Text

Forwards Corrected FSAR mark-up to Replace Attachment 2 Submitted W/Util 850920 Power Ascension Ltr
	ML20132B145
Person / Time
Site:	Hope Creek
Issue date:	09/23/1985
From:	Mittl R, Prestorf B; Public Service Enterprise Group
To:	Butler W; Office of Nuclear Reactor Regulation
References
	NUDOCS 8509260114
	Download: ML20132B145 (8)
	v • d • e

.

IUhliC b'fMCO I

ES i ls'0;""

80 Par k Plaza. Newar k, NJ 07101/ 201 130 8217 MAILING ADDRESS / P.O Bov 570, New-trk, NJ 07101 Robert L. Mitti General Manaty r Nucfear Assuranm and Regulation September 23, 1985 Director of Nuclear Reactor Regulation United States Nuclear Regulatory Commission 7920 Norfolk Avenue Bethesda, Maryland 20814 Attention:

Mr. Walter Butler, Chief Licensing Branch 2 Division of Licensing Gentlemen:

POWER ASCENSION PROGRAM PSAR CIIANGES IIOPE CREEK GENERATING STATION DOCKET NO. 50-354 PSE&G's September 20, 1985 Power Ascension letter included an incorrect FSAR markup (Attachment 2).

Please find attached to this letter the corrected FSAR markup which should be utilized in lieu of attachment 2 to the September 20, 1985 letter.

Very truly yours,

).L. YiH) w 6

8509260114 850923 PDR ADOCK 05000354 A

PDR Attachment C

D. ll. Wagner USNRC Licensing Project Manager 0

A.R. Blough

$O USNRC Senior Resident Inspector o i The Energy People r~m c.a a

)

e Sh Pg 50 Non/adp # 4 4 k y & m nu.w ofeud9 a/ odwe cw&

M m m a g n..: -i hs42k 4 f & jt/d, ['=h&cd spuykta & p x:# ~ m c M k yodyw w pnM op e d a s u C M s u<* v u c-s u D

~.

.I I

1

e

~.

d 1

I i

l 1

l l

1 l

l til Tut contat sons refer to ytant co=sation.

ITusvl tornu luxaTl l

l l

on r aq. 14.2%

l mo.l Tust isuts tvssssa.1 or 1 l 2 1 3 l es. I s 1 6 lumammTr l l!22)l I

l l

l (2) perform Test 5, timsms of 4 slowest contro!

l l

rode, to com)=ction with==sacted scrans i 1 l Cheatcal and andtomenical lx lx lx l

lu l

lx la I

i

! 2 l mastatsoa nea.w a6ent Ia ia la l

la l

l lx l

l (3) pymante system Tut came to be cumpleted l 3 i ruel to ss=,

lx l

l l

betma teet condtetone 1 and 3 1 4 l ruta core shutdown nargia lx l

l l

1 5 I control mod artvo lx ia Ix(2) lst2) gat 2) l g

l,12 ) l l

l 6 I sa.= Performance 1x l

l l

.mammanmaammam.

I o l Ime Performance l

lx la i

l l

1 o i 1. ries cattbration l

l se l a i

la 1

i la l

l ts) setween so a.s 9a percent thermal power, l t) l Arsee Caitbration l

lx la lx lx I

lx la l

l ans sur too sorcent core flow I 11 l Process caputer lx la Ix(33 l la l

Is I

i l

l 12 l aCzC l

lx lx l

l l

(6) nes rW amaut Capabstity 6 nectrc Pump l 13 I uPCs l

lx i l

la l

l l

aumbeck must have already boen empleted i 14 l selected Proces. Temp l

l emo l l

lx leEM l lchado l l

l 14 i Water Emel Ref log Temp l

lx l l

la l

l lx l

l (7) meactor power between 80 ans 90 percent l 15 I system xxpansson Ia lx la i

la l

l lx l

\\

l 16 i Tis m cartataty l

l l

l lx l

l la l

l to) neactor po==r antween 45 and 65 preent l 17 l core n rformance l

l lx la lx le.

la la l x l

l 1e i stema Prod.ceton l

l l

l l x l

to) meactor power between 75 a=s 90 percent l is I core twr-void seode assenmal l

l l

l 6e-la l

l 1

l 20 I truewe aegulator l

l lx lx la le>

la la l

l tion at mastaam power that wait not cease scr am l 21 l reed sye-sete tat changes i ia lx lx Ix lem la lx l

l t at I re s sye-toes tw meattas l

l l

1x(5 ) l l

(113 mrform between cut conditions 1 ans 3 1 21 I reeswater Pump Trty l

l l

lst6) g g

i at I nas rW am mt capabtitty l

l l

l at? 8 I I

(12) auctor po.er bet== a 40 and 55 preent i 22 i Turntae valve sww.111ance l l

l l

lx(88 l Ist'8 la( Ioll l

I 23 I nsiv runettomal Tut i

Ia lutHi mis 23l l

gg(12)g g

l g g 3,,,,cto, po,

n,t,,,,

,,,s o g p,,,,,

l l 23 l ns tv ru11 1m>1atton 1

i i

l l

la l

l l 24 l mettef Walves l

lx 11(20)lg ggt 203l l

lgt203l l

(14) setween test condat&ons 2 and 3 l 25 l Turbtaa Trap 6 Koes l

l l

l s( 15 3 l x( 1'Il l

lx11731 l

\\

\\ majectica l

l l

l (15) Cenerator loaJ rejection. within bypass l 26 l shutdown Outside CaC l

l l

lx l

l l

l valve capacity 1 27 l mectralataca riou Control l l

l lxII43l l

l al 38 ) l l

l l 2s l Rectro-one Pump Trap l

l l

l lI l

l lx l

l (16) meactor sewer between 60 and 80 percent l 2e I arr Trip-Two Pumpe

'l l

l l

lxII93l l

l l

l st core flow > 95 sorcent - t urt&me trip l 2n I a.carc systen Performance l l

l lx la team l

lx l

\\

l 2e l accirc Pump amback l

l l

l lx l

l l

,l l

(17) Lud r ej ec t ion i as I sectre sys cavatatson i

I l

l la l

I l

l l 30 l loss of of f stte rwr l

l lx l

I l

l l

tie) setween tue constesans s ans 6 l 31 i espe vibrataan I

ix la la la l

l la l

l l 29 l mectre riaw Calibration l

l l

l la l

I lx l

l (19) >5 0t poemr and _>95 core flow, and performed 1 32 l awas l

lx l l

l l

before Tur bia. Tr ty 6 loas aeject zon l n I ama I

i i

lx l

l 1

lat2til i

I 34 l oryweit 6 stem. T m et l

lx la l

lx I

l la l

l (2o) check saw set potate during major a ram i

I cooling i

I l

l 1

i l

l l

I tute on cas s u l 35 i Gaseous masteste l

l la l

l&

l l

la l

l GE NE R A TahG ST Af TON e

l 38 l sacs Performance l

l l

l lx l

l lx' l

l (21) Performed &aring cooldown from test f ehAL $AFETY ANALYass aE PORT l 40 l Conf irmatory in-Plant Test l l

l lx l

l l

l condition 6 rsAn 3/7 (22) The test maber correlates to rsam sect rom TEST SCHEDULE AND CONDailONS 14.2.12.3.s dwse a to the indicated test number.

r8GURE 142S Amendaiens to 06/35

HCGS FSAR 10/84 above the reactor pressure to simulate the-largest expected pipeline pressure drop.

This CST-testing is done to demonstrate general system operability and for makinggeaggcontrolleradjustments.

g Reactor vessel injection tests follow to complete the controller adjustments and to demonstrate automatic starting from a cold standby condition.

" Cold" is defined as a minimum 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months without any kind of RCIC operation.

Data will be taken to determine the RCIC -

high steam flow isolation trip setpoint while injecting at rated flow to the reactor vessel.

Af ter all final controller and system adjustments have been determined, a defined set of demonstration tests must be performed with that one set of adjustments.

Two consecutive reactor vessel injections starting from cold conditions in the automatic mode must satisfactorily be performed to demonstrate system reliability.

Following these tests, a set of CST injections are done to provide a benchmark for comparison with future surveillance tests.

After the auto start portion of'certain of the above tests is completed, and while the system is still i

l

' operating, small step disturbances in speed and flow command are input (in manual and automatic mode respectively) in order to demonstrate satisfactory-stability.

This is to be done at both' low (above minimum turbine speed) and near rated flow initial conditions to span the RCIC operating' range.

l A demonstration of extended operation of up to two hours (or until pump and turbine oil temperature is j;

stabilized) of continuous running at rated flow l

conditions is to be scheduled at a convenient time

["

l during the startup test program.

Depressing the manual initiation pushbutton is defined

!~

as automatic starting or automatic initiation of the l

RCIC system.

d.

Acceptance Criteria f

Level 1:

l l

1.

Following automatic initiation, the pump discharge i

flow must be' equal to or greater than rated flow l

as specified in Section 5.4.6 within the time specified by the GE startup test specification.

14.2-165 Amendment 8

HCGS FSAR~

5/85 l '.

By flow injection into a test line leading to the condensate storage tank (CST), and 2.

By flow injection directly into the reactor vessel.

The earlier set of CST injection tests consist of manual and automatic mode starts at 200 psig and near rated reactor pressure conditions.

The pump discharge pressure during these tests is throttled to be 100 psi above the reactor pressure to simulate the largest expected pipeline pressure drop.

This CST testing is done to demonstrate general system operability and for making anset controller adjustments.

a j

speesi l

Reactor vessel injection tests follow to complete the controller adjustments and to demonstrate automatic starting from a cold standby condition.

" Cold" is defined as a minimum 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months without any kind of HPCI operation.

Data will be taken to determine the HPCI high steam flow isolation trip setpoint while injecting at rated flow to the reactor vessel.

Depressing the manual initiation pushbutton is defined as automatic starting or automatic initiation of the HPCI system.

Af ter all final controller and system adjustments have -

been determined, a defined set of demonstration tests must be performed with that one set of adjustmen'ts.

Two consecutive reactor vessel injections starting from i

cold conditions in the automatic mode must satisfactorily be performed to demonstrate system reliability.

Following these tests, a set of CST injections are done to provide a benchmark for comparison with future surveillance tests.

After the auto start portion of certain of the above tests is completed, and while the system is still operating, small step disturbances in speed and flow command are input (in manual and automatic modes respectively) in order to demonstrate satisfactory.

+

stability.

This is to be done at both low (above minimum turbine speed) and near' rated flow initial conditions to span the HPCI operating range.

A continuous running test is to be scheduled at a convenient time.during.the startup test program.

This demonstration of extended operation should be for up to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months or until steady turbine and pump conditions are 14.2-167 Amendment 10

O i

HCGS FSAR 10/84 reached or until limits on plant operation are encountered, i

d.

Acceptance Criteria Level 1:

l 1.

Following automatic initiation, the pump discharge flow must be equal to or greater than the. rated flow, and within the time specified in Section 6.3.2.2.1.

2.

The HPCI turbine shall not isolate or trip during automatic or manual start tests.

Level 2:

l 1.

The speed and flow control loops are adjusted to meet the decay ratio specified in the GE startup test specification.

2.

The turbine gland seal system is capable of preventing steam leakage to the atmosphere.

3.

The delta-pressure setpoints for HPCI steam supply -

line high flow shall be calibrated to technical specification requirements using actual flow

'onditions.

c 4.

In order to provide overspeed and isolation trip avoidance margin, the transient start speed peaks must not exceed the requirements of the GE startup test specification.

14.2.12.3.14 Selected Process and Water Level Reference Leg Temperatures a.

Objectives establish low speed limits for the rec umps to avoid coolant temperature stratification or pressure vessel (RPV) bottom head region 14.2-168 Amendment 8

l

'l HCGS FSAR 10/84 l h To ensure that the measured bottom head drain l

temperature corresponds to bottom head coolant temperature during normal operation.

2. A.

To measure the reactor water level instrument l

l reference leg temperature and recalibrate the affected indicators if the measured temperature is different than expected.

i b.

Prerequisites The plant is in a hot standby condition.

System and test instrumentation have been installed.

c.

Test Method i

m M

ing initial heatup at hot standby conditions, the

.5

' bot drain line temperature and applicable reactor l

, paramet are monitored as the recirculation pump k $ g n} 3 of the low spe

{

speed is sl lowered to determine the proper setting t

A iter.

The parameters'above are I g y d also monitored duri g

w l

g.. N lanned recirculation pump trips e

} to determine if tempera stratification occurs in a

b u

b 4 the idle loop (s) and to ass hat idle loop-to-bulk gjg}4.

able J

E coolant temperature differentia e within Technical.

Specification limits prior to resta the pump (s).

a rsg M

,E 4 (

1 E I

The bottom drain line temperature and ap i

parameters are monitored when core flow is of d f rated flow.

j9 E3 s 0

l F g $ C,$ 6 0 A test is also performed at rated temperature and

h pressure under steady state conditions to verify that

,c t4 8 E,%

the reference leg temperature of the level instrumentation is the value assumed during initial calibration.

Recalibration will be performed if necessary.

d.

Acceptance Criteria i

Level 1:

l 1.

The reactor recirculation pumps shall not be started unless the loop to loop delta-temperatures and steam dome to bottom drain delta-temperatures

(

are within the technical specification limits.

14.2-169 Amendment 8 m

,,.m

llo ~~ A. NATURAL CIRCULATION

. 8. MINIMUM RECIRCULATION PUMP SPEE too.

C. ANALYTICAL LOWER LIMIT OF s

MASTER power FLOW CONTROL So ~~ D. ANALYTICAL UPPER LIMIT t.c.

OF MASTER POWER FLOW s

80 -- CONTROL T.c.es a

j f

T.c...

l

,.,~** / /

l p

d so -

A 7

W

/

/

l t

o So ~

4

~

9 4 o '"

~

u so -

e

/Nr...

6

'r r u w e u w 8L to ~

7.c.

~

lo ~

pp nEasoit tg f

i f

I l

t I

o,.

i e

i

.i i

e i

i i

g o

10 to 30 4o So so 70 so so too lio i

PERCENT CORE FLOW TEST CONDITION (TC) REGION DEFINITIONS TEST CONDITION NO.

POWER FLOW MAP REGION AND NOTES

.1 8EFORE OR AFTER M AIN GENERATOR SYNCHRONIZATION 8ETWEEN S.% AND 20.% THERMAL POWERWITHIN310.% OF M4 SET MINIMUM OPERATINO SPEED UNE IN LOCAL MANUAL MOOE.

2 AFTER MAIN GENER ATOR SYNCHRONIZATION SETWEEN THE 48.% AND 75.% POWER ROO LINES SETWEEN M4 SET MINIMUM SPEEDS FOR LOCAL M ANUAL AND MASTER MANUAL MODES THE LOWER POWER CORNER MUST BE LESS THAN SYPASS VALVE CAPACITY, 3

SETWEEN THE 46.% and 75.% POWER ROD LINES -

CORE FLOW SETWEEN 80% AND 100.% OF ITS R ATED VALUE.

Dele +td.

5 WITHIN +0. 4% OF THE 100.% POWER ROO LINE -

WITHIN S.% OF THE ANALYTICAL OF THE LOWER i

LIMIT OF MASTER FLOW CONTROL.

6 WITHIN +0. 4% O F RATED 100.5 POWER -WITHIN

+0, 6% OF RATED 100.% CORE FLOW RATE.

HO9ECREER GENERATING STATION FINAL SAFETY ANALYSIS REFORT OPERATIONAL POWER / FLOW MAP FIGURE 14.24 Aniendment 1,8/83 1

+

.. -.... -.,.----,,.. -.,... - -,,

ML20132B145

Text

Navigation menu

Search