when the reactor coolant loops are drained.

1 i

I 1

i Amend. 17 7/85 Amend. 30 12/86 15.4.6-2a Amend. 35 3/88

VEGP-FSAlt _.

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1 15.4.6-2b-Amend. 17 7/85

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VEGP-FSAR-15 i

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15.4.6.2.1.3 Dilution Durine Full Power Ooeration, Including Startuo.

i j

15.4.6.2.1.3.1 Dilution During Startup.

Conditions at startup E17 require the reactor to have available at least 1.30-percent Ak/k shutdown margin.

The maximum boron concentration.

required to' meet this shutdown margin is conservatively i

estimated to be 1704 ppa.

The following conditions are assumed for an uncontrolled baron dilution during startup:

A.

Dilution flow is assumed to be the combined capacity i

of the two primary water makeup pumps (approximately

~,

i 242 gal / min).

l B.

A minimum water volume (9757 ft ) in the reactor 8

coolant system is used.

This volume corresponds to the active volume of the RCS minus the pressurizar volume.

j.

15.4.'6.2.1.3.2 Dilution During Power Operation.

During power Il7 i

operation, the plant may be operated two ways, under manual t

operator control or under automatic Tavg/ rod control.

While the plant is in manual control, the dilution flow is assumed to

.be'a maximum of.242 gal / min, which is the combined capacity of the two primary water makeup pumps.

While in automatic control, the dilution flow is limited by the maximum letdown i

flow (approximately 125 gal / min).

. Conditions at power operation require the reactor to have available at least 1.30-percent Ak/k shutdown margin.

The maximum boron concentration required to meet this shutdown margin is very conservatively estimated to be 1704 ppa.

t

-15.4.6-3 Amend. 17 7/85

l I

VEGP-FSAR-15

, A. minimum water volume (9757 ft*) in the RCS is used.

This i

i j

volume corresponds to the active volume of the RCS minus the pressurizer volume.

5 l

15.4.6.2.2 Results J

4 The calculated sequence of events is shown in table 15.4.1-1.

i j

15.4.6.2.2.1 Dilution During Refuelin_g.

Dilution during 1

J refueling cannot occur due to administrative controls.

(See l

paragraph 15.4.6.2.1.1).

)

i 15.4.6.2.2.2 Dilution Durine Cold Shutdown.

For dilution i

during cold shutdown, the Technical Specifications provide the required shutdown margin as a function of RCS baron concentration.

The specified shutdown margin ensures that the operator has 15 min from the time of the high flux at shudown -

alarm to the total loss of shudown margin.

1 a

i 15.4.6.2.2.3 Dilution Durine Bot Standby and Hot Shutdown.

1 For dilution during hot standby and hot shutdown, the Technical

l Specifications provide the required shutdown margin as a function of RCS boron concentration.

The specified shutdown l

margin ensures that the operator has 15 min from the time of the l

i high flux at shutdown alarm to the total loss of shutdown margin.

4 i

l 15.4.6.2.2.4 Dilution Durine Startup.

In the event of an i

unplanned approach to criticality or dilution during power 1

escalation while in the startup mode, the operator is alerted to an unplanned dilution by a reactor trip at the power range neutron flux high, low setpoint.

After reactor trip there is at least 19.0 min for operator action prior to loss of shutdown i

margin.

i 15.4.6.2.2.5 Dilution Durine Power Operation.

During full-s power operation with the reactor in manual control, the-l operator is alerted to an uncontrolled dilution by an overtemperature'AT reactor trip.

At least 19.0 min are 1

5 available from the trip for operator action prior to loss of shutdown margin.

)

During full-power operation with the reactor in automatic control, the operator is alerted to an uncontrolled reactivity insertion by the rod insertion lisit alarms.

At least 36.8 min are available for operator action from the low-low rod insertion limit alara until a loss of shutdown margin occurs.

Amend. 17 7/85 I

Amend. 30 12/86 i

15.4.6-4 Amend. 35 3/88 i

i 70 i

VEGP-FSAR-15 15.4.6.3 Conclusions l 1~<

hheresultspresentedaboveshowthatadequatetimeisavailable for the operator to manually terminate the source of dilution 4

Following termination of the dilution flow, the operator can initiate reboration to recover the shutdown margin.

flow.

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Amend. I 11/83 15.4.6-5 Amend. 17

?/85

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VEGP-ESAR-15 TABLE 15.4.6-1 PARAMETERS Dilution Flowrates:

Initiator Flowrate (apa) i 1

63 i

2 1

120 3

3.5 4

130 Volumes:

Mode volume (ft' )

volume (cal) f 3, 4 9972 74593 i

Sa (filled).

5239 39188 J'

e.

1 1

s 0150V Amend. 17 7/85 Amend. 30 12/86 Amend. 35 3/88 4

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LEAR ONAATIONS E

M. ORKhn do laPt

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l UN,IT NO.

OA6 9 ATE t 0

/7/

t UNIT COOLDOWN TO COLD SMUTDOWN I

MANUAL SET 1.0 FURPOSE N0.

'A i

This procedure provides instructions for maintaining i

hot standb following reactor trip, maintaining hot standby fo loving reactor shutdown, taking the unit from het standby to cold shutdown.

Instructions are provided for maintaining conditions stable at points i

between.

2.0 PRECAUTIONS AND LIMITATIONS 2.1 PRECAUTIONS i

2.1.1 If this procedure is terminated prior to completion, j

the Unit Shift Supervisor (USS) should note the reason for the termination in the coussents section.

i 2.1.2 The Reactor Coolant System (RCS) pressure and temperature shall be maintained within the operating j

region of Figure 1.

l 2.1.3 Do not add positive reactivity by more than one controlled method at a time while the reactor is i

suberitical.

2.1.4 Whenever RCS temperature is above 160'F, at least one j.

RCF should be in operation.

Preferably Pump 4 to l

ensure best spray capability.

.a 2.1.5 The hydrogen concentration in the RCS must be reduced

~

to less than Sec/kg prior to opening any RCS component.

2.1.6 The boron concentration in the pressuriser should not be different from the RCS by more than 50 ppa.

Pressurizer Backup Heaters may be energized as i

necessary to equalize the boron concentration.

2.1.7 The Control Rod Drive Mechanism (CRDM) Cooling System shall be operating when RCS temperature is greater than or equal to 350'T or when any CRDM is energized.

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-C 9

l During)cooldown, all Main Steam Isolation Valvesshould 2.1.8 (MSIVs to allow uniform cooldown of all Reactor Coolant System (RCS) loops and Steam Generators (SGs).

Steam dump is j

the preferred method of heat removal.

l The Residual Heat Removal (RHR) Pump Suction Line 2.1.9 1

should not be isolated from the RCS unless there is a 4

steam bubble in the Pressurizer.

One Reactor Coolant Pump (RCP) should be running j

2.1.10 anytime RCS temperature is changed by more than 10*F in one hour.

]

Spray flow into the Pressurizer should not be initiated 2.1.11 if the temperature difference between the Pressurizar i

steam space and the spray fluid exceeds 125'F.

}

Before auxiliary spray is initiated with a temperature 2.1.12 difference between the pressuriser steam space and the spray fluid exceeding.320*F, notify the USS.

i l

(Technical Specification 5.7.1) i While in Hot Standby, feeding Steam Generators should i

2.1.13 be continuous to minimize thermal stresses on the L

Feedwater Nozzle.

Vacuum should be maintained on the Main Turbine 2.1.14 following unit shutdown until the Turbine coasts down unless an i

to approximately 662 rated speed (1200 rpm) emergency dictates rapid coastdown of the Turbine Rotor.

The Main Turbine should be kept on Turning Gear until 2.1.15 metal casing temperatures have returned to ambient.

Bearing lube oil circulation must also be maintained.

During periods of operation with the RCS level below 2.1.16 the Reactor Vessel Flange elevation (194 feet slavation), ongoing work activities should be closely i

scrutinized and any work activity ILaited that has the potential for reducing RCS inventory.

1 l

4 4

t 9

i

wx:: ae =o s.svision esca wo VEGP 12

-C 9

3 of 41 2.2 LIMITATIONS 2.2.1' The RCS pressure and temperature shall not exceed 425 psig and 350*F when open to the RHR system.

2.2.2 While in Modes 3 and 4 shutdown margin shall be greater than or equal to the limit specified in Technical Specification 3.1.1.2, Figure 3.1-1.

2.2.3 While in Mode 5, shutdown margin shall be greater than or apal to the limit specified in Technical Specification 3.1.1.2, Figure 3.1-2.

2.2.4 While in Mode 3, at least two RCS loops shall be in operation with the Reactor Trip Breakers closed and at least one in operation with the Reactor Trip Breakers open.

(Technical Specifications 3.4.1.2) 2.2.5 While in Mode 4 at least two RCS loops and/or RHR trains shall be operable and at least one of the RCS loops and/or RNR trains shall be in operation.

(Technical Specifications 3.4.1.3) 2.2.6 While in Mode 5 with the RCS loops filled, at least one RHR train shall be operable and in operation and either one additional RHR train operable or the secondary side water level of at least two steam generators shall be greater than 17% wide range.

(Technical Specification 3.4.1.4.1) 2.2.7 While in Mode 5 with the RCS loops not filled, at least two RHR : rains shall be operable and at least one RHR j

j train shall be in operation.

(Technical Specification 3.4.1.4.2) j_

1 2.2.8 While in Modes 4, 5, and 6 with the Reactor Vessel Head on, at least one of the following cold overpressure

{

protection systems shall be operable 4

l a.

Two PORVs with lift settings which do not exceed i

the limits established in Figure 1 b.

Two RHR suction Relief Valves each with a setpoint of 450 psig *31, or The RCS depressurized with an RCS vent capable of c.

relieving at least 670 gym water flow at 470 psig.

j-(Technical Specification 3.4.9.3)

I 2.2.9 WhileinModes5and6,atleastoneChar!1$bePump in i

the required boron injection flow path sh l

operable.

(Technical Specification 3.1.2.3)

" m*

l

.- - - - +

-w w

s--

4

^-

act.

/

navisioN 15 _Ts )-C 9

4 of 41 acom.4 ~o

'*ECP 2.2.10 The primary to secondary pressure differential shall not exceed 1600 paid or a secondary to primary pressure differential of 670 paid during unit operations or leak l

tests.

l 2.2.11 The maximum cooldown of the RCS shall be limited to 100*F in any one hour period.

(Technical Specification 3.4.9.1) j

)

2.2.12 The maximum cooldown of the pressurizer shall be limited to 200*F in any one hour period.

(Technical Specification 3.4.9.2)

The maximum temperature differential between auxiliary 1

l 2.2.13 spray water and pressurizer steam space is 625'F.

l (Technical Specification 3.4.9.2)

The temperature of both the primary and secondary 2.2.14 coolant in the Steam Generators shall be greater than i

70*F when the pressure of either coolant in the Steam i'

Generator is greater than.200 psig.

(Technical Specification 3.7.2)

While in Modes 3, 4 and 5, both channels of Source 2.2.15 Range Nuclear Instrumentation shall be operable.

(Technical Specifications Table 3.3 1, 6.8)

While in Modes 3, 4, and 5 at least one channel Source i

2.2.16 Range Nuclear Instrumentation should be selected to Recorder NR-45 and the CONTROL ROOM HI FLUX LEVEL AT l

SHUTDOWN alarm operable.

While in Modes 5 and 6, with the RCS level below 2.2.17 Reactor Vessel Flange elevation (194 feet elevation),

the RWST will be operable with a minimum volume of l

70,832 gallons (51 of instrument span) of water at a boron concentration between 2000 and 2200 ppm.

i 3.0 INITIAL CONDITIONS The reactor is shut down either following normal 3.1 shutdown or reactor trip with Shutdown Rods either i

i withdrawn or inserted.

RCS temperature is stabilized at no load Tavs under 3.2 control of the steam dumps in Steam Pressure mode or by operation of the Steam Generator Atmospheric Relief Valves.

l 3.3 RCS pressure is stable at normal operating pressure.

I l

l l

l i

eG0Cl;.EE NO LEvsow WAGE ho

'EGP 12

-C 9

5 e.,i 41 j

3.4 At least one RCP is operating.

)

3.5 Pressurizer level is at apsroximately or returning to the program level with eitner the Positive Displacement i

(PD) Pump or a Centrifugal Charging Pump (CCP) operating to supply normal charging and RCP sent

)

injection flow.

3.6 SG 1evels are at 45% to 55% NR level with Auxiliary Feedwater (AFW) operating.

3.7 The main Turbine is tripped s*J aither coasting down or on the Turning Gear.

4.0 INSTRUCTIONS NOTES This procedure is divided a.

into sections which permit either cooldown or maintaining stable conditions within a

^

specified mode.

Section E may be performed concurrently with Sections A B.C.D.

j i

b.

Aster'sk (*) steps beside INITIAL steps indicatus steps that generate additf or.a) j documents, i

This procedure is written using c.

Train A designations.

Train B component designations are shown in parenthesis, i

The sections of this procedure are:

A.

Hot Standby Following Reactor l

Shutdown or Trip.

i B.

Cooldown to not less than 350'F.

c.

Cooldown to not less than 205'F.

i D.

Cooldovu to Cold Shutdown (less

~

than 200*F).

E.

Secondary Plant Shutdown.

l l

l f

.ns ao i

0 6 or ei

'~

navassow lh-C moc we wo 9

VECP l

Hot Standby Following Reactor Shutdown or Trip 4

SECTION A:

OPERATING IN NOT STANDBY FOLLOWING PEACTOR SHU1,0WN OR A4.1 TRIP:

INITIALS A4.1.1 If this procedure has been entered from a reactor trip, then perform the following:

f INITIATE 10006-C, " Reactor Trip a.

(

1 Review",

i l

b.

If entering this procedure from SI termiastion, then perform j

11886, " Recovery From ESF Actuation",

If required, INITIATE STARTUP i

c.

of the Auxiliary Boiler per 1

13760-C, " Auxiliary Steam Boiler W

System".

NOTIFY Chemistry Department, 2

d.

If applicable ENSURE that TDAFW Pump has been stopped per 13610, j

" Auxiliary Feedwater System" and returned to STANDBY per 13610 AM*

j e

l/D l

Checklist 2.

/

u-e When Source Range channels e.

indication stabilise PLACE CONTROL R00H HI FLUX LEVEL AT i

SHUTDOWN alarm in operation by t

performing the following

(.

I.

(1)

NOTIFY IEC and RKSET the HI FLUX AT SHUTDOWN alarm j

setpoint per 24695 and i

24696, "N.I. Systen Source W

- Range Channel Calibration".

{

(2)

EHABLE THE HI FLUX AT SHUTDOWN alarm by placing the HIGH FLUX AT SHUTDOWN NORMAL / BLOCK f

i switches to the NORMAL, 1

g

$ 3 4%

i

a

AGE NO MCCE.8E No KEvisioN 7 of 41 VECP 1.

-C 9

l-INITIALS l

(3)

VERITY annunciator SOURCE RNG i

HI SHUTDOW FLUX ALARM BLOCKED llY i

ALB-10 B01 resets, l

i (4)

SELECT both channels of Source NRfeindicationonRecorder 1

Ran i

5 ANNOTATE chart to reflect channels selected, i

f.

CALCULATE SHUTDOW MARGIN per 14005, " Shutdown Margin i

Calculations",

j If necessary, BORATE the RCS per r

I' g.

13009, "CVCS heacter Makeup

((I,I' Contral System",

W l

h.

SHUT DOW the CVCS BTRS System by j

performing the followings j

(1)

PLACE the CVCS BTRS SELECTOR Switch HS-10351 in the OFF M

position, (2)

CLOSE the BTRS Domineralizer d

Flow Control HV-0387 to the FULLY CLOSED position,

,/f/1,,

f 1.

T.' RECT Chemistry to sample the RCS hydrogen, gas activity concentrations and PERFORM an RCS l

i i

Iodine sample analysis per the rl,j//

required frequencies of Technical

/ l, j

j j

Specifications Table 4.4-4, l

f Person Contacted

6. & b e v e DateJC 7 <T7 Time / W OO J.

MAXIMIZE CVCS letdown nucification flow rate per 13006

" Chemical

+

l And Volume Control System Startup MIN And Normal Operacion ',

l in m W KIDE Date Time i

~4 0 %

[. l 4 s u \\.'.5 %

) A ',, \\ \\. y 13 3%

pw j

D e s.

6 AGE No

&cCCE.4E No LEVl51oN VEGP 1.

-C 9

8 of 41 INITIALS k.

MONITOR Main Turbine coastdown, (1)

ENSURE that the Turning Gear y

i/

Motor Control Handswitch is Pg j

in AUT0/ PULL-TO-LOCK position, (2) t'han Turbine Rotor reaches zero speed, VERIFY all Lift Pumps, Turning Gear Oil Pumps ON and

/'

j Turning Gear engagement.

125[

1.

STOP both Heater Drain Pumps,

((b\\

STOP all but one Condensate Pump, m.

REDUCE in-service Condensate n.

Demineralizer Powdex Vessels as r.pplicable per 13616. " Condensate i,

Filter Domineralizer System",

PLACE the Condensate and Feedwater o.

System on Long cycle recirc per 13615. " Condensate And Feedwater Systems",

NOTIFY Chemistry to initiate p.

placing condensate and feedwater t/

into proper chemical wet layup, I

V If necessary,' SHUT DOWN all but one ii/NS q.

Circulating Water Pump, If necessary, SHUT DOWN all but one r.

River Makeup Pump and RECORD time

)/

in the Unit Control Log Book, ENSURE SG Blowdown Isolation Valves

[t23 s.

1-HV-7603A(B, C, D) open.

j

(-.'

A4.1*.2 If No-Load Tava cannot be maintained due to excessive steam demand, REDUCE steam demand by performing the following ENSURE MSR Heating Steam Supply

///?h[,-

a.

Valves HS-6015 and MS-6030 closed, b.

TRANSFER the Auxiliary Steam System per 13761, g to the Auxiliary Boiler steam suppi Auxiliary Steam System",

//

h

" AOE NO

$2CIh.,

LEvasioN g g gg INITIALS TRANSFER the Turbine Steam Seal c.

supply t.o the Auxiliary Steam Supply per 13825, " Turbine Steam Seal

\\

/

System",

d.

TRANSFER the SJAE steam supply to l

the Auxiliary Steam Supply per 13620 Wj

" Condenser Air Ejection. System",

If Main Generator is to be shut down e.

for more than two days, then to prevent overheating relay 360A, OPEN links TER 28, 29 and 30, located in Protectiva Relay Panel Bay 4, per 00306-C

" Temporary Jumper And I / " "~;p A

i Lifted Wira Control",

f.

If the Generator Regulator Panel (1328-P5-GRC) is to be de-energized for maintenance, l

then OPEN links TBR 56 and 57 and TBS 4 and 5 located in Protective Relay Panel Bay 4, per 00306-C,

" Temporary Jumper and Lifted Wire Control".

This will prevent tripping Lockout Relays 386 G9 and 4

A.

386 G10 which trip Generator output

'lU/-y/;j Breakers.

At the Main Transformer Control g.

Cabincts, de-energize the Transformer Oil Pumps and Tans per 13800, " Main Turbine Operation" 4/c' d Sub-subsection 4.3.1.

s A4.1.3 Either OPERATE unit systems as necessary to maintain the unit at Hot Standby, or PROCEED to either Section B to initiate unit cooldown or 12003-C

" Reactor Startup" to return to power.

-e END OF SECTION A 0!

At't..!

t. ** 0 e

- s p en re,h p, rejfe.. s's A!g,q t,

jf. n f j..., s. f,,,,

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. r.. r.,

7,,,,

,, n

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M js, ee;% e '$

L.W*

d' fre.e e.* n e

%f i" 'Ipe c.* t pH O ttt %

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usos no 0-10 of 4 Tao.:r vat wo reviso.

i..

VECP 12

-C 9

i*-

I SECTION B:

Cooldown to not less than 350' F NOTE

^

This section directs cooldown to 375'T or any. point between without crossing the boundary J

for Mode 4 at 350*F.

J i

B4.1 PREPARATION FOR UNIT C00LDOWN 1

INITIALS 84.1.1 If required to cooldown secondary systems, then INITIATE Section E of this procedure.

)

B4.1.2 If Condenser vacuum is being maintained, then INITIATE placing a steam blanket on Operation"per 13800, " Main Turbine Q

the MSR's l

i l

l B4.1.3 INITIATE pressurizer and RCS boron equali:stion by energizing Pressurizer L-v Backup Heaters.

f B4.1.4 MAXIMIZECVCSletdownpu}ification j

flowrate.

M N 'i f l date/ time

~

i B4.1.5 INITIATE Borating the RCS to the cold shutdown boron concentration per 13009,

,i "CVCS Reactor Makeup Control System".

j-If applicable, PERFORM 14835 "Borie Acid Injection Check Valve Cold Shutdown C-Inservice Test" during the boration.

i B4.1.6 DIRECT Chemistry to sample the RCS and w

C W1 Pressuriser boron concentration.

INSERT all Shutdown h

f 54.1.7 If withdrawn, fully inserted position.

i Banks to the a

7Tl B4.1.8 OPEN the Reactor Trip breakers.

s r

4 j ;

4

- 1. 9

~ _...

l.

HGE No l

'12h4" 0;octll.8E No O

12 or 41 Keys 54oN

-C 9

VEGP INITIALS

\\

l B4.1.9 If not currently in progress, INITIATE RCS gaseous activity degas i

by performing the follovtng:

l j

a.

ENSURE that the Pressurizer Steam Space Sample line is in l

operation by verifying that l

the PRZR S'1H SAMPLE IRC/ ORC Valves HV-3513/HV-3514 are t

MO

open, 4

b.

NOTIFY Chemistry to adjust the pressurizer steam space sample t't flow rate to maximum, A/M c.

While maintaining hydrogen cover gas, DEGAS the RCS by raising VCT gas purge flow rate to the Caseous waste Processing System to approximately 1.2 scfm using HIC-1094, as limited by the

+y/M A

Hydrogen Recombiners.

B4.1.10 When notified by Chemistry that the RCS gaseous activity has been reduced to an acceptable level, TRANSFER VCT cover gas to Nitrogen and INITIATE RCS Hydrogen degas per 13007, "VCT Gas yre/A

/2 Control And RCS Chemical Addition".

NOTE Prior to opening the RCS to containment the hydrogen concentration shall be less than 5 cc/kg.

B4.1.11 START both Containment Pre-access Filter CTB PREACCESS FLTR UNIT-1/2h E o 4 a m * ' #^' g"".

p Units usiN/2621. 4"C

2 FAN HS-26 date/ time B4.1.12 If it is planned to cool devn to Cold Shutdown, and if not perforced in the previous three months, COMPLETE 14748, Check Valve Shutdown Inservice N X All H3 < M / h V ( w M. W /.y / f

"; te s*

pAGE NO

8fI;.#E NO ag /:* io%

'.'E G P 1.

-C 9

12 of 41 l'

INITIALS 1

B4.2 RCS COOLDOWN TO 375'T B4.2.1 COMMENCE RCS/ Pressurizer pressure and temperature trending at 30 minute j

intervals using Data Sheet I and ERF (Technical Specification computer.

4.4.9.1) i

\\

Data taking and plotting may be suspended during holds in the i

cooldown if the duration is expected i

to exceed one hour.

l NOTE i'

t It is recommended that the i

RCS temperature be maintained between 75* F and 125' F less than pressurizer temperature.

4 (See Figure 1.)

4 CONMENCE the cooldown to 375'T and 540 B4.2.2 psig at a recommended rate of i

approximately 50'F per hour by performing

{

the following:

l i

REDUCE the number of operating RCPs a.

a to two per 13003, " Reactor Coolant eM Pump Operation",

F ps 4 and I are the preferred running pumps, 3

b.

INITIATE Pressurizer cooldown and f

4 depressurization by slowly opening

<,jJ~Fq i

the Pressurizer Spray valves, y

If necessary, selectively DE-ENERGIZE Pressurizar Back-up Heaters by alacing Control Switches to PULL-TO-Loct, CAUTION

~

RCS temperature and pressure shall be maintained within the acceptable operating region of Figure 1.

Slowly ADJUST the Steam Dump Controller I

L c.

setpo:.nt or if applicable the Atmospheric Relief Valves to initiate RCS cooldown.

([7 i

a, se

- ~

LAGE NJ pac::EC A Eeso V 'SCN VEGP 1

-C 9

13 of 41 i

INITIALS j

l B4.2.3 At approximately 2185 psig, OBSERVE PRZR PORY BLOCK VALVES HV-8000A and HV-80005 l

auto close.

i NOTE Depending on the rate of RCS cooldown and depressurization, 3

Step B4.2.5 may occur before 1

Step B4.2.4.

4 i

B4.2.4 At approximately 550*F RCS temperature PERFOM the following:

a VERITY status light LO LO TAVG TRAIN a.

A STEAM DUMP INT. F12 illuminated, l

BYPASS the LO LO TAVG interlock by b.

1 momentarily placing the Train A and B Steam Dump Interlock Selector Switches to the BYPASS INTERLOCK l

position.

If operating on Steam Dumps, then 4

VERIN Steam Dump Cooldown Valves PV-0507A,B and C are open by j-

,f observing ZLB-2 on QMCB, CAUTION i

If the RCS is allowed to pressurize above Pil and SG pressure is below 585 psig, 4

Safety Injection and Steam i

Line Isolation will occur.

1 B4.2.5 At approxLmately 1970 psis, manually BLOCK Pressuriser Pressure and Steam Line Pressure Safety Injection and Steam Line Pressure 1

Steam Line Isolation signals by performing 4

i the following:

4 It is is planned to cool down for a.

refueling, then PERFORM 14710

" Remote Shutdown Panel Transfer Switch And control Circuit 18 Month Surveillance Test" Data Sheets 3A and 3B in lieu of the following

substeps, b.

VERIFY Block Permissive Status Light PRZR LO PRESS SI BLOCK PERM P11 illuminates,

.w.,

~

a j

.. ~...

84GE NO LEyssioN 14 of 41

1. 0CECWENO 12hc 9

VEGP INITIALS

(

4 BLOCK the Low Pressurizer Pressure c.

Safety Injection signal using PRZR PRESS SI BLOCK / RESET A and B i

handswitches HS-40012 and 40013, 4

d.

OBSERVE Status Lights PRZR TRAIN A/B g'.f SI BLOCKED illuminated, BLOCK the Low Steam Line Pressure l

s.

SafetbSSSI/SLIBLbnalusingLOW T~h Injection si STM P K RESET j

hand witches HS-40068 and 40069, ts STMLINE ISO g

4 OBSERVEStatusLigDilluminated.

l f.

TRAIN A/B SI BLOC l

54.2.6

' CHECK that Pressurizer level is between g[

l 20% and 40%.

As RCS pressure lowers, OPEN additional B4.2.7 Letdown Orifice Isolation Valves and 4

ADJUST PIC-131 setpoint to maintain desired letdown flowrate.

During RCS depressurization, MAINTAIN all t

l 84.2.8 RCP seal injection flow rates between 8 and 13 gpa by adjusting the Charging Header Flow Controller HC-0182.

f 54.2.9 At approximately 950 psig I

{E Accumulators by perform ng t 8,

REMOVE TAG, UNLOCK and CLOSE the a.

Acc.ssulator Discharge Isolation Valve 480V MCC Breakers:

UNIT 1 UNIT 2 l

ACCUM-1 1ABE-19 2ABE-19 f

ACCUM-2 IBBC-19 2BBC-19 ACCUM-3 1ABC-19 2ABC-19 ACCUM-4 IBBE-19 2BBE-19 1

i 4

1 IOOk 4

(h ndHo

~

reveseo=

12hc eacccc6cawo 15 of 41 9

"EGP l

i' INITIALS b.

CLOSE the Accumulator Isolation Valves, J

N ACCUM-1 HV-8808A, O

ACCUM-2 HV-88088, ACCUM-3 HV-8808C, 48 ACCUM-4 HV-8808D.

VERIFY annunciators ACCUM TANK i

c.

1(2,3,4) ISO VLV 8808A(B,C,D)

)

NOT FULLY OPEN in alarm.

ALB06-A05,505,C05,D05, 1

d.

OPEN, LOCK and TAG the Accumulator i

Discharge Isolation Valves 480V MCC 2

Breakers, UNIT 1 UNIT 2 i

i ACCUM-1 1ABE-19 2ABE-19 i

T3 l'

IV i.

i ACCUM-2 1BBC-19 2BBC-19 i

N ACCUM-3 1ABC-19 2ABC-19 i

i 4

LY' d

l ACCUM-4 IBBE-19 2BBE-19 IV B4.2.10 When steam pressure falls too less than 550 psig, at the USS's discretion i

the Steam Generators may be supplied by the running Condensate Pump per Section E4.2 of this procedure.

4 4

$$ ^

^

_7 WAGt 40 FCCC[C,scE NO KEVIStoN VEGP 17 C

9 16 of 41 I

INITIALS B4.2.11 Either OPERATE unit systems as necessary to maintain RCS within the following parameter values or PROCEED to either Sec.cion C to continue the cooldown or 12002-C, " Unit Heatup to Normal Operating Temperature and Pressure" to commence a heatup.

i RCS temperature 375'T *10*F RCS pressure 540 psig *25 psig Pressurizer level at program level 1

END OF SECTION B t

j i

S

=

?.a*

r----------____________

~w-

AGE No

/

KEVl51oN 17 of 41 12Ls}-C pcCCE3.8E No 9

\\*EGP SECTION C:

Cooldown to not less than 205'T NOTE This section directs cooldown to 225'F or any point between without crossing the boundary for Mode 5.

PREPARATION FOR CONTINUING UNIT C00LDOWN.

C4.1 INIT_IALS f

If required to cooldown secondary systems C4.1.1 and break condenser vacuum, then INITIATE SECTION E of this procedure.

CAUTION Maintain pressurizer cold calibration level greater

'than 17Z.

l l

C4.1.2 If it is planned to cool down to cold shutdown, then ALLOW pressurizer i

level to rise during the cooldown to not greater than 80% cold calibrate.

COMMENCE RCS/ Pressurizer pressure and j

C4.1.3 temperature trending at 30 minutes intervals using Data Sheet 1 l

and ERF computer.

(Technical l

Specif :a. tion 4.4.9.1)

Plotting may be suspended during l

holds in the cooldown if the duration is expected to exceed one i

l hour.

i l

i i

i 1

i

~

Doo t".GE NO r;g y 540 N

]

PAGE NO VEGP 12 W -C 9

18 of 41 INITIALS t

C4.2 RCS C00LDOWN TO 225'F.

NOTE It is recommended that the RCS tenerature be i

maintained between 75'F and 125'T less than pressurizer temperature.

(See Figure 1.)

C4.2.1 COMMENCE the cooldown to 225'T and 250 psig at a recommended rate nf approximately 50 F.per hour by performing the following:

I I

a.

CONTINUE the pressurizer cooldown and depressurization by slowly opening

/2h/

the Pressurizar Spray Valves, If necessary. selectively DE-ENERGIZE Pressurizar Backup Heaters by placing Control Switches to 1

i PULL-TO-LOCK, CAUTION l

RCS temperature and pressure shall be maintained within i

the acceptable operating region of Figure 1.

b.

SidwIy ADJUST the Steam Dump controller Setpoint or if applicable the Atmospheric Relief Valves to 254' initiate RCS cooldown.

C4.2.2 If it is planned to cool down for refueling,UEST confirmation fromthen prior to reaching i

350'F. HQ Engineering /Haintenance that actions have been taken to preclude Reactor j

Vessel Seismic Tie Rod Binding.

5 C4.2.3 Prior to reaching 350*F. NOTIFY to isolate PERMS CVCS 48E ChemiserkonitorRE-48000.

Letdown l

i i

4 k$

e

~

- -,,,,-.- - =

i.

G AGE No levis @N O

PaoCEcuaE No 120hc 2'

r '2 9

VEGP 1

INITIALS j

j C4.2.4 Prior to reaching 350*F, PLACE the Cold Overpressure Protection System (COPS) in operation by performing the following:

a.

If not performed in the previous three months. PERFORM 14860, "PORV Cold Shutdown Inservice i

l Test",

b.

ARM the A and B COPS by placing the PRZR PORY BLOCK VLV COLD l

OVF'JRESSURE CNTL handswitches H3-8000C and 8000H to the ARM F"

position,

}

c.

VERIFY the following annunciators 4

alarmed upon arming COMS:

A COLD OP ACTU VLV HV-8000A NOT M

FULL OPEN (ALB12 E06),

j B COLD OP ACTU VLV HV-80005 NOT g

i i

FULL OPEN (ALB12 F06),

d.

ENSURE PRZR PORVs PV-455A and 1-PV-456A are closed and the M

l handswitches in AUTO, e.

ENSURE OPEN PRZR PORV BLOCK M

i Valves HV-8000A and 80005 l

NOTE l

Step f satisfies Technical l

Specification surveillance 4.4.9.3.1.c f

f.

VERITY the following annunciators reset:

A COLD OF ACTU VLV HV-8000A NOT Iy FULL OFEN (ALB12 E06),

j B COLD OP ACTU VLV HV-80005 NOT

//Y FULL OPEN (ALB12 F06).

C4.2.5 At 350'F, LOG' time and date of entry into Book.

Mode 4 in the Unit Control Log /M /l.M0

}/V ja4 date/ time 1

4

%.0%

i

--...,m.

i 84GE NO PAOCEhut N06 q

Evl& ION 20 of 41 VEGP 12CgC 9

4 INITIALS l

C4.2.6 Within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months af ter entering Mode 4 and prior to reaching 325'T PERFORM the l

following:

RACK OUT and TAG both safety 1

a.

Injection Pump Breakers, i

UNIT 1 UNIT 2 SI PHP-A 1AA02-16 2AA02-16 Th I

SI PHP-B 1BA03-17 25A03-17 TB NOTE f

AFWAS should be defeated to the SG B)ewdown Valves, Sample i

Valves and MDAFW Ptamp Discharge Valves to accomanodate MFP activities and/or SG draining /

i filling operations without J

resulting in impacting those i

activities.

l b.

At the USS's discretion, REMOVE and TAG the following fuses:

(1)

Train A i

(a)

Auxiliary Relay Panel -

Fuse Block (Allows full use of SG Blowdown valves),

UNIT 1 UNIT 2 f

'f[-

1ACPAR6-FU-2 2ACPAR6-FU-2 i

fr m3 4 Tyyd

*4 /

< /*. e c. e.

..o /o,23 T-7 w

S i

(b)

Auxiliary Relay Panel -

Fuse Block (Idibits feed pump trip rignal to d

initiate AFWAS),

4 3

UNIT 1 UNIT 2 1NCPAR-2-FU-4 2NCPAR-2-FU-4 78 i

Armsf 4 I*ftesy Lv W,,

t. q,,

tM41 e

n.-

_. n actno me t.as no rx navesson VECP 12'J -C 9

21 of 41 INITIALS (2)

Train B (a)

Auxiliary Relay Panel -

Fuse Block (Allows full use of SG Blowdown valves).

UNIT 1 UNIT 2 IBCPAR7-FU-6 2BCPAR7-FU-6

...... s... i.... u.,,,, 3

_O I

IV l

(b)

Auxiliary Relay Panel -

1 Fuse Block -(Inhibits feed pump trip signal to initiate AFWAS),

UNIT 1 UNIT 2 INCPAR-4-FU-1 2NCPAR-4-FU-1 n - ~ J. +

r.,,, 4

,pg

^

I ss 3:3 zy i

c.

PLACE standby MDAW Pumps handswitch i

in PULL-TO-LOCK.

i d.

If the TDAW Pump is not being i

utilized, CLOSE HV-5122, 5125, 5127 and 5120.

l.8/

i a

e

- 1eet

>w,

EEd.Cf No MEvissoN FAGE No VEGP 1

6-C 9

22 of 41 INITIALS C4.2.7 When the RCS pressure is less than 377 psig, and RCS temperature is less than 340 F. PLACE at least one RNR Train in operation per,1,3011. " Residual Heat 8

Removal System a.

OPERATE RHR HX Outlet Valves HV-0606(0607) and Bypass Valves FV-0618(0619) to control RCS temperature as necessary and RHR flow at a minimum total flow of 3000 spa, b.

If applicable, PERFORM 14896,

)( Mh "ECCS Check Valve Cold Shutdown Inservice Test",

c.

ENSURE RHR Suction Isolation surveillance is initiated each shift per 14000

" Shift And Daily Surveillance Logs".

CAUTION I

While in Mode 5 with the Reactor Coolant Loops filled, with 1 RHR Train inoperable, the secondary side water level of at least two Steam Generators shall be greater than 17% WR.

C4.2.8 If desired, REDUCE the number of operating RCPs to one per 13003, " Reactor Coolant 8g Pump Operation".

Pump 4 is the preferred running pump to ensure best spray capability.

C4.2.9 When SG pressure falls to 25 paig INITIATE aligning Nitrogen to the SG's per 13601, " Steam Generator And Main Steam System Operation" with regulators set at 2 to 5 pais.

I C4.2.10 If it is intended to perform maintenance on the RAT's during the outage, then NOTIFY Maintenance to initiate work TransformerandUAh'throughtheMain M

towards backfeedin s.

d

~

Mobil 5 A ~ i c.

Q ce i g

.A

.g' 4 ug oAy %s su \\ i-m"'

F % t.

C L-y

% c, b_.

p i.jul36

WoCEi.rf E No CEVisioN PAGE NO VEGP 1

-C 9

23 of 41 INITIALS C4.2.11 Either OFERATE unit systems as necessary to maintain RCS within the following parameter values or PROCEED to either Section D to continue the cooldown or 12001-C, " Unit Heatup t.o Hot Shutdown" to commence a heatup.

CAUTION Ensure running RCP seal differential pressure is maintained greater than 200 psid.

RCS temperature 225 F *10*F RCS pressure 250 psig *25 psig END OF SECTION C i

1 j

i 4

l l

i i

e i

)

- )4 8 9

~

m

- GE No k

1. oCEDW-E NO fifYlSioN 24 of 41 j.*.

~.

VEGP 1

6-C 9

SECTION D Cooldown to Cold Shutdown l

(less than 200*F).

NOTE This section directs cooldown t

to Mode 5 and maintains i

tem >erature between 130*F and l

80*?.

D4.1 PREPARATION FOR CONTINUING UNIT COOLDOWN l

INITIALS D4.1.1 If required to cool down secondary systems and break condenser vacuum, then INITIATE Section E of this procedure.

l D4.1.2 COMMENCE RCS/Pressuriser pressure and temperature trending at 30 minute intervals using Data Sheet 1 and ERF i

Computer.

(Technical Speciff cation 1

4.4.9.1)

Plotting may be suspended during holds in the cooldown if the duration is expected to exceed one hour.

ls l

D4.1.3 ENSURE RHR letdown is in operation with 4.8 V flow rate greater than or equal to 75 spm.

D4.2 RCS COOLDOWN TO BETWEEN 130*F and 80*F I

D4.2.1 COMMENCE the cooldown at a recommended rate of approximately 50*F per hour by perfor. sing the followings i

f a.

Slowly ADJUST the RHR Outlet Valves HV 0606(0607) to reduce RCS

//V temperature, l

CAUTION Ensure running RCP seal differential pressure is maintained greater than 200 paid.

4 b.

MAINTAIN Pressurizer pressure at 250 by selective use of

/fV psig, *25'psig,kup Heaters.

Pressurizar Bac mest

~

TN.'.

accac6cm ao lb]6-C

!csvis.6n h

25 of 41 act no I

VEGP 9

I INITIALS D4.2.2 At 200*F, LOG time and date of' entry into Mode 5 in the Unit Control Log Book.

4A, 172 4 Nie9/1Y j

time /date i

D4.2.3 RACK OUT and TAG the Containment Spray pump breakers.

f UNIT 1 UNIT 2 CS PMP A 1AA02-14 2AA02-14 d

i, CS PHP B IBA03-14 2BA03-14 d

)

i D4.2.4 As directed by the USS, PLACE the Conesinment Pre-access Purge System Purge System"per 13125. " Containment in operation i

D4.2.5 To facilitate personnel ingress and r

j egress, during cold shutdown, NOTIFY Maintenance to bypass the Containment Personnel Lock Interlock System.

i i

If desired the Containment Equipment Hatch Missile Shield may be moved at this time.

D4.2.6 NOTIFY Work Planning Group to schedule and initiate mode dependent Fire M/b #,r Protection Surveillances.

8 l

D4.2.7 When the RCS temperature is less than 140*F, PERFORM the following:

t INSERT all Shutdown If withdrawn, fully inserted position.

g a.

Banks to the Mk b.

OPEN the Reactor Trip Breakers, c.

STOP the CRDH Cooling Fans using the following handswitches:

CRDM UNIT - FAN 1 HS-12273A, CRDh UNIT - FAN 2 HS-12274A, CRDM UNIT - FAN 3 HS-12275A,

--l f,-

CRDM UNIT - FAN 4 HS-12276A.

rd_L d.

If it is intended to remain in cold PLACE the SG' greater than 4 days, then shutdown for i

s in wat layup per 13601, l

" Steam Generator and Main Steam System f IvL Operation".

j g

1

~

C 26 of 41 "CCC*yggy' 1h-c o

1 -

INITIALS NOTE i

The RCP(s) shall be run for one or more hours after reaching 1

the desired RCS temperature plateau to enhance SG and RCS 2[h/

temperature equalization.

D4.2.8 When RCS temperature is less than 110*F, the remaining RCPs may be stopped per Ip, 13003, " Reactor Coolant Pump h eration".

2 D4.2.9 If it is desired to collapse the pressurizar bubble and cooldown the pressurizar,.then PERFORM the following:

i i

a.

ENSURE all CVCS Letdown Orifices are j

in operation, CAUTION Expect rapid pressuriser pressure rise with charging i

flow greater than letdown j

flow at the point of going solid.

Be prepared to reduce l

charging flow or raise letdown 3

flow to prevent extreme l

pressure fluctuations.

4 b.

RAISE pressurizer level by raising chars ng flow rate and/or lowering RHR 1 tdown flow rate, jV When the pressurizer is solid as c.

indicated by rising RCS pressure or if PIC-131 is in A M rising letdown i

flow rate, then PERFORM the following:

(1)

BALANCE charging and letdown flow rates using HV-0128 l

and/or P1C-131 to maintain RCS pressure at 250 psig *25 psig, st/h' 4

i i

NOk 4

8

NGL ido XOCEME NO kgytsON 27 of 41 VECP I m 6-C 9-i i

INITIALS 1'

1 NOTE i,

i Charging flow may remain greater ther. letdown flow as a result of coolant contraction during the l

co01down.

I l

(2)

Charging /RHR letdown flow rate should be adjusted so that RHR I

letdown purification flow is i

maintained greater than or equal

/./V i

to 75 spa, l

(3)

OPEN Pressurizar Auxiliary Spray

[TY, 4

valve HV-8145

\\

i (a)

INITIATE AUX SPRAY /PRER j

DELTA-T surveillance per 14915 "Special conditions Surveillance Logs",

l (Technical Specification I

( DS 4.4.9.2),

(b)

If pressurir,ar auxiliary i

i spray water delta-T exceeds i

320 F, then LOG the spray i

valve operation in the Unit Control Log and NOTIFY Engineering to log the cycle per 50040-C. " Component Cyclic or Transient Limits".

Ui a

i l

(4)

CLOSE the open Charging Isolation Valve MV-8146 or HV-8147, ih (5)

Continue CHARGING through the pressuriser auxiliary spray line until pressuriser steam space

,s temperature is less than 190*F.

I D' i

i D4.2.10 MAINTAIN RC3 tem >erature between 130*F and 80'F using RiR HX Outlet Valves

/ (%

HV-0606(0607).

7 NOTIFY Engineering to log the unit

,3

_tw*

cooldown per 50040-C, " Component CA J

Cyclic or Transient Limits '.

h)

!)

U n J.M t it Et06 t0e m.r0(-

tomi rirO so.us u GM\\

I

E H84

_ w ;

i

M 44---+-

e

._.as aa4 a-,.e,a

%4

..ma

.,um,__a

_a a..mam--um

,m...

.m.-

h 28 of 41

Y'EN 12b-C 9

MITIA!.S CAUTION Ensure all RCP's are shutdown.

D4.2.11 If it is desired to depressurize the RCS, then PERFORM the following l

a.

INITIATE Lowering RCS pressure to i

atmospheric (50 peig as indicated on PI-408, 418, 428 or 438) using letdown pressure control PIC-131,

[7'J.

7 i

b.

When RCS pressure reaches 100 psig (150 psig as indicated on PI-408, 418, 428, 438), CLOSE all RCP Seal Leakoff Isolation valves BV-8141A, B, C, D, (h.

c.

ENSURE PRT nitrogen pressure is

[O,>

maintained greater than 0.5 psig.

i NOTE SI Pap Cold Leg Isolation Valves are closed to preclude inadvertent draining of RWST to the RCS while the RCS is depressurized and partially drained.

j D4.2.12 ISOLATt the Safety Inbection Cold legs by performing the follow:.ng a.

CLOSE 81 PHP-A TO COLD LEG ISO VLV HV-8821A,

/2h b.

CLOSE SI PHP-3 TO COLD LEG 180 VLV '

NV-88213,

/A e.

OPEN and TAG the followina SI Cold Leg Isolation Valves HCC Ereakers:

UNIT 1 UNIT 2 (1)

SI PHP-A TO COLD LEG 150 VLV HV-8821A, 1ABD-15 2ABD-15

[kk y (2) 81 PMP-B TO COLD LEG 150 VLV HV-88218.

185D-15 2BBD-15

/'Os

- lee.

7 1

h 29 of 1

YEN 12$.C 9

j INITIALS 1

cat! TION 1

Frior to opening the RCS to the containment atmosphere, the RCS hydrogen concentration shall be 3

less than 5 cc/kg.

D4.2.13 When required INITIATE RC5 draining by performing the following:

i 1

a.

If it is intended to drain down to perfora maintenance on Reactor Head, 80's or RCP seals, then the following j

RCS level controls should be placed into effect:

l (1)

If it is intended to operate at one foot above mid-nozzle level, the preferred RNR configuration is one train operating with a flow of 3000 N

i i

spa, (2)

If it is intended to operate i

at one foot above mid-nozzle i

level, a miniaua of two incore

{

i thermocouples should be available during periods where k,

the Reactor Head is installed, ce r

(3)

IEC should be notified to install temporary remote RCS level monitoring in the Na Control Room.

(4)

Tyson tube watch is required any time the RCS level is i

be:ma changed while the RCS level La below 171 (approximately 207 feet i

elevation) pressuriser level, 3k 3

(5)

Periodic comparison checks should be made every 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months between the control Room Temporary RCS Level Men'. tors Af 4

and the Tyson tube.

(6)

The Control Room Monitors should agree within 2 percent of scale with the Tyson tube.

E

-=s

" ea se

' tysseose PAat too l

e

- C4EDu-t seo A

c 9'

.e, 30 et 41 4 -

VEGP 1

1 INITIALS (7)

Two out of three Level Monitors must agree before draining RCS i

below the top of the hot leg i

(188 feet 3 inches),

i 4

(8)

If neither control Room RCS l

Level Monitor is available.

then a continuous Tyson tube i

J i

watch should be established while RC8 level is below 171 f

pressuriser level.

87" i

' (9)

While operating with 8 team i

Generator Nossle Dans installed.

ENSURE one Safety Injection Pump i

is capable of be h g racked in l

and operated if needed.

(10) While-level is in the region of the hot legs. TREND RHR i

parameters on ERF for ea %

rly detection of possible RNA Fum i

degradation due to vortexing.p i

(11) Minimum RCS level is one foot above mid-nossle (188 feet 0 inches elevation) excet for l

Steam Generator burping during initial drain down.

For effective 80 tube draining. RCS i

i i

level should be lowered to 187 feet 6 inches.

Upn completion of 80 burping RAISE RCS level to 188 feet E inches and MAINTAIN at this level

.1 /g thereafter.

VI i

(12) INITIATE drainig the RCS per 2

13005. " Reactor Coolant System Draining".

. P' i

e 1

- ** )4 8 4 m

-w.-v

-i.

m

PJt0Cg;.e( #4

~

7g5 M

4ct 880 INITIALS D4.2.14 If it is intended en drain the RCS to less than 252 cold calibrate pressurizer level, then prior to reaching 25I ISOLATE potential dilution flow paths by performing the following:

a.

CLOSE, LOCK and TAG the following

)

valves

)

(1)

UNIT 1:

CVCS ISOLATION RMW TO BA BLEND, 1-1208-U4-175 JIls UNIT 2:

CVCS ISOLATION RMW TO BA BLEND, N!A 2-1208-U4-175 (2)

UNIT 1:

CVCS ISOLATION RMW TO CVCS 1-1208-U4-1f7 Ji.l-UNIT 2:

CVCS ISOLATION RMW TO CVCS 2-1208-U4-1f7 A)!4 b.

ENSURE CLOSED, LOCKED and TA0GED the following valves (1)

UNIT 1:

CVCS OUTLET CHEM MIXING TK, 1-1208-U4-181 I,h i

UNIT 2:

CVCS OUTLET CHEM MIXING TK, 2-1208-U4-181 Mr)L4 l

(2)

UNIT 1:

CVCS SUPPLY RHW i

TO CHEM MIXING TK, s

1-1208-U4-176 sOA

.i UNIT 2:

CVCS SUPPLY RHW TO CHEM MIXING TK, d,i 2-1208-U4-176 i

i 4

l 80 Hs,

___y w

m m

[

l.

Pact.E:.tf No LEYlS40N AaE NO VEGP 1

-C 9

W 32 of 41 INITIALS I

(3)

UNIT 1:

CVCS FLUSH RMW TO TRN A EMERG l

l BORATION.

J

~

1-1208-U4-183 UNIT 2:

CVCS FLUSH RMW l

TO TRN A EMERG

BORATION, 2-1208-U4-183 NO (4)

UNIT 1:

RMWST TO BTRS ISO, 1-1208-U6-226 Y2 UNIT 2:

RMWST TO BTRS 150, 2-1208-U6-226 M%

makeup to the VCT by When necessary, followings c.

performing the (1)

OPEN RWST TO CCP A & B SUCTION Valves LV-0112D and LV-0112E, (2)

CLOSE VCT CUTLET ISOLATIONS, LV-01128 and LV-0112C, (3)

ENSURE Letdown to VCT or Hold-up Tank Valve LV-0112A is in the I

VCT position, I

1 (4)

When VCT level has been returned OPEN LV-01128 and

.to normal, hen CLOSE LV-0112D LV-0112C t and LV-0112E.

D4.2.15 OPERATE unit systems as necessary to maintain the above conditions, a.

If required to break condenser vacuum, then PROCEED to Section E.

b.

If it is intended to proceed to Mode 6, then Go to 12007-C,

" Refueling Entry",

If it is intended to commence unit c.

heat up, then Go to 12001-C. " Unit Heatup to Hot Shutdown".

END OF SECTION D

m o

}+

PAGE NO pacCE*.aE N3 KEvtSION j

'.*EG P 1 no6-C 9

33 of 41 l

SECTION E.

Secondary Plant Shutdown NOTE 1

I This section directs secondary plant activities during unit j

shutdown and can be used in i

coniunction with primary system d

i cool.down operatiens.

l C

The subsections of this section are:

)

i E4.1 Transfer From Steam Dumps to Atmospheric Relief valves.

l E4.2 Feeding Steam Generators With Condensate Pump.

J E4.3 Breaking Condenser Vacuum.

l E4.4 Secondary Systems activities.

E4.1 TRANSFER FROM STEAM DUMPS TO ATMOSPHERIC RELIEF VALVES 1

INITIALS i

E4.1.1 TRANSFER to the SG Atmospheric Relief Valves by performing the following:

Slowly OPEN each atmospheric g.

a.

relte;. while verifying a reduced l

steam dump demand signal on 1

/

l UI-507, vIV

/

l b.

VERIFY that the Steam Dump Control Valves close if PIC-507 4

is in AUTO or if operating in MANUAL, slowly CLOSE the

(

i Steam Dump control Valves 1

while opening each atmospheric

\\/ A

relief, l

c.

When all Steam Dump Control n

Valves are closed ENSURE l

PIC-507 is in MANUAL, d.

BALANCE the positions of each

/'

i if atmospheric relief while d

I maintaining Tavg as desired.

\\

i i

$ $ Ok

-s nysuon NGL h; VECP 6-C 9

34 of 41

~

INITIALS i

E4.2 FEEDING STEAM GENERATORS WITH CONDENSATE PUMP E4.2.1 At the USS's discretion, INITIATE feeding Steam Generators with the running Condensate Pump by performing the following:

i VERIFY SG pressure is less than

, ll A l

a.

I 550 psig, M/i'P i

b VERIFY that lube oil pressure to 4

j the reset HFP and MFP Turbine Fearings is 10 to 12 psig by local AII\\

indications.

4 c.

OPEN the reset HFP Discharge Valve by placing the Control Switch in OPEN-PULL-TO-LOCK at the Main i

j Control Panel QHCB:

Mt l

SGFP A HS-5208, l

SGFP B HS-5209.

d.

If not previously performed, RESET l

both trains of Feedwater Isolation k) hh f,

(1)

HS-40049 for Train A, (2)

HS-40050 for Train B.

k)I A k) i4 e.

OPEN all BFIV's, l

f.

CONTINUE maintaining de# m d SG

)

j level utilizing the BFEV's.

U i

Is i

k p

e= O$

~

SCOst:,.&E NO rgy 5 DON

/" \\

> AGE 8vo VEGP 1

6-C 9

U 35 of 41

+

\\

INITIALS i

E4.3 BREAKING CONDENSER VACUUM E4.3.1 If necessary, TRANSFER the Auxiliary I

Steam System steam supply to che Auxiliary Boiler per 13761, " Auxiliary

/

Steam System".

s E4.3.2 TRANSFER the Turbine Steam Seal supply esi System,17 per 13825, Steam Supp g

to the Auxiliar

" Turbine Steam l

E4.3.3 TRANSFER the SJAE steam supply to the I

i Auxiliary Steam Supply per 13620, 1

" Condenser Air Ejection System".

V)

E4.3.4 CLOSE the MSIVs and Bypasses, t

CAUTION i

j Breaking condenser vacuum will result in a MFFT Low t

Vac Trip.

If AFWAS has not been defeated, then both r

MFPs tripped will result in l

a AFWAS initiation.

1 t

a f

E4.3.5 PLACE the standby MDAFW Pump (s)

/.D)

Handswitches in PULL-TO-LOCK.

i E4.3.6 BREAK condenser vacuum and SHUT DOWN the Steam Jet Air Ejectors and the Condenser Vacuum Pumps per 13620,

" Condenser Air Ejection System".

E4.3.7 PERFORM the following to reset the AFVAS signal:

i RESET the AFWAS by resetting one a.

MFPT Low Vacuum Trip by j

momentarily placing the MFPT-A(B) i VAC TRIP BYPASS Handswitch to j

RESET position and MFPT A(B)

TRIP M ET HS-3169 (3170) to the l/A i

h/D 1

RESET position, b.

If running a MDAFW Pump, then THROITLE the AFW Flow Control Valves to the pre-initiation Al//

IUI FI flow rate, i

l

". H ei

noo o

..o o.,

. 3acc1:. 5po, g

INITIALS If applicable, ENSURE the SG c.

Blowdown Isolation Valves M/A MV-7603A(B,C,D) open.

E4.3.8 After the condenser pressure reaches atmospheric, SHUT DOJN the Turbine Steam Seal System"per 13825, " Turbine steam Seal System

[b5 E4.3.9 MAINTAIN the main Turbine and MFFTs on Turning Gear per 13800, 'hin Turbine Operation" and 13615

" Condensate and Feedvater Systems".

E4.4 SECONDARY SYSTEM ACTIVITIES E4.4.1 If condensate and feedwater cleanup is not anticipated, then when condensate and feedwater metal tem>eratures are less than 200*F, SHUT DOWN tie Condensate and And Feedwater Systems,1,3615. Condensate Feedwater System per (ED E4.4.2 NOTIFY Chemistry and SHUT DOWN the Condensate Filter Domineralizar System ber13616,"CondensateFilter b

emineralizar System".

E4.4.3 If the secondary outage is planned to exceed 10 days, then PERFORM the following:

When condensate and feedwater metal a.

tangerature is between 90*F and 200 F, C9 ORDINATE with Chemistry and FLACE the Feedwater Heaters in wet

[h5 i

i

layup, i

b.

When Turbine metal temperatures reach ambient, REMOVE Turbine from Turning Gear per 13800

" Main

@4g

+

l Turbine Operation".

(

During the unit outage, once a week

c.

PLACE the Turbine or Turning Gear for 4 to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

l

LEYlf [N GAGE NO l

VECP L306-C 9(

37 of 41 WOCEDUCE No A

t INITIALS E4.4.4 If required, PLACE a steam blanket on the MSRs per 13800, " Main Oh Turbine Operation".

l l

E4.4.5 If required, for condenser Waterbox or Circulating Water System maintenance, SHUT DOWN the Circulating Water System per 13724, " Circulating water System".

f If required for maintenance or inspection, then INITIATE draining i

of the Condenser Waterboxes per 13724, " Circulating Water System".

[]W E4.4.6 If main generator maintenance or inspection is planned, then INITIATE i

the main generator per purging" Generator Gas System".

c 13810 If hydrogen atmosphere is to be l

maintained, then MINIMIZE usage during the outage by reducing hydrogen pressure to not less l

than 5 psig.

E4.4.7 SHUT DOWN the Isophase Bus Duct Cooling System by performing the following:

At 480V AC SWGR NB03, OPEN l

a.

Isophase Bus Duct Heater Breaker kb l

UNIT 1:

1NB03-16 i

[h UNIT 2:

2NB03-16.

b.

At local Panel PLCB, STOP the running fan using HS-16550 for Fan No. 1 and/or HS-16551 for i

Fan No. 2

$l du

/W19l(( l70V$

Completed patt/ Time' signito e

[O */[*

6f2 Reviewed

]

Date/ Time p nature Comments cius-i

~

ast no GtvsseOn h6-c 0

35 or 't

>%i t;. s L **o 9

y VEGP

=

5.O REFERENCES 5.1 PROCEDURES 5.1.1 10006-C,

" Reactor Trip Review" 5.1.2 12001-C,

" Unit Heatup To Hot Shutdown" 5.1.3 12002-C,

" Unit Heatup To Normal Operating Temperature And Pressure" 5.1.4 12003-C,

" Reactor Startup" 5.1.5

13003,

" Reactor Coolant Pump Operation" 5.1.6

13005,

" Reactor Coolant System Draining" 5.1.7

13006,

" Chemical And Volume Control System Startup And Normal Operation" 5.1.8

13007, "VCT Gas Control And RCS Chemical Addition" 5.1.9

13009, "CVCS Reactor Makeup Control System" 5.1.10

13010,

" Boron Thermal Regeneration System" 5.1.11

13011,

." Residual Heat Removal System" 5.1.12

13120,

" Containment Building Cooling Systems' 5.1.13

13125,

" Containment Purge System" 5.1.14 13601

" Steam Generator And Main Steam System Operation" 5.1.15

13605,

" Steam Generator Blowdown Processing System" 5.1.16

13610,

" Auxiliary Feedwater System" 5.1.17 13615

" Condensate And Feedwater Systems" j

5.1.18

13616,

" Condensate Filter Domineralizer System" 5.1.19 13617 "Feedwater Hester Extraction, Vent And Drain System" i

5.1.20

13620,

" Condenser Air Ejection System"

)

5.1.21

13724,

" Circulating Water System" I

h$

S * ! E :.'E NO LEVISaON h

LAGE NO VEGP lau6-C 9

W 39 of 41 y

g 5.1.22

13760,

" Auxiliary Steam Boiler System" 5.1.23

13761,

" Auxiliary Steam System" 5.1.24

13800,

" Main Turbine Operation" 5.1.25

13810,

" Generator Cas System" 5.1.26

13825,

" Turbine Steam Seal System" 5.1.27

14000,

" Operations Shift and Daily Surveillance Logs" 5.1.28

14005,

" Shutdown Margin Calculations" 5.1.29

14748, "A W Check Valve Cold Shutdown Inservice Test" 5.1.30

14915, "Special Conditions Surveillance Logs" 5.1.31

24695, "N.I. System Source Range Char.nel Calibration" 5.1.32

24696, "N.I. System Source Range Channel Calibration" END OF PROCEDURE TEXT 4

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References:

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