ML20236L993

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Rev 1 to SMNH-97-008, Unit 1 Core Spray NPSH Margin Calculation. W/Two Oversize Drawings
ML20236L993
Person / Time
Site: Hatch  Southern Nuclear icon.png
Issue date: 09/04/1997
From:
SOUTHERN NUCLEAR OPERATING CO.
To:
Shared Package
ML20135G018 List:
References
SMNH-97-008, SMNH-97-008-R01, SMNH-97-8, SMNH-97-8-R1, NUDOCS 9807130257
Download: ML20236L993 (26)
v • d • e


Text

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E. I. HATCH NU' CLEAR PLANT i

I SCS CALCULATION UNIT FORINFORMRI0h DN_Y SmyIMMP

' ' DAldULATION #"

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REVISION.

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  • - Design Crl:ul:tirn3 - Nucirr S:uth;rn CrmpIny S:rviles,Inc.

Calculation Number SMNH-97-008 fuject Discipiire E. I. Hatch Nuclear Plant - Unit (s): G31 02 Mechanical C%ee Job Number Determine the NPSH margin for the Unit 1 Core Spray pumps DCR 96-040 subject /ime Unit 1 Core Spray Pump NPSH Margin Calculation Dee6gn Eng6neer's 86gnature Date Last Pege Number William Scott Walker 5/29/97 5

contents Top 6c.

Pege Attechmente Number (Computer Pmtouts. Techrucal Pacers. Sketches. Correspanoence) of Peges Purpose of Calculation / Summary of Conclusions 1

GE Letter OLH 0025 "Drywell LQ Temperature Profile and LOCA Pool Temperature for NPSil Evaluation

  • dated May 10 15.1997 Cntens 1, 2 CS Pump Performance Curve PC 36787 i

Major Equation Sources /Denvauon M+tnous 2,3 HNP-FSAR 14, Page 14.415 i

Assumptions 3

Listed References 4

Body of Calculations 3

l Safety Related O Yes O No l

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

Record of Revisions j

new.No.

Descrtpuon Originator / Date Rev6 ewer i Oate Superv6 sori Date l

i 0

Issued in Response to DCR 96-040 w.s.wa:Ler / 5-29-97 atu / 5 30-97 wMw / 6-t 7-97 1

Revised Suction Piping Head Loss

//)(//f.f.p Rtg fa).4 97

,,,,, p p l

l Notes:

FORINFORMMIONORY C tWORDW60HATCHtCCSCALCS$MNH9708 DOC CALC DOT / Rev 1 31101996

Design C:lculations - Nuclear souemm company s. Mees,Inc.

4 W

cmewsoon nwnner E. I. Hatch Nuclear Plant - Unit (s): lid 1 02 SMNH-97-008 sen ime.

sn Unit 1 Core Spray Pump NPSH Margin Calculation 1 of 5 Purpose / Scope:

The purpose of this calculation is to determine the NPSH margin for the Unit 1 Core Spray (CS) pumps, excluding the pump suction strainers, under accident conditions; This value will be used for i

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

- term worst case conditions. This calculation supersedes Bechtel Calculation M041, SCS Folder #

4819 (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: 5900 gpm Temperature: 165'F; Time: 600 seconds (10 min.)

NPSH,.,,,, = 28.955 - 16.5 f1 = 12.455 ft l

For Long Term Operation:.

Flow rate: 4725 gpm Temperature: 208"F Time: 3 X 10'sec (8.333 hrs)

NPSH.,,. = 23.333 - 14.0 ft = 9.333 ft l

Criteria:

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 order to determine the worst case conditions for NPSH, th: highest calculated suppression pool I

cwoamnomrencesotesa. mew ooc cuc oona-unn,*

l l

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' Dealgn C:lculations - Nucirr southern cornpany services. InC.

l Propct Calculabon Number E. I. Hatch Nuclear Plant - Unit (s): 91 02 SMNH-97-008 Subject / Title sheet Unit 1 Core Spray Pump NPSH Margin Calculation 2 of 5 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 i

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 CS 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 4725 gpm per pump. Maximum 3

4 pool temperature occurs at approximately 3 x 10 seconds (8.33 hrs), with a corresponding containment 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 Unit 1 is not committed to Reg. Guide 1.1.

Equation Sources / Derivation Methods:

. The NPSH available will be calculated using Bemoulli's Theorem:

2 2

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

2 t

p, 2g p2 2g where:

Z = minimum torus water elevation i

Z = CS 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 ho = total head loss = piping friction losses + strainer head loss The strainer head loss will be ignored for the purpose of this calculation. Since vi = v2 and pi = p2 this equation reduces to:

CMORDWhouiATCMECCS\\CALCStSMNH9706 DOC CALC DOT / Rev 1 3110-19-%

?

Design Calculations '. Nuclear southwn company s:rvices,Inc.

l

Probot cmeussuonnumnw E. I. Hatch Nuclear Plant - Unit (s): El O2 SMNH-97-008 sump ime.

sn e Unit 1 Core Spray Pump NPSH Margin Calculation 3 of 5 L

1' (P, - Pur)I44 l.

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

2 y

P i

The NPSH required is taken from the pump curves and is dependent upon the flow rate. PsAT IS f

temperature dependent, while the piping friction losses are flow and temperature dependent.

. The NPSH margin = NPSH,,a - NPSH,y L

Assumptions:

The CS 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 5900 'gpm. The process flow diagram (Ref. 5) does not show pump operation at pump run-out when drawing water from the suppression pool. The Unit 2 CS process flow diagram does show a pump run-out condition; therefore this flow rate was used. 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. 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 4725 gpm. Per the process flow diagram, this is Condition IV, which is core spray injecting at reactor pressure. 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 5 psig for conservatism. This provides nearly 5 psig of margin.

1 There are two core spray pumps, each with a different NPSH required and slightly different suction piping configuration. Rather than perform two 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 increases with increasin'g temperature, has a greater effect on NPSH than the temperature effect on head loss. For this reason, the piping head loss was calculated at the highest temperature for both

'short term operation and long term operation. See SMNH-96-012 for this calculation'(Ref. 3).

C WWORDWBDHATCHECC3% CALC 841MNH9708 DOC CALC DOT / Hov 1 3110-19-96 u___

_ _ _ _ = _ _ - _ _ _ _ - _ _ _ - _ - _ - _ _ _ _ _ _ _ _ _ _ - - -. -

(

Design C:lculations - Nucle:r 3ruthem company services. Inc.

l.

IM Calculauon Numb.r L

E. I. Hatch Nuclear Plant - Unit (s): El O2 SMNH-97-008 sunweimo.

sn e Unit 1 Core Spray Pump NPSH Margin Calculation 4 of 5 l

References:

~

1.

Bechtel Calculation M041, Vol.1, Bind.1, (SCS Folder # 4819)

-2.

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

SCS Calculation SMNH 96-012, Rev. I " Head Loss in the HNP-1 CS Pump Suction Piping" 4.

H-16331 Rev.12 Core Spray System P&lD 5.

S-15117D Core Spray System Process Diagram 161F267BA

6. (a)

H-16945 Rev. O Core Spray System 16" Suction from Torus to Pump "A" (b) H-16859 Rev.1 Core Spray System 16" Suction from Torus to Pump "B" l.

7. (a)

SX-15188 CS Pump Performance Curves (Test Data) TC-3424 (E21-C001 A)

(b) S-15617B Core Spray Pump Performance Curve - PF-2777-66-1 (PC-36787)(E21-C001B) 8.

HNP-1-FSAR Section 14.4, Rev 15A,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:

l.-

. Letter GEH-0025 "Drywell EQ Temperature Profile and LOCA Pool Temperature for NPSH Evaluation" dated May 15,1997 (Ref. 2)

' 2.

RHR Pump Performance Curve PC-36787 (See Ref. 7) 3.

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

Design C:Iculations - Nu: lear southern company services,Inc.

.s; c comon nu.a.,

E. I. Hatch Nuclear Plant - Unit (s): 91 02 SMNH-97-008 I

suspevise sn t Unit 1 Core Spray Pump NPSH Margin Calculation 5 of 5 Body of Calculation:

(P - Pm)l44 i

+ (Z, - Z )- (h,,,, ) = NPSH_,,

2 i

p For Short Term Operation:

Flow rate: 5900 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

. 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'-10.5" = 89.875 ft Ref. 6 2

he _= 2.066 psi = 4.885 ft Ref. 3 for "A" RHR pump @ 165 F _l and 5900 gpm 2 2 3

NPSH,,ii = (14.7 psi - 5.3665 psi)(144 in /ft )(;3 / 60.90134 lb) + (l01.646 f1 - 89.875 ft) - 4.885ft NPSH,,,ii = 28.955 R NPSH,,, = 16.5 Ref. 7(b)

NPSH.,,j, = 28.955 ft - 16.5 ft = 12.455 ft l

For Long Term Operation:

Flow rate: 4725 gpm Temperature: 208'F Time: 3 X 10'sec (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 = 101'-7.75" = 101.646 ft Ref. 9 i

Z = 89'-10.5" = 89.875 ft Ref. 6 2

ho = 1.312 psi = 3.152 ft Ref. 3 for "A" CS pump @ 208 F l

and 4725 gpm NPSH.,,;i = (19.7 psi - 13.576 psi)(144 in'/ft )(; g3 / 59.93048 lb) + (101.646 ft - 89.875 ft) - 3.152ft 2

l.

NPSH.,,ii = 23.333 ft I

' NPSH,,, = 14.0 ft Ref. 7(b)

NPSH.,,i, = 22.333 ft - 14.0 ft = 9.333 ft l

. C WOROWOHATCH\\ECCST.,ALCS\\SMNH9708 DOC CALC DOTiRev 13i1419-96

(

ATTMENT 1 PME I 0F 10 O

' GENuClear Energy l..

GeneralElonene Connneny fit Cwener Avenue. San Jose CA DESH May 15,1997 GEH-0025 cc:

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

Southem Nuclear Operating Company P. O. Box 1295 Binningham. 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 i

Response at Extended Power Uprate Conditions, dated April 2,1997.

l

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.

Dear Mr. McElroy:

The purpose of this letter is to formally transmit the attached GE data for SNOC's EQ and NPSH evaluations in support of Hatch Extended Power Uprate as stated in the

' Reference 1 action items. 'Ihese verified data are essentially the same as those preliminary data faxcd to SNOC in References 2 and 3.

'Ihe 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. The increase in the drywell temperature during this period is due to the increase in the reactor theimal power for extended power uprate. Another factor that contributes to the current EQ profile being exceeded during this time period is that the portion of the current EQ profile from approximately 1,800 seconds to 40,000 seconds was based on decay heat alone without considering the effect of sensible heat. The effect of sensible heat becomes noticeable from 30.000 seconds to 70,000 seconds when the decay heat has decreased substantially.

t

I ATTACMEMT E 1 PME Z OF 10 i

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

effort.

)

Suppression pool temperature and wetwell (suppression c. amber) 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-term response up to 600 seconds (before initiation of containment spray) for the most limiting event of a double-ended recirculation discharge line break. It is assumed that all four RHR pumps are running at a maximum runout flow j

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

l Figures 6 and 7 show the long-tenn suppression pool temperature and wetwell pressure i

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 pool temperature for this case is 208"F and the corresponding wetwell pressure is 24.4 l

psia. Table I provides a summary of the calculated suppression pool temperature and i

wetwell pressure. Data for Appendix R and SBO will not be available until the end of l

May.

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

Sincerely, k

C.H. Stoll, Project Manager Hatch Extended Power Uprate M/C 172 Tel. (408)925-1401 l

I

________-__a

ATTACHMENT 1 PA6E 3 0F 10 Table 1. Summdy 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 of operator actions)

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

(At initiation ofoperator actions)

Peck 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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i ENCLOSURE 6 DRAWING E-10173, REVISION 7 GENERAL BUILDING SITE PLAN 1

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ENCLOSURE 7 PRIMARY METEOROLOGICAL TOWER AND PLANT STRUCTURES 1

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ENCLOSURE 8 j

PAGE CHANGE TO LICENSING SUBMITTAL 1

  • I f

' Request for License Amendment Extended Power Uprate Submittal Environmental Assessment In the FES for operation of Unit 2, the NRC noted that, although

~ dvanced models that could be applied to the cooling tower drift issue a

were available, it was more appropriate to evaluate the effects of cooling tower drift using the actual data collected from the Unit I monitoring program. Based upon review of the actual data, no vegetative effects attributable to salt deposition from cooling tower drift were observed. A monitoring program, which included low altitude true and false color photography, was required for Unit 2 for a minimum of 4 years. The NRC reviewed the results of the Unit 2 monitoring program and determined them to be acceptable. Thus, the Unit 2 monitoring requirement was eliminated.

A small increase in fogging potential due to operation of the cooling towers was noted in the FES but was determined to be insignificant.

The circulating water system flow does not change due to extended power uprate and consequently, cooling tower drift does not change.

The conclusions of the FES relative to cooling tower drift remain valid for extended power uprate.

l' 6.2 Hydrology

'6.2.1 Groundwater The FES states that a minimal quantity of groundwater (327 gal / min) i -

will be withdrawn from two wells in the regional aquifer for normal I.

two-unit operation. The FES concluded groundwater use at the site is not expected to significantly impact the regional aquifer and is not expected to affect offsite use. A permit issued by the State of Georgia Department of Natural Resources - Environmental Protection Division governs groundwater use, with limits for withdrawal significantly above the 327 gal / min withdrawal rate associated with two-unit operation.

The proposed extended power uprate will not result in a significant increase in the use of groundwater resources and will not significantly reduce the margin to limits contained in the referenced permit. The conclusions of the FES relative to groundwater use remain valid for extended po_wer uprate.

HL-5413 E3-7 A

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