ML20236L990

Rev 1 to SMNH-97-007, Unit 1 RHR Pump NPSH Margin Calculation

ML20236L990
Person / Time
Site:	Hatch
Issue date:	09/04/1997
From:	SOUTHERN NUCLEAR OPERATING CO.
To:
Shared Package
ML20135G018	List: HL-5647, Forwards Proprietary & non-proprietary Info in Response to 980327 RAI Re Licensee Extended Power Uprate Amend Request, Submitted on 970808.Calculations SMNH-97-007 & SMNH-97-008, Encl.Proprietary Info Withheld ML20236L990 ML20236L993
References
SMNH-97-007, SMNH-97-007-R01, SMNH-97-7, SMNH-97-7-R1, NUDOCS 9807130255
Download: ML20236L990 (19)

Text

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f E. I. HATCH NUCLEAR PLANT l

l SCS CALCULATION UNIT I

P W

q

0R 'Nf0RNON 0NLY smn M M1 CAL'COLATION #

l REVISION.

Design Calculations - Nuclear Southern Company Services, Inc.

Calculation Number SMNH-97-007 Project Discapim E. I. Hatch Nuclear Plant - Unit (s): 91 02 Mechanical Objectkve Job Number Determine the NPSH margin for the Unit 1 RHR pumps DCR 96-040 t

subj.curdue Unit 1 RHR Pump NPSH Margin Calculation Design E.ngmeer's Signature Date Last Page Number William Scott Walker 5/21/97 5

Contents topic Page Attachments Nun.JYe (Computer Pnntouts. Techncal Pepers. Sketches. Correspondence of Pages Purpose of Calculation / Summary of Conclusions

[

GE Letter OLil-0025 "Drywell LQ Temperature Profile and LOCA Pool Temperature for NPSil Evaluation" dated May 10 15,1997 Cntena

],2 RilR Pump Performance Curve icd 664 i

Major Equation Sources /Denvation Methods 2, 3 ffNP-lSAR 14, Page 14 415 i

Assumptions 3

Listed References 4

Body of Calculations 5

l Safety Related B Yes O No l

Nonsafety-related That Could Impact Safety-Related O Yes O No l

Record of Revisions Rev.No.

Desenption Origmatori Data Reviewer i Date Supervisors Date 0

issued in Response to DCR 96-040

• 5 walker / 5-21-97 RLM / 5 22-97 wMw / &i 7-97 1

Revised Suction Piping flead Loss

/gW/ f-/y7 RLM /*) 97 ma pr-go Notes:

20RINFORMiIl0N ONd 4

C \\WORDW5CRHATCH\\ECCSCALCSiSMNH9707 00C CALC DOT / Rev i 3110-19-96

Design Calculations - Nuclear Southern Company Services,Inc.

Pi%

Calculebon Number E. I. Hatch Nuclear Plant - Unit (s): B1 02 SMNH-97-007 simpeurm.

sw Unit 1 RHR Pump NPSH Margin Calculation 1 of 5 Purpose / Scope:

The purpose of this calculation is to determine the NPSH margin for the Unit 1 Residual Heat Removal (RHR) Pumps, excluding the pump suction strainers, when in LPCI (low pressure coolant injection) and containment spray mode. This value will be used for sizing new, larger capacity strainers. The value obtained in this calculation is to be added to the head loss through the strainers with the maximum debris loading calculated using the URG and NRC approved methodology to obtain the worst case NPSH margin. The head loss through the strainers at the operating conditions indicated is a function of the strainer design and is to be determined by the pump vendor. The strainer head loss includes the tee inside the torus, elbows and other fittings between the tee and the strainer.

These pumps operate in a wide varying range of containment pressures and suppression pool 3

temperatures. The main conditions to be considered are the short term (first ten minutes) and long i

term worst case conditions. This calculation supersedes Bechtel Calculation M044. SCS Folder #

2044 (Ref.1).

Summary of

Conclusions:

Any strainer attached to the RHR pump suction piping must have a fully loaded head loss less than the lower of the two values shown below For Short Term Operation:

Flow rate: 10,600 gpm Temperature: 165'F; Time: 600 seconds (10 min.)

NPSH,,,i, = 31.144 ft - 19.5 ft = 11.644 ft j

For Long Term Operation:

Flow rate: 7700 gpm Temperature: 208"F Time: 3 X 10'sec (8.3.93 hrs)

NPSH.,,i, = 25.054 ft - 15 ft = 10.054 ft l

1 l

Criteria:.

i This calculation is being performed as part of the response to NRC Bulletin 96-03: " Potential Plugging of Emergency Core Cooling Suction Strainers By Debris in Boiling-Water Reactors". In l

C MORDW60HATCHfCCSCALCStSMNH9707 DOC CALC DOT / Rev i 3/10 19 96

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Design C:lculations - Nucl:ar southern company services,ine.

Project C.icut.tson Number E.1. Hatch Nuclear Plant - Unit (s): 551 02 SMNH-97-007 sons. cine.

an Unit 1 RHR Pump NPSH Margin Calculation 2 of 5 order to determine the worst case conditions for NPSH, the highest calculated suppression pool temperature and highest pump flow rate were compared with the other corresponding operating conditions. 208 F is the highest temperature that will be reached by the water in the suppression pool as indicated by General Electric (GE) calculations for the Power Uprate project (Ref. 2). The maximum pump flow rate came from the Bechtel calculations for.NPSH available (see Reference 1).

The operating conditions in the Bechtel calculation were the design basis conditions for Unit 1 prior to power uprate. The extended power uprate modifications to support plant operation at 2763 MWt have been taken into account for this calculation. The maximum pool temperature and highest pump flow rate do not occur simultaneously. The RHR pump could reach pump runout flow rate during the first ten minutes. The maximum pool temperature at ten minutes is 161 F.165 F was used to make sure the temperature was enveloped for NPSH margin purposes. After ten minutes,

. operators can throttle the pump flow rate back to the design flow of 7700 gpm per pump. Maximum 4

pool temperature occurs at approximately 3 x 10 seconds (8.33 hrs), with a corresponding contain nent pressure of 24.4 psia (see Reference 2). Credit has been taken for containment pressure at the corresponding suppression pool temperature for long term operation. The value used for containment pressure provides a 4.7 psi margin between the calculated containment pressure at the maximum pool temperature, and the pressure value used for this NPSH calculation. This is allowed since it matches the design basis for NPSH as stated in Unit 1 FSAR page 14.4-15.

Equation Sources / Derivation Methods:

The NPSH available will be calculated using Bernoulli's Theorem:

2 2

Z + 144 P, + v, = 2 + g 44 p2+y,+h i

2 t

p, 2g p,

2g where:

Z = minimum torus water elevation i

Z = RHR pump suction center-line elevation 2

P = Pressure inside the torus i

P = Saturation pressure at suppression pool temperature 2

pi = p2 = density of suppression pool water vi = v2 = velocity of the water in the piping I

h, = total head loss = piping friction losses + strainer head loss t

l The strainer head loss will be ignored for the purpose of this calculation. Since vi = v2 and pi = p2, this equation reduces to:

j c monovesuctrecessencsWNH9707 DOC enc DOT / Rev 1 3110-19 %

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)

i' Design Calculations. Nuclear -

southem company services, Inc.

Propei cmemenon monin.,

)

E. I. Hatch Nuclear Plant ~- Unit (s): lid 1 02 SMNH-97-007 l

suspeims.

sn i Unit 1 RHR Pump NPSH Margin Calculation 3 of 5 j

j 4

(P-Pur)l44 3

+ (Z, - 2 )-(h,) = NPSH 2

t u

P

~ The NPSH required is taken from the pump curves and is dependent upon the flow rate. Pswr is temperature dependent, while the piping friction losses are flow and temperature dependent.

The NPSH margin = NPSH,y a - NPSH,,q Assumptions:

The RHR pumps have two distinct operating modes. For 'short term operation, the pumps are allowed to operate at "run-out" conditions. No attempt to throttle them is made; therefore, they run at the highest flow rate that piping friction losses and reactor pressure will physically allow. For

. this calculation, that is assumed to be 10,600 gpm. The process flow diagram (Ref. 5) shows that run-out is 10,400 gpm (Mode G); but, Bechtel calculation M044 (Ref.1) used 10,600 gpm. The

'l higher value was used for conservatism. The reactor is assumed to be at 0 psig. Per calculations completed by GE for plant operation at 2763 MWt (Ref. 2), the maximum suppression pool temperature during this ten minute mode is 161 F.165 F degrees was assumed for conservatism.

I No credit is taken for containment pressure during short term operation.

For long term operation (over ten minutes), the operators can throttle the flow rate back to the pump design flow rate of 7700 gpm. Per the process flow diagram, this is Mode C-2, which is post accident containment spray with heat rejection using one RHR pump. Per the GE calculations for containment temperature and pressure for plant operation at 2763 MWt, the maximum suppression pool temperature is 208 F which occurs at 3 X 10 seconds (8.33 hours3.819444e-4 days <br />0.00917 hours <br />5.456349e-5 weeks <br />1.25565e-5 months <br />) into the event. The containment pressure at this point is 9.7 psig (24.4 psia). We will assume a containment pressure of l

5 psig for conservatism and to maintain the nearly 5 psig margin specified in the FSAR._

There are four RHR pumps, each with a slightly different NPSH required and suction piping

' configuration. Rather than perform four different calculations, the pump with the highest value for these parameters will be used as the bounding value.

- The piping friction losses are dependent upon both flow rate and water temperature. Increasing the flow rate increases the head loss. Decreasing the temperature increases the head loss. Temperature.

however, has less effect on head loss than flow rate does. Additionally, the vapor pressure, which 1 increases with increasing temperature, has a greater effect on NPSH than the temperature effect on I

head loss. For this reason, the piping head loss was calculated at the highest temperature for both i

short term operation and long term operation. See SMNH-96-011 for this calculation (Ref. 3).

l l

C.tWORDW609tATCHECCS\\CALCS$MNH9707 DOC CALC DOT IRev 1 3110-19-96 I

Design C:lculations - Nucle:r southem company services,Inc.

j

^4i Calcul. hon Number E. I. Hatch Nuclear Plant - Unit (s): B1 02 SMNH-97-007 l

sunpouria.

an e Unit 1 RHR Pump NPSH Margin Calculation 4 of 5 1

References:

1.

Bechtel Calculation M044, Vol.1, Bind.1, (SCS Folder # 2044)

' 2.

Letter GEH-0025 "Drywell EQ Temperature Profile and LOCA Pool Temperature for NPSH Evaluation" dated May 15,1997 3.

SCS Calculation SMNH 96-011, Rev. I " Head Loss in line HNP-1 RHR Pump Suction Piping"

4. (a) H-16329 Rev. 43 RHR System P&ID Sheet No. I l

(b) H-16330 Rev. 36 RHR System P&ID Sheet No. 2

5. (a)

S-15304F Process Diagram. Residual Heat Removal System 729E623BA (b) S-15305D Process Diagram Residual Heat Removal System 729E623BA

6. (a)

H-16856 Rev.1 RHR System Suction from Torus to Pump "A" (b) H-16826 Rev. O RHR System Suction from Torus to Pump "B" i

(c)

H-16857 Rev.1 RHR Systera Suction from Torus to Pump "C" (d) H-16827 Rev. O RHR System Suction from Torus to Pump "D" 7.

S-19611 Test Results - RHR Pumps Performance Curves TC-3664, TC-3665, TC-3666, and TC-3667.

8.

HNP-1-FSAR Section 14.4, Rev ISA,3/97 9.

Bechtel Calculation M038, Vol.1, Bind. 2 (SCS Folder # 0761) 10.

Crane Flow of Fluids Technical Paper 410, @ 1988 11.

. SMNH 89-054 NPSH Limits - Core Spray and RHR Pumps Attachments:

1.

Letter GEH-0025. "Drywell EQ Temperature Profile and LOCA Pool Temperature for l

NPSH Evaluation" dated May 15,1997 (Ref. 2) 2.

RHR Pump Performance Curve TC-3654 (See Ref. 7) 3.

HNP-FSAR-14, Page 14.4-15 (Ref. 8)

L

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Design Calculations - Nuclear southern company services,Inc.

Pi@

Ca6culeDon Number l

E. I. Hatch Nuclear Plant - Unit (s): 91 02 SMNH-97-007 sowm.

se Unit 1 RHR Pump NPSH Margin Calculation 5 of 5 Body of Calculation:

(P-Pur)l44 i

+(Z - Z )-(h,,) = NPSH,,,a i

2 t

For Short Term Operation:

Flow rate: 10,600 gpm Temperature: 165'F; Time: 600 seconds (10 min.)

P = 14.7 psia i

P = PsAT = 5.3665 psia Per Steam Tables @ 165 F 2

3 p = (1/v) = 60.90134 lb/ft Per Steam Tables @ 165 F r

Z = 101'-7.75" = 101.646 ft Ref. 9 i

Z = 89'-l0.5" = 89.875 ft Ref. 6 2

ho = 1.140 psi = 2.6955 ft Ref. 3 for "D" RHR pump @ 165F l and 10,600 gpm 2 2 NPSH,y,a = (14.7 psi - 5.3665 psi)(l44 in /ft )(1ft' / 60.90134 lb)+(101.646 ft - 89.875 ft)- 2.6955ft NPSHavan = 31.144 ft i

NPSH,,, = 19.5 i

NPSH,,,,,i, = 31.144 ft - 19.5 ft = 11.644 ft l

For Long Term Operation:

Flow rate: 7700 gpm Temperature: 208'F Time: 3 X 10'see (8.333 hrs)

P = 14.7 psia + 5 psia = 19.7 psia i

P = PsAT = 13.576 psia Per Steam Tables @,208 F 2

p = (1/v ) = 59.93048 lb/ft' Per Steam Tables @ 208 F r

Z = 10l'-7.75" = 101.646 ft Ref. 9 Z = 89'-10.5" = 89.875 ft Ref. 6 2

ho = 0.596 psi = 1.432 ft Ref. 3 for "D" RHR pump @ 208 F l and 7700 gpm 2 2 3

NPSH.,.u = (19 7 si - 13.576 psi)(144 in /ft )(1ft / 59.93048 lb) + (101.646 ft - 89.875 ft)- 1.432ft P

NPSH.v.a = 25.054 ft NPSH,,, = 15 ft L

NPSH,,,,,i, = 25.054 ft - 15 ft = 10.054 ft l

C WWORDW50u4ATCHECCSCALC$$MNH9707 DOC CALC DOTi Rev 1 31101996

i ATTACHMENT 1 PME 1 0F 10 O

GENuclear Energy annaessueem ceneeny tis Curtner Avenue, San Joen CA ss125 May.15,1997

< GEH-0025 cc:

GE-NE DRF-A13-00402, Vol. 4 [TC) i Mr. G. K. McElroy i

Southem Nuclear Operating Company P. O. Box 1295 Birmingham. Alabama 35201

Subject:

Drywell EQ Temperature Profile and LOCA Pool Temperature for NPSH Evaluation

References:

1. Action Items 97-46,97-53, Same Subjects.

2. Fax from SK Rhow (GENE) to D. Howard on Drywell Temperature Response at Extended Power Uprate Conditions, dated April 2,1997.

3. Fax from TH Chuang (GENE) to GK McElroy on Pool Temperature and Wetwell Pressure Data for Short-Term and Long-Term NPSH Evaluation, dated April 21,1997.

i

Dear Mr. McElroy:

L The purpose of this letter is to fonnally transmit the attached GE data for SNOC's EQ j

and NPSH evaluations in support of Hatch Extended Power Uprate as stated in the l~

Reference 1 action items. These verified data are essentially the same as those j

preliminary data faxed to SNOC in References 2 and 3.

i The attached Figures 1 (for Hatch Unit 1) and 2 (for Hatch Unit 2) provide a comparison of the current drywell EQ temperature profile with the drywell temperature profile calculated at the extended power uprate conditions. Both figures show that the newly calculated drywell temperature exceeds the current EQ profile by up to 7'F during the time period from 35,000 seconds to 70,000 seconds. De m in the drywell temperature during this period is due to the increase in th rew r thermal power for trent EQ profile being extended power uprate. Another factor that contribute =

m exceeded during this time period is that the portion of L.

St EQ profile from appror.imately 1,800 seconds to 40,000 seconds was bax v,,, decay heat alone without considering the effect of sensible heat. De effect of sensible heat becomes noticeable

' from 30.000 seconds to 70,000 seconds when the decay heat has decreased substantially.

ATTACHMENT E 1 L

PME 2 0F 10 If the current EQ profile is revised by replacing the portion between 1,800 seconds (330'F) and 80,000 seconds (200*F) with a straight line, then the new profile will bound

)

the drywell temperature profile calculated at extended power uprate conditions. Figure 3 L

shows the revised EQ temperature profile thus obtained. This revised EQ profile is

. applicable to both Hatch Units 1 and 2. However, it is up to SNOC to determine what is L

the best revised EQ profile for them to use in order to minimize their EQ reevaluation 1

I effort.

Suppression pool temperature and wetwell (suppression chamber) pressure profiles for LOCA events are provided in Figures 4 through 7 for SNOC's NPSH evaluation. Figures 4 and 5 are obtained for the short-tenn response up to 600 seconds (before initiation of '

containment spray) for the most limiting event of a double-ended recirculation discharge L'

line break. It is assumed that all four RHR pumps are running at a maximum runout flow l,

of 10,600 gpm per pump. 'Ihe maximum pool temperature for this case is 161'F at 600 seconds, while the corresponding wetwell pressure is 16.9 psia.

Figures 6 and 7 show the long-term suppression pool temperature and wetwell pressure responses, respectively, up to the point when the suppression pool temperature peaks following a DBA LOCA event of a double-ended recirculation suction line break. It is assumed that one core spray pump is available to provide flow to the vessel and one RHR pump is running in containment spray mode after 600 seconds. The peak suppression l

pool temperature for this case is 208'F and the corresponding wetwell pressure is 24.4 l_

psia. Table 1 provides a summary of the calculated suppression pool temperature and wetwell pressure. Data for Appendix R and SBO will not be available until the end of May.

If you have any questions regarding this transmittal, please call Teng Chuang at (408)925-3634 or me.

Sincerely, tk

C.H.' Stoll, Project Manager Hatch Extended Power Uprate L

M/C 172, Tel. (408)925-1401 i

t i

l i

i i

l

ATWHMENT 1 PA6E 3 0F 10 Table 1. Summary of Suppression Pool Temperature and Suppression Chamber Pressure for NPSH Evaluation Short-Term Response Long-Term Response CASE Recirculation Discharge Recirculation Suction Line Break Line Break 2 CS and 4 LPCI 1 CS and 1 RHR Pump Pumps Running Running Before Containment Containment Spray Starts Spray Starts at 600 Seconds Suppression Pool Temperature 161 at 600 sec (*F)

(At initiation ofoperator actions)

Suppression Chamber Airspace Pressure 2.2 at 600 sec (psig*)

(At initiation of operator actions)

Peak Suppression Pool Temperature (*F) 208 (at 30,000 seconds)

Corresponding Suppression Chamber 9.7 Airspace Pressure at Time of Peak Suppression Pool Temperature (psig*)

(at 30,000 seconds)

• Based on an atmospheric pressure of 14.7 psia.

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ATTACRMENT 3 r"

PAGE 1 0F 1 i=

l HNp-1-FSAR-14 l

L Assumptions E, F,

and G result in the minimum

.possible quantity of noncondensible gases being

.present in the containment during the transient which, in turn,.results in.the minimum possible L

pressure.. Assumption H gives the minimum l

containment gas temperature and, thus, also I

minimizes the pressure.

~

The. combination,of maximum fluid temperature and maximum containment pressure calculated with the above assumptions is the most severe condition for.which adequate NpSH must'be shown to, exist.

Figure 14.4-5 shows the rate and total heat rejected

-from the suppression pool assuming one RHR heat exchanger is available and assuming the service water temperature remains at 95'F throughout'the transient.

Figure 14.4-6 shows the suppression pool temperature I

transient assuming only one RHR heat exchanger and pump to be available and assuming the service water to remain at 95'F throughout the transient.

The peak pool temperature under these conditions is 240'F and

[

occurs 10 h Sfter the postulated LOCA.

]

The physical 3r rrs ;ement of the CSCS is as follows:

1 Suppression pool water elevation 101 ft 8 in.

(lowest level)

Elevation of the pumps CS 89 ft 10 in.

LpCI 89 ft 10 in.

a Head loss through the pump suction lines at rated flow and 204'F CS 5.6 ft LpCI 3.0 ft Figure 14.4-7'shows the minimum containment pressure transient that occurs using the very degraded assumptions discussed in,section 14.4.3.1.

l Also shown is the minimum containment pressure required in order for adequate NpSH to exist at the

.CSCS pumps.

The least margin between the minimum

. containment pressure and the pressure required for adequate NpSH occurs at about 7 x 10' s.

It is nearly 5 psi for the LpCI pumps and over 6 psi for the CS pumps.

The CS pumps have 3dequate NpSH even if the containment is.at atmospheric pressure.

There is a 14.4-15 REV 8 7/90 r