Calculation MDQ099920060011, Rev. 0, 'Transient NPSH ... · TRANSIENT NPSH/CONTAINMENT PRESSURE EVALUATION OF RHR AND CORE SPRAY PUMPS 2.14 EPU FTR T0400 R1, Containment System Response

TVAN CALCULATION COVERSHEET/CCRIS UPDATEPage 1

REV 0 EDMS/RIMS NO. EDMS TYPE: EDMS ACCESSION NO INIA for REV, 0)

I calculations(nuclear) INA

Calc Title:

TRANSIENT NPSWCONTAINMENT PRESSURE EVALUATION OF RHR AND CORE SPRAY PUMPS

CLC ID n 2M NUMBER CUR REV DMUEW

CURRENT CN NUC REVISIONAPPLICABILITY

NEW CN NUC BFN MEB MDQ099920060011 SeEntire calg 0Selected Pages E3,.i,,No CCRIS Changes [3

ACTION NEW I DELETE [I SUPERSEDE 0 CCRIS UPDATE ONLY [0 (For calc revision, CCRISREVISION r- RENAM [3 DUPLICATE 0 (Verifier Approval Signatures Not been reviewed and no

E Required) CCRIS changes required)

001 002 003 064 074 075DCN,EDCN/A APPLICABLE DESIGN DOCUMENT(S) CLASSIFICATIONN/A

LSAFET UNVERIFIED SPECIAL REQUIREMENTS DESIGN OUTPU SAR/TS and/or ISFSIRUA=o- RELATED? Of yes, ASSUMPTIQN AND/OR UMITING CONQnN? ATTACHMENT2 SAR/CoC AFFECTED

R= Yes) Yes 0 No0 Yes0El No 0 Yes'0 No 0. Yes NNorII Yes 0 No 10

PREPARER ID PREPARER PHONE NO PREPARING ORG (BRANCH) VERIFICATIO NEW METHOD OF ANALYSISWilliam A. Eberly 423-751-8222 MNE MIiiQ 0 Yes

Design Review [] NoPREP RER SIGNATURE " DATE CHECKER SI3gNA 0•E DATE

_________I__ , Eý4 L8/-o

VERIFIER SIGNATURE V p) 0 10 DATE APPVAL S1GNWTURE DATE

.. U& ,- /I- ,1. 0 - "_ W_,/_,

STATEMENT OF PROBLEM/ABSTRACT /The purpose of this calculation is to determine the Net Positive Suction Head (NPSH) available to the Core Spray (CS) andResidual Heat Removal (RHR) pumps as a function of time after postulated accident and operational transient events inaccordance with Regulatory Guide (RG) 1.82. The available NPSH is compared to the required NPSH for the respectivepumps to demonstrate that adequate margins exist to ensure that the RHR and CS pumps perform their Intended designsafety functions. The containment pressure necessary to preclude pump cavitation Is also determined. This calculationprovides graphical representations of the sequences to support responses to Round 6 Requests for Additional Information(RAI) in support of BFN Units 1, 2 and 3 Extended Power Uprate (EPU) license amendment requests (TS-418 and TS-431).

The results presented In Table 6.2-1 on page 21 show that adequate NPSH margins exist for each event scenarioanalyzed. The minimum margins, maximum required containment (wetwell) overpressure, and the duration for requiredoverpressure credit are presented in this table.

Acceptable results for the Appendix R event are based on assumed operator action at 2 hours to Isolate all drywell coolers(see UNVERIFIED ASSUMPTION, Appendix R Assumption 6 on page 18).

MICROFICHE/EFICHE Yes 0 No I FICHE NUMBER(S,-LOAD INTO EDMS AND DESTROY

[ LOAD INTO EDMS AND RETURN CALCULATION TO CALCULATION UBRARY. ADDRESS: SAB 1A-BFN0 LOAD INTO EDMS AND RETURN CALCULATION TO:

TVA 40632 [07-20051 Page I of 2 NEDP-2-1 [07-M20061

TVAN CALCULATION COVERSHEETICCRIS UPDATEP'age 2

CALC ID TYPE ORG PLANT BRANCH

ICN NUC BFN MEB

NI IMRFR I I=VNUMBE )age

MDQ099920060011II

ALTERNATE CALCULATION IDENTIFICATION

BLDG ROOM ELEV COORD/AZIM FIRM Print Report Yes 001 TVA

CATEGORIES NA

KEY NOUNS (A-add, D-delete)

ACTION KEY NOUN KEY NOUN

A PUMP A RHRA POOL A CSA ATWS A NPSHA DBA A SBOA LOCA A APPENDIX R

CROSS-REFERENCES (A-add, C-change, D-delete)ACTION XREF XREF XREF XREF XREF XREF(AIC/D) CODE TYPE PLANT BRANCH NUMBER REV

A P CN BFN MEB MDQ0999970046 R9

A P CN BFN MEB MDQ0023980143 R2

A P CN BFN MEB MD00064920353 R1

A P VD BFN MEB VTD-P160-0030 R6

A S CN BFN NTB NDQ0999920116 R20

A P VD BFN MEB GE-ER1-AEP-06-334 (W79-060803-001)

A P VD BFN MEB VPF2647-10-1

A P VD BFN NTB C1320503-6924 R2

CCRIS ONLY UPDATES:Following are required only when making keyword/cross reference CCRIS updates and page I of form NEDP-2-1 is not included:

PREPARER SIGNATURE DATE CHECKER SIGNATURE DATE

PREPARER PHONE NO. EDMS ACCESSION NO.TVA 40532 [07-2005] Page 2 of 2 NEDP-2-1 [07-08-20051

v

Page 3TVAN CALCULATION RECORD OF REVISION

CALCULATION IDENTIFIER 'MO0099920060011

Title TRANSIENT NPSH/CONTAINMENT PRESSURE EVALUATIONOF RHR AND CORE SPRAY PUMPS

Revision " , DESCRIPTION OF REVISION_-No.

0 Initial Issue

Total Number of Pages =64 (Including attachments)

The SAR and ISFSI SAR haVe been reviewed by 0,.)- L1 6 ('-"and this revision of the calculation does not affect SAR sections 6.1.6.2.6.3. 6.4.6.5. 14.5 andj4.6 and does not affect any ISFSI SAR sections.

Tech Specs and ISFSI CoC have been reviewed and determined not to be affected.

The calculation reflects parameters/values associated with the Implementation of ExtendedPower Uprate (EPU) as well as the use of containment over-pressure credit where needed forcalculating NPSH margins.

WA 40709 [1 2.2000] Pageloti NEDP4-2 (12.04-2000]TVA 40709 112-20001 Page I of I ,NEDPý 1 2-211 i 2-04-20001

1

Page 4

TVAN CALCULATION TABLE OF CONTENTS

Calculation Identifier: MDQ099920060011 Revision: o

TABLE OF CONTENTS

SECTION TITLE PAGE

Coversheet ........................................................................................................ ITVAN Calculation CCRIS Update ................................................................ 2

Revision Log ................................................................................................... 3Table of Contents ............................................................................................ 4

Design Verification (Independent Review) .................................................... 5

Computer Input File Storage Information Sheet .............................................. 6

1.0 Purpose .............................................................................................................. 72.0 References ........................................................................................................ 73.0 Design input data ............................................................................................. 84.0 Assum ptions .................................................................................................... 95.0 Requirem ents/Lim iting Conditions ................................................................ 9

6.0 Com putations and Analysis ............................................................................. 107.0 Supporting Graphics ....................................................................................... 22

8.0 Sum m ary of Results ........................................................................................ 349.0 Conclusions ...................................................................................................... 34

AppendicesA RHR Heat Exchanger K-Factor Evaluation (4 pages) ....................................B Recirculation Pump Motor Heat Load (4 pages) ...........................................

C Excel Spreadsheet Calculations (3 pages) .................................................

Attachments1 Sulzer Pumps Required NPSH Charts (2 pages) ............................................2 Dryw ell Cooler D ata (7 pages) ........................................................................

Total Pages 54

TVA 40710 [12-20001 Page 1 of I NEDP-2-3 [12-04-2000]

Paae 5

WAN CALCULATION VERIFICATION FORM

Calculation Identifier Revision 0MDQ099920060011

Method of verification used: I1. Deslgn Revwew': .

2. Alternate Calculation ' Verifier J arvs/Bechtel Date ____/__,,

3. Qualification Test ']Comments:This calculation was verified using the design review method to verify that themethodology, design Inputs, assumptions, computations, and results of this analysis aretechnically accurate, adequate, complete and in accordance with Regulatory Guide 1.82.The design review was performed in accordance with NEPD-5, Document DesignReview.

The Excel spreadsheets were reviewed to confirm that the plotted results and calculatedNPSH/containment pressure margins for the different accident and operational transientevents are reasonable compared to the inputs. The calculation provides adequateexplanations and justifications. Therefore, the reviewer finds this calculation to beacceptable for its intended safety related purpose

WA 40533 [07-20011 Page 1 of 1 NEDP-2-4 (07-09-2001J

TVA 40533107-20011 Page I of I NEOP-2-4107-09-20011

Page 6

TVAN COMPUTER INPUT FILESTORAGE INFORMATION SHEET

Document MDQ099920060011 Rev. 0 Plant: BFN

Subject:TRANSIENT NPSHICONTAINMENT PRESSURE EVALUATION OF RHR AND CORE SPRAY PUMPS

Electronic storage of the input files for this calculation is not required. Comments:

0 Input files for this calculation have been stored electronically and sufficient identifying information isprovided below for each input file. (Any retrieved file requires re-verification of its contents before use.)

RHR/CS TRANSIENT NPSH EVALUATION

I oorurentutJwuncI

0 Microfiche/eFiche

TVA 40535 [12-2000] Page 1 of I NEDP-2-6 [12-04-20001

Calculation No. MDQ099920060011 Rev: 0 Plant: BFN Unit 0 Page: 7

Subject:TRANSIENT NPSH/CONTAINMENT PRESSURE EVALUATION OF RHR AND CORE SPRAY PUMPS

1.0 Purpose:

The purpose of this calculation is to determine the Net Positive Suction Head (NPSH) available to theCore Spray (CS) and Residual Heat Removal (RHR) pumps as a function of time after postulatedaccident and operational transient events in accordance with Regulatory Guide (RG) 1.82. Thecalculation specifically addresses the recirculation pump suction DBA-LOCA, Station Blackout(SBO), Appendix R (APP R), and Anticipated Transient Without Scram (ATWS) events.

The available NPSH is compared to the required NPSH for the respective pumps to demonstrate thatadequate margins exist to ensure that the RHR and CS pumps perform their intended design safetyfunctions. The containment pressure necessary to preclude pump cavitation is also determined. Thiscalculation evaluates maximum pump flow rates, operation of drywell coolers, and containmentsprays with minimum or maximum cooling water temperature and provides graphical representationsof the sequences to support responses to Round 6 Requests for Additional Information (RAI) relativeto BFN Units 1, 2 and 3 Extended Power Uprate (EPU) license amendment requests (TS-418 and TS-431).

2.0 References:

2.1 TVA Calculation MDQ0999970046, Revision 9

2.2 GE-ER1-AEP-06-334, GE Responses to NRC Request for Additional Information - ACVB-37

and Draft TVA Letter, W79-060803-001

2.3 Sulzer Pumps (US) Inc. Document No: E12.5.1267 Rev 0, NPSH Transient Review RHR andCore Spray Pumps, 7/11/2006

2.4 TVA Calculation MDQ0023980143, Revision 2 (for RHR HX K-factor method)

2.5 TVA Vendor Datasheet for Aerofin Drywell Coolers, VPF2647-10-1 (see Attachment 2)

2.6 PROTOHX Version 4.00 QA software for heat exchanger performance analysis

2.7 Browns Ferry Nuclear Plant (BFN) - Units 2 And 3- Proposed Technical Specifications (TS)Change TS - 418 - Request For License Amendment Extended Power Uprate (EPU) Operation

2.8 Browns Ferry Nuclear Plant (BFN) - Unit 1- Proposed Technical Specifications (TS) ChangeTS - 431 - Request For License Amendment - Extended Power Uprate (EPU) Operation ***

2.9 NRC Requests for Additional Information for EPU - RAI 6, June 26, 2006 Unit 1 and Units 2and 3 letters from Eva A. Brown to Karl W. Singer ***

2.10 Heat Exchanger Specification Sheet, Perfex Corporation, vendor manual VTM-P160-0010 (VTD-P160-0030, R6)

2.11 TVA Calculation MDQ0064920353, Revision 1

2.12 C1320503-6924, Revision 2, BFN EPU Containment Overpressure (COP) Credit RiskAssessment

2.13 TVA Calculation NDQ0999920116, Revision 20, Appendix R Manual Action Requirements

*** Information Only reference, not specifically cited in calculation for design input



2.14 EPU FTR T0400 R1, Containment System Response

2.15 Browns Ferry EOI-I, RPV Control, R 1I (Unit 2), R8 (Unit 3)

2.16 Browns Ferry EOI-2, Primary Containment Control, R9 (Unit 2), R7 (Unit 3)

2.17 EPU FTR T061 1 RO, Appendix R Fire Protection

2.18 EPU FTR T0903 RO, Station Blackout

3.0 Design Input Data:3.1 Pump Flow Rates - Maximum flow rates per pump are determined from Ref2.1 as follows:

Short Term post DBA-LOCA

RHR pump flow rate to the broken recirc loop = 11,500 gpmRHR pump flow rate to the intact recirc loop = 10,500 gpmCS pump flow rate = 4125 gpm

Long Term post DBA-LOCA

RHR pump flow rate = 6500 gpmCS pump flow rate = 3125 gpm

Station Blackout (SBO) RHR pump flow rate = 6500 gpm

Appendix R (APP R) RHR pump flow rate = 7200 gpm

Anticipated Transient Without Scram (ATWS) RHR pump flow rate = 6500 gpm

3.2 Pump suction hydraulic losses and available NPSH without overpressure are determined forspecified state point conditions from Tables 6, 10, and 13 of Ref. 2.1

3.3 Containment transient response parameters (suppression pool temperature, wetwell pressure, etc.) areobtained from Ref 2.2 and Ref 2.14

3.4 RHR and CS pump required NPSH as functions of flow rate and operating duration are obtainedfrom the charts on pages 8 & 9 of Ref 2.3.

3.5 Initial suppression pool volume of 122,940 ft3 (TS Minimum with Drywell-to-Wetwell operatingpressure differential) from MDQ0064920353, Rev. 1 (Ref. 2.11)

3.6 RHRSW maximum temperature of 92°F based upon highest recorded temperature during study forC1320503-6924, Rev. 2 (Ref 2.12)

3.7 RHR heat exchanger K value of 227 BTU/sec-*F per RHR heat exchanger based upon RHRSWtemperature of 92°F (see Appendix A)

3.8 For other inputs used in the GE containment analyses, see Ref. 2.2

Calculation No. MDQ099920060011 Rev: 0 1 Plant: BFN Unit 0 Page: 9


4.0 Assumptions:

4.1 For events involving containment spray cooling, the minimum service water temperature isassumed to be 32F. Technical Justification: This limiting temperature condition conservativelymaximizes the depressurization of the containment following containment spray coolinginitiation.

4.2 For events involving containment spray cooling (LOCA and SBO), the static head in thesuppression pool is reduced by the equivalent amount of water that would be required to flood thedrywell floor holdup volume to the elevation of the downcomer pipe invert. TechnicalJustification: The drywell holdup volume will accumulate spillage from the break in the eventof a LOCA and containment spray water following spray initiation after a LOCA or SBO. It isconservative for the NPSH computations to assume that this inventory is deducted from the initialpool inventory at the onset of the event scenario.

4.3 It is assumed that no makeup is provided from the condensate storage tank (CST). TechnicalJustification: Although the HPCI!RCIC systems would initially take suction from the CST tomaintain reactor water level, compensating for coolant volume shrinkage during cooldown, thisinventory of relatively cool water would reduce the pool temperature response and increase thepool level and pump suction static head. It is conservative to neglect this makeup source.

4.4 UNVERIFIED ASSUMPTION - see Section 6.2.3, Appendix R, Assumption 6.

5.0 Requirements/Limiting Conditions:

There are no operational requirements / limiting conditions for operation established by this analysis.The action sequences and timing are consistent with the current Emergency Operating Instructions andTechnical Specifications relative to reactor and containment control and initiation of suppression poolcooling and containment sprays.

Calculation No. MDQ099920060011 Rev: 0 Plant: BFN Unit 0 Page: 10Subject:

TRANSIENT NPSH/CONTAINMENT PRESSURE EVALUATION OF RHR AND CORE SPRAY PUMPS

6.0 Computations and Analyses:

6.1 Methodology

The NPSH available is determined from the following standard equation for pumps with floodedsuctions:

NPSHa = Hstatic + 144/p(Pww - Pvapor) - Hf

Where: Hstatic = water static head from the pool surface to the pump impeller centerline, ftPww = the containment wetwell pressure, psiaPvapor = the water saturation pressure at the respective pool temperature, psiap = the density of the water at the respective pool temperature, lbm/ft3

Hf = the suction piping and strainer frictional head loss at the respective flow rate, ft

The available NPSH without credit for containment pressure is determined in Ref. 2.1 at specified pooltemperature conditions (initial pump start, maximum pool temperature, and end of required overpressurecredit period) and flow rates for each event. The TVA MultiFlow hydraulic flow balance software isemployed in Ref. 2.1 to determine the suction head loss, Hf including the strainer head loss reflectingthe appropriate debris loading for cases subject to post-accident debris generation (LOCA).

GE determined the containment response for each event using the Browns Ferry SHEX model (Ref 2.2)which provides the containment pressure and temperature transient conditions. To maximizesuppression pool temperature and minimize containment pressure the mechanistic, non-equilibriummodel of the mass and energy exchange between the pool surface and the wetwell atmosphere is appliedin the subject NPSH analyses.

Sulzer Pumps evaluated the Browns Ferry RHR and CS pumps and provided charts of the requiredpump NPSH as a function of the flow rate and operational period in Ref 2.3 (see Attachment 1). Thevalues for required NPSH are obtained from these charts by interpolation when necessary. RequiredNPSH values are selected for operating periods which bound the specific transient characteristic. Forexample, the APP R event is analyzed with one RHR pump operating at 7200 gpm and the followingrequired NPSH values are applied:

RHR OperatingFlow Rate Time NPSHr

gpm hours ft7200 0-8 22.47200 8-24 247200 24-72 31.3

These parameters are input into a Microsoft V EXCEL spreadsheet to calculate the available NPSHversus time for each event scenario. The steady-state NPSHa value from Ref. 2.1 is adjusted in thespreadsheet by replacing the steady-state vapor pressure and wetwell pressure with the transient vaporpressure and wetwell pressure, Pww. Available NPSH declines with increasing temperature. Therefore,



the steady-state hydraulic calculations performed for the peak suppression pool temperature conditionsare the base values in this analysis. No adjustment is made to the frictional and static head terms for theminor increase in fluid specific gravity at lower temperature conditions. The resulting transientavailable NPSHa is then compared to the required NPSHr to determine the margin available. Finally,the minimum containment pressure necessary to preclude pump cavitation is determined.

6.2 Analysis

This calculation analyzes the following event sequences to determine the NPSH available to the RHRand CS pumps as a function of time after the respective events:

* Loss of Coolant Accident (LOCA) - Short Term* Loss of Coolant Accident (LOCA) - Long Term* Anticipated Transient Without Scram (ATWS)* Appendix R* Station Blackout (SBO)

For each scenario, input parameters for this calculation are chosen from appropriate containmentpressure/temperature models, flow models, available NPSH values and vendor supplied required NPSHinformation.

The spreadsheets for each event are documented in Appendix C and are identified as follows:

S

S

0

0

EPURAI_6_LOCA.xlsEPURAI_6_ATWS.xlsEPU RAI 6 APPR.xlsEPURAI_6_SBO.xls

Pertinent parameters (i.e. suppression pool temperatures, containment pressures and subject pumprequired containment pressures) are plotted to provide graphic representations of the time history ofthese events. The graphs for each case are included in Section 7 of this calculation,"

The event-specific boundary conditions and assumptions are described in the following sections.



6.2.1 Loss of Coolant Accident (LOCA) - Short Term (ST)

The limiting design basis loss of coolant accident (LOCA), instantaneous double-ended rupture of oneof the recirculation pump suction lines is postulated. The containment response is predicted with theSHEX code based on the following inputs and assumptions:

LOCA Containment Analysis Key Inputs

1. Reactor Power 102% of EPU power 4031 MWt

2. Reactor Steam Dome Pressure 1055 psia3. Decay Heat Decay heat used in the SHEX analysis is

based on 102% of ANS 5.1-1979 decayheat with 2-sigma uncertainty adder

4. Initial Suppression Pool volume corresponding 121,500 fW3

to minimum suppression pool level

5. Initial Drywell Volume 159,000 fW3

6. Initial Wetwell Airspace Volume 129,300 fW3

7. Initial Drywell Pressure 15.5 psia

8. Initial Drywell Temperature 150°F9. Initial Drywell Relative Humidity 100%

10. Initial Wetwell Pressure 14.4 psia11. Initial Wetwell Temperature 950F

12. Initial Suppression Pool Temperature 950F13. Initial Wetwell Relative Humidity 100%

14. Ultimate Heat Sink/RHR Service Water 950FTemperature

15. RHR Heat Exchanger (HX) K value (per loop) 223 Btu/sec-0 F

16. Number of RHR Loops (I RHR pump & 1 RHR 4HX per RHR loop)

17. RHR Mode of Operation LPCI and Pool Cooling

18. Number of Drywell Coolers 0 (unavailable following LOOP)

19. Heat Loads Modeled Yes

20. Heat Sinks in Drywell, Wetwell and YesSuppression Pool Modeled

21. Leakage from the primary containment 1 2%/day



Pertinent Equipment Status:

" Two RHR Pumps at 11,500 gpm each (broken loop)* Two RHR Pumps at 10,500 gpm each (intact loop)" Four Core Spray Pumps at 4,125 gpm each" No Containment Sprays in short term

LOCA-ST Assumptions:

1. The suppression pool is assumed to be initially at minimum technical specification level.Justification - This minimizes the static head contribution to the available NPSH.

2. The suppression pool is assumed to be initially at maximum technical specification temperature.Justification - This maximizes the temperature transient which minimizes the available NPSH.

3. Maximum drywell relative humidity and temperature are assumed. Justification - This minimizesthe initial mass of non-condensable nitrogen in the containment and thus minimizes the transientpressure response.

4. Pumps start automatically and operate with wide open discharge valves with no operatorintervention. Justification - No operator actions are credited within the first ten minutes.

5. Pumps operate on their pump curves above their design flow rates (no throttling). Justification -NPSH required increases and NPSH available decreases with flow rate so it is conservative toconsider maximum flow rates.

6. Maximum suction strainer pressure drop is assumed, consistent with maximum debris loading.Justification - Maximum pressure drop is conservative for prediction of minimum NPSH available.

The time-history graphs of NPSH, containment pressure, and suppression pool temperature arepresented in Section 7.

I I- - - --- -- I

LCalculation No. MDQ099920060011 I Rev: 0 I Plant: BFN Unit 0 I Page: 14Subject:


-2

Loss of Coolant Accident (LOCA) - Long Term

The LOCA-LT is the continuation of the LOCA-ST scenario from 10 minutes until suppression pooltemperature is reduced and containment overpressure credit is no longer required for adequate NPSH.The limiting long-term LOCA scenario assumes loss of offsite power and single active failure of onedivision of emergency AC power, providing one train of safety equipment for accident mitigation.


" Two RHR Pumps at 6,500 gpm each" Two Core Spray Pumps at 3125 gpm each" Containment Spray cooling mode initiated at 10 minutes

LOCA-LT Assumptions:

1. Pumps are assumed to operate at their design flow rates under operator control.Justification- Emergency Operating Instruction (EOI) entry conditions for initiation ofcontainment sprays are satisfied for this event and the operators will respond accordingly.

2. RHRSW is assumed to be supplied to the RHR heat exchangers at either 32TF or 950F (twoextremes are analyzed to determine the limiting case). Justification - Cold cooling waterminimizes the containment spray temperature and produces the most rapid reduction incontainment overpressure. Maximum cooling water temperature produces the maximum pooltemperature response.

The time-history graphs of NPSH, containment pressure, and suppression pool temperature arepresented in Section 7.

Calculation No. MDQ099920060011 Rev: 0i Plant: BFN Unit 0 [Page: 15


6.2.2 Anticipated Transient Without Scram (ATWS)

For Browns Ferry, the limiting ATWS events are the Main Steam Isolation Valve Closure (MSIVC) andPressure Regulator Failure-Open (PRFO). The containment response for these events is very similar,therefore the MSIVC event is selected for the NPSH evaluation.

ATWS Containment Analysis Key Inputs

1. Reactor Power 100% of EPU power 3952 MWt2. Reactor Steam Dome Pressure 1050 psia3. Decay Heat Decay heat prior to reactor

depressurization used in the ODYNanalysis is based on the May-Witt model.Decay heat used in the SHEX analysisafter reactor depressurization is initiated isbased on nominal ANS 5.1-1979 decayheat (i.e., with no uncertainty adder).

4. Initial Suppression Pool volume corresponding 122,940 ft3


5. Initial Drywell Volume 171,000 fts

6. Initial Wetwell Airspace Volume 127,860 ft3

7. Initial Drywell Pressure 15.5 psia8. Initial Drywell Temperature 150°F9. Initial Drywell Relative Humidity 50%10. Initial Wetwell Pressure 14.4 psia11. Initial Wetwell Temperature 950F12. Initial Wetwell Relative Humidity 100%13. Initial Suppression Pool Temperature 950F I

14. Ultimate Heat Sink/RHR Service Water 920FTemperature ,

15. RHR Heat Exchanger (HX) K value (per loop) 227 Btu/sec,°F _ _ _

16. Number of RHR Loops (1 RHR pump & 1 RHR 4HX per RHR loop) _ _ _

17. RHR Mode of Operation Pool Cooling _

18. Number of Drywell Coolers 10 _ _ _ _ _

19. Heat Loads Modeled Yes20. Heat Sinks in Drywell, Wetwell and Yes

Suppression Pool Modeled

21. Leakage from the primary containment 2%/day




" Four RHR Pumps at 6,500 gpm each in Suppression Pool Cooling Mode" All ten drywell air coolers remain in service

ATWS Assumptions:

1. Initial Drywell Relative Humidity is 50%. Justification - Drywell RH normally ranges from 20%to 40% without coolant system leakage. The maximum value of 50% RH is selected to minimizethe mass of non-condensable nitrogen in the drywell and thereby minimize the containmentpressure response.

2. The operator initiates the Automatic Depressurization System (ADS) at the Heat CapacityTemperature Limit (HCTL) at approximately 20 minutes. Justification - The suppression pooltemperature reaches the EOI-2 HCTL before reactor shutdown and RCS depressurization isrequired by.EOI-2 (SP/T-7).

3. Assume the operator uses the FW system to maintain water level after depressurization to replaceHPCI when below HPCI isolation pressure. Justification - EOI-l (RC/L-4)

4. Both RHR trains (2 RHR pumps and HXs per train) are aligned in pool cooling mode.Justification - This is consistent with EOI-2 (SP/T-7)

5. The drywell coolers (and drywell heat loads) are modeled. It is assumed that all 10 drywellcoolers are operating. Justification - Operating all 10 coolers minimizes containment pressure.

6. There is no leakage from the primary system to the drywell. Justification - This assumptionminimizes drywell pressure.

The ATWS containment response analysis is conducted in two parts corresponding to the period fromevent initiation until reactor depressurization and the period subsequent to depressurization. The firstphase of the transient is modeled with the Browns Ferry ODYN model which determines the reactorpower response and MSRV flow which is input to the SHEX containment model to determine the initialsuppression pool temperature increase to the HCTL (180F). At that point the RCS is depressurized and,the SHEX containment code with a shutdown power curve is utilized to determine the long term, post-depressurization response.

Time-history graphs of NPSH, containment pressure, and suppression pool temperature are presented inSection 7.



6.2.3 Appendix R (Fire Safe Shutdown)

The limiting APP R event for containment response, previously identified and analyzed in EPUTask Report 0611 (Ref. 2.17) as APP R Case 1 postulates the following:

" No spurious operation of plant equipment." Depressurization begins at 25 minutes using three main steam relief valves (MSRVs)." One RHR pump aligned in the Low Pressure Coolant Injection (LPCI) mode, one RHR heat

exchanger, and one RHR service water (RHRSW) pump is initiated at 2 hours

GE re-analyzed this event with their approved SHEX containment code utilizing the following inputsand assumptions:

_______ Paaie ~Valuew1. Reactor Power 100% of EPU power 3952 MWt2. Reactor Steam Dome Pressure 1055 psia3. Decay Heat Decay heat used in the SHEX analysis is

based on nominal ANS 5.1-1979 decayheat (i.e., with no uncertainty adder).



5. Initial Drywell Volume 171,000 ft3

6. Initial Wetwell Airspace Volume 127,860 ft7. Initial Drywell Pressure 15.5 psia8. Initial Drywell Temperature 150OF9. Initial Drywell Relative Humidity 50%10. Initial Wetwell Pressure 14.4 psia11. Initial Wetwell Temperature 950F12. Initial Wetwell Relative Humidity 100%13. Initial Suppression Pool Temperature 95°F14. Ultimate Heat Sink/RHR Service Water 920F

Temperature15. RHR Heat Exchanger (HX) K value (per loop) 227 Btu/sec-°F16. Number of RHR Loops (1 RHR pump & 1 RHR 1

HX per RHR loop)

17. RHR Mode of Operation 9400 gpm in LPCI mode until RCSdepressurization, then 6000 gpm inAlternate Shutdown Cooling mode

18. Number of Drywell Coolers 10 for first 2 hours, then isolated19. Heat Loads Modeled Yes

Calculation No. MDQ099920060011 Rev: 0 Plant: BFN UnIt 0 Page: 18Subject:





* One RHR Pump in ASDC mode at 2 hours* 6,000 gpm assumed for minimum heat removal (Ref. Attachment 2)* 7,200 gpm assumed for maximum required NPSH* Ten Drywell Coolers continue operation until isolated by operator action at 2 hours

APP R Assumptions:

1. Initial Drywell Relative Humidity is 50%. Justification - Drywell RH normally ranges from 20%to 40% without coolant system leakage. The maximum value of 50% RH is selected to minimizethe mass of non-condensable nitrogen in the drywell and thereby minimize the containmentpressure response.

2. RHRSW Temperature of 92°F. Justification - Based upon highest recorded temperature duringstudy for C1320503-6924, Rev. 2 (Ref. 2.12)

3. RHR heat exchanger K value of 227 BTU/sec-*F per RHR heat exchanger. Justification - Basedupon using RHRSW Temperature of 92'F (see Appendix A).

4. Use initial suppression pool volume of 122,940 ft3 (TS Minimum with Drywell-to-Wetwelloperating pressure differential). Justification - MDQ0064920353, Rev. 1 (Ref. 2.11)

5. Pump is running on its pump curve above its design flow rate (no throttling). Justification -NPSH required increases and NPSH available decreases with flow rate so it is conservative toconsider maximum flow rates.

6. It is assumed that the unit operators isolate all drywell coolers at 2 hours after the start of the fireevent based on the recognition that the reduction in drywell pressure by the coolers and the pooltemperature increase due to the MSRV discharge are challenging the available NPSH to the RHRpump(s). Justification - This is an UNVERIFIED ASSUMPTION which will be resolved withthe subsequent revision of the Appendix R Manual Actions Requirements calculation (Ref. 2.13)which is listed as a successor document to this calculation in CCRIS.




6.2.4 Station Blackout (SBO)

The Station Blackout event sequence defined in EPU Task Report 0903 was re-analyzed by GE with theapproved SHEX code methodology. Inputs and assumptions consistent with RG 1.82 to maximize pooltemperature and minimize containment pressure were applied as follows:

" Unit trips when SBO occurs with automatic initiation of RCIC/HPCI systems to provide initiallevel control.

" Initial pressure control by automatic MSRVs operation." Operator action taken at one hour to control depressurization by cycling MSRVs while level

control is maintained automatically by RCIC system.* Coping duration is 4 hours.

1. Reactor Power 100% of EPU power 3952 MWt

2. Reactor Steam Dome Pressure 1055 psia

3. Decay Heat Decay heat used in the SHEX analysis isbased on nominal ANS 5.1-1979 decayheat (i.e., with no uncertainty adder).



5. Initial Drywell Volume 171,000 ft3

6. Initial Wetwell Airspace Volume 129,300 Wt3

7. Initial Drywell Pressure 15.5 psia

8. Initial Drywell Temperature 150°F

9. Initial Drywell Relative Humidity 100%

10. Initial Wetwell Pressure 14.4 psia11. Initial Wetwell Temperature 950F

Initial Wetwell Relative Humidity 100%12. Initial Suppression Pool Temperature 950F13. Ultimate Heat Sink/RHR Service Water 950F and 320F

Temperature14. RHR Heat Exchanger (HX) K value (per loop) 223 Btu/sec-°F

15. Number of RHR Loops (lRHR pump & 1RHR 2HX per RHR loop)

16. RHR Mode of Operation Containment Spray Cooling mode at 4hours

17. Number of Drywell Coolers 0, unavailable due to SBO

18. Heat Loads Modeled Yes



Calculation No. MDQ09992006001o Rev: 0 Plant: BFN Unit 0 Page: 20



" Two RHR Pumps initiated in Containment Spray Mode at 4 hours" Containment heat removal is based on assumed 5850 gpm each pump (Ref 2.18)* NPSH is evaluated assuming 6500 gpm each pump

Assumptions:

1. Containment spray and suppression pool cooling at 4 hours. Justification - The analysisdemonstrates that the EOI entry conditions for containment spray are met at the end of the copingperiod when power is restored.

Two SBO cases are analyzed to demonstrate the sensitivity of the available NPSH to the extremes ofspray water temperature (i.e., RHRSW water temperature).


Calculation No. MDQ099920060011 Rev: 0 F Plant: BFN Unit 0 TPage: 21Subject:TRANSIENT NPSH/CONTAINMENT PRESSURE EVALUATION OF RHR AND CORE SPRAY PUMPS

Table 6.2-1 - SUMMARY OF NPSH AND CONTAINMENT PRESSURE MARGINS

SUMMARY OF NPSH RESULTS

MAXIMUM MINIMUM DURATIONMINIMUM REQUIRED CONTAINMENT OF

MINIMUM REQUIRED NPSH CONTAINMENT PRESSURE REQUIREDCASE PUMP FLOW NPSHA NPSH MARGIN PRESSURE MARGIN COP

GPM FT FT FT PSIA PSI

CS 4125 26.5 25.5 1.0 16.4 0.4 9 min.

LOCA-ST RHR-IL 10500 29.4 25.5 3.9 15.2 1.6 5 min.

RHR-BL 11500 26.4 28.4 -2.0 17.7 -0.9 10 min.

CS 3125 35.1 24.5 10.6 12.6 4.5 0LOCA-LTSPRAYS, 32F RHRSW Cs 3125 35.1 24.5 10.6 12.6 4.5

RHR 6500 38.5 23 15.6 9.8 6.6 0

LOCA-LT CS 3125 36.3 29 7.3 17.4 3.1 22.5 hoursSPRAYS, 95F RHRSW

RHR 6500 39.8 23 16.8 13.4 7.1 0ATWS

ALL DW COOLERS RHR 6500 24.3 21.5 2.8 16.3 1.2 1.2 hoursAPP R

ALL DW COOLERS RHR 7200 11.8 24.1 -12.3 27.5 -6.8 NAAPP R

NO DW COOLERS RHR 7200 32.6 22.4 10.2 23.3 2.6 71 hoursAPP R

DW COOLERS FOR 2HRS RHR 7200 25.7 22.4 3.3 23.0 1.4 60 hoursSBO

SPRAYS, 32F RHRSW RHR 6500 27.6 21.5 6.1 15.6 2.5 0.6 hourSBO

SPRAYS, 95F RHRSW RHR 6500 32.2 21.5 10.7 15.8 4.5 1.4 hours



7.0 Supporting Graphics:



Figure 7.2

ST LOCAMAXIMUM RHR AND CS FLOW RATES

160 22

150 20

140 18

130- 1621

0 11 11 11 11, 1, 1

- 106000 100 200 300 400 500

Time (seconds)

Suppression Pool Temperature -.- Wetwell Pressure

- - - Atmospheric Pressure X--RHR Pump Broken Loop Containment Pressure Required

-- RHR Pump LPCI Loop Containment Pressure Required --9--CS Pump Containment Pressure Required

Figure 7.3

ST LOCACS PUMP 4125 GPM

* NPIa________ACTUAL

*~ NPSHaNO COP

-NPI

0 100 200 300 400 500 600 700

TIME, SEC



Figure 7.4

Z

ST LOCARHR 10500 GPM

90

80 - --70 -

60

*NPSHa501 ACTUAL

TIE NPSHC

4011 - -NO COP

301- ftwom

NPSWr

30

0 100 200 300 400 500 600 700

TIME, SEC

Figure 7.5

ST LOCARHR 11500 GPM

90

70N

60

*NPSH~a50 ___ EACTUAL

-h-- NPSHaNO COP

z40 -NPS~r

0 100 200 300 400 500 500 700

TIME, SEC



Figure 7.6

LT LOCA95F SPRAYS

200

190

180

170I

1160

I150

140

130

IL16 1I.

0 4 8 12 I6 20 24

Time (hours)

- Suppression Pool Temperature

- - - Atmospheric Pressure

- CS Pump Containment Pressure Required

F r Wetwell PressureX -RHR Pump Containment Pressure Required

Figure 7.7LT LOCA

32F SPRAYS

200 40

19D 35

180 30

170 -25 S

160 -20i

150 .15

140 - 10

130 5

120 00 1 2 3 4 5 6 7 8 9

TIME, HOURS

Suppression Pool Temperature --- Containment Pressure- Atmospheric Pressure Kud RHR Pump Containment Pressure Requiredý-4--CS PureD Containment Pressure Reouired



Figure 7.8

LT LOCACS 3125 GPM, 95F SPRAYS

100

90

80

70

60 * NPSHaACTUAL

~50 a- NPSI~aNo COP

Z _NPSHr40

:30 - 9-24.5-

10

00 4 8 12 16 20 24

TIME, HOURS

Figure 7.9

LT LOCACS 3125 GPM, 32F SPRAYS

100

90

80

70

60 *NPSHaACTUAL

z50 -a- NPSHaNO COP

z -NPSHr- ,-

30 - -,- - - - -24.5 - ,

20

10o_

0 1 2 3 4 5 6 7 8 9TIME, HOURS



Figure 7.10

LT LOCARHR 6500 GPM, 95F SPRAYS

100

80

70

60 * NPSHaACTUAL

_50_ &-- NPSHaNO COP

z ,mw N P S H r

203-20 ____

10 i

0 4 8 12 16 20 24

lIME, HOURS

Figure 7.11LT LOCA

RHR 6500 GPM, 32F SPRAYS

100 ____

90

70

0 NPSHat •ACTUAL

:e50 _______ ANPSHsNo COP

-NPSHr40 ____

30 __

2021.

0 1 2 3 4 5 6 7 8 9

TIME, HOURS

I Calculation No. MDQ099920060011 Rev: 0 Plant: BFN Unit 0 Page: 28


Figure 7.12

ATWS10 DW COOLERS, BALANCED PERFORMANCE

250

SP Tamp

C 150 DWTmp

50

0 0.5 1 1.5 2 2.5 3 3.5 4 4.5 5TIME, HOURS

- Suppression Pool Temperature --- DWTEMP F- Wetwell Pressure Atmospheric Pressure

-(--RHR Pumo Containment Pressure Reauired - DW PRESS PSIA

50

5.5 6

Figure 7.13

ATWS6500 GPM, 10 DW COOLERS

AS2RAIATWSDWC2

~ E NPSHaACTUAL

-- NPSHaNO OOP

-NPS:Hrr

0 0.5 1 1.5 2 2.5 3 3.5 4 4.5 5 5.5 6TIME, HOURS



Figure 7.14

I10

APP R10 DW COOLERS, 100% RH

Coolers Off After 2 Hr

30

26

181

14

• 10

32 40 48 56 64 72

Time (hours)a t6 24

1- Suppression Pool Temperature --- Wetwell Pressure - - - Atmospheric Pressure --- RHR Pump Containment Pressure Required[

Figure 7.15

APP R7200 GPM, 10 DW COOLERS

Coolers Off After 2 Hrs

* NPSHaACTUAL

* NPSHaNO COP

_NPSFWt

0 4 8 12 16 20 24 28 32 36 40 44 48 52 56 60 64

TIME, HOURS



Figure7.16

APP R10 DW COOLERS, 100% RH

240 30

230 28

220 26

210 24

M Iw

190 20

180 -18

1 14

0 4 8 12 16 20 24 28 32 36 40 44 48 52 56 60 64

TIME, HOURS

- Suppression Pool Temperature --- Containment Pressure

Atmospheric Pressure w RHR Pump Containment Pressure Required

Figure7.17

APP R7200 GPM, 10 DW COOLERS

50

40

0 * NPSHaIz 2.11JACTUAL

£20 -. 1110 NPSHa

z -NPSHr

10-

01

0 10 20 30 40 50 60

TIME, HOURS



Figure7.18

APP RNO DW COOLERS

240• 30

230 .28

220 .26

210 •24

190 -209

170 -•16

150 -12

140 10

0 8 16 24 32 40 48 56 64 72 W0 88 96 104 112 120 128 136 144

TIME, HOURS

•Suppression Pool Temperature -. -Containment Pressure

SAtmospheric Pressure -- XRHR Pumnp Containnmerd Pres,,sure Reqiuiredi

Figure7.19

APP R7200 GPM, NO DW COOLERS

zACTU:AL

-NPISHr

F *- NPSHa-*-NPSHa'0 NOCOP

0 8 16 24 32 40 48 56 64 72 80 88 96 104 112 120 128 136 144

l1ME. HOURS

-Calculation No. MD0099920060011 Rev: 0 1 Plant: BFN Unit 0 Page: 32


Figure7.20

SBO95F SPRAY AT 4 HOURS

50

16

.20

0 4

Time (hours)

a

- Suppression Pool Temperture --- Wetwel Pressure - - - AtmosDheric Pressure -N-- RHR PumD Containment Pressure Reouired

Figure7.21

SBO32F SPRAY AT 4 HOURS

50

20

10

4 6

Time (hours)

0 2

I- Suppression Pool Temperature -f-- Wetwell Pressure - - - Atmospheric Pressure --- X- RHR Pump Containment Pressure Required I



Figure7.22

SBO6500 GPM, 95F SPRAYS AT 4 HOURS

250

200

* NPSHa150 E ACTUAL

-&- NPSHa_NOCOP

-NPSHr

S100 -SPTEMP DEGF

0 4 8 12 16 20 24

TIME, HOURS

Figure7.23

SBO6500 GPM, 32F SPRAYS AT 4 HOURS

* NPSHaACTUAL

--A- NPSHaNO COP

-NPSHr

SP TEMP DEG F

TWE, HOURS I



8.0 Summary of Results:

The case parameters and results are presented in Table 6.2-1 (page 21) and in Figures 7.2 through7.23.

9.0 Conclusions:

Analyses determining the Net Positive Suction Head (NPSH) available to the Core Spray (CS) andResidual Heat Removal (RHR) pumps as a function of time after postulated accident andoperational transient events in accordance with Regulatory Guide (RG) 1.82 have been performed.The calculations are performed at EPU bounding conditions specifically for the recirculation pumpsuction DBA-LOCA, Anticipated Transient Without Scram (ATWS), Appendix R (APP R), andStation Blackout (SBO) events.

This calculation evaluates maximum pump flow rates, operation of drywell coolers, andcontainment sprays with minimum or maximum cooling water temperature and provides graphicalrepresentations of the sequences to support responses to Round 6 Requests for AdditionalInformation (RAI) relative to BFN Units 1, 2 and 3 Extended Power Uprate (EPU) licenseamendment requests (TS-418 and TS-43 1).

Comparison of the available NPSH to the required NPSH for the respective pumps demonstratesthat adequate margins exist to ensure that the RHR and CS pumps perform their intended designsafety functions. The containment overpressure necessary to preclude pump cavitation and theduration for the required COP credit are determined for each event as summarized in Table 6.2-1(page 21).

Specific conclusions are:

* The small deficiency (-2 ft) for the RHR pumps discharging to the broken loop in theLOCA-ST case is considered acceptable on the basis of the short (<10 min.) durationinvolved.

" Maximum spray temperature produces the maximum duration for the wetwell overpressurerequirement as indicated by comparison of the two LOCA-LT cases for 32F and 95FRHRSW.

" The case which results in the minimum available NPSH margin is the ATWS event whichreflects a minimum margin of 2.8 ft for a short duration of approximately one hour. This isa consequence of the conservative power input included in the ATWS model.

" A small margin is also predicted for the Appendix R event (3.3 ft). This event requiresoperator action to isolate the drywell coolers within the first two hours of the eventscenario.

" The maximum duration for required wetwell overpressure is determined by the Appendix Revent with coolers isolated at two hours.

" Continued operation of drywell coolers for events which do not involve LOCA break flowor drywell sprays (ATWS and Appendix R) minimizes the containment pressure and NPSHmargins for those cases.

APPENDIX A

Calculation No. MDQ099920060011 Rev: 0 1 Plant: BFN Unit 0 Page: Al of 4


1.0 Purpose

The purpose of this Appendix is to calculate the heat exchanger K-factor per RHR heat exchangerrequired to transfer the design basis heat loads for the applicable PRA event sequences described inSection 6 of the main calculation. The result of this calculation serves as input to containment analysisthat is used in the main calculation to provide time histories of the event sequences.

2.0 References

2.1 TVA Calculation MDQ0023980143, Revision 2 - RHR Heat Exchanger Tube PluggingAnalysis For Power Uprate (RIMS W78030630006)

2.2 Textbook entitled Fundamentals of Heat and Mass Transfer by Frank P. Incropera and David P.DeWitt, John Wiley & Sons, 3rd Edition

2.3 Power Uprate Evaluation Report for the Tennessee Valley Authority, Browns Ferry Units 2 and 3,Primary Containment System," General Electric Design Record File GE-NE-B13-01866-4, Rev 1,July 1998, (RIMS W79 980716 001)

3.0 Design Input Data

3.9 TVA Calculation MDQ0023980143, Revision 2 - RHR Heat Exchanger Tube PluggingAnalysis For Power Uprate (RIMS W78030630006)

4.0 Documentation of Assumptions

4.1 RHRSW Temperature of 92°F. Justification - Based upon highest recordedtemperature during study for C1 320503-6924, Rev. 2

4.2 Suppression Pool Temperature of 187.4°F. Justification - reference 2.3.4.3 RHRSW flow is 4000 gpm per pump. Justification - reference 2.14.4 RHR flow is 6500 gpm per pump. Justification - reference 2.1

5.0 Special RequirementslLimiting Conditions

None.

6.0 Computations and Analysis

6.1 Methodology

This Appendix uses an RHR heat exchanger model developed for reference 2.1. This model isan Excel spreadsheet application that uses known heat exchanger parameters and acceptedstandard engineering formulas to solve for unknown parameters. The accuracy of this modelwas confirmed previously (reference 2.1).The major equation deals with heat exchanger effectiveness as a function of the overall heattransfer coefficient, the effective heat transfer area, the minimum mass flow-heat capacityproduct, and the heat capacity ratio. The effectiveness for a single shell pass, two tube passCES type heat exchanger is given by reference 2.2, as follows:

APPENDIX A

Calculation No. MDQ099920060011 Rev: 0 1 Plant: BFN Unit 0 1 Page: A2 of 4


e=2* +CR + [(I+ C'R2 Y1 m[].[1+]. (Eqn 1)

I 1-e NU(C~-jJ

where:9 = heat exchanger effectivenessCR = heat capacity ratio

= Cmin/CmaxCmin = minimum mass flow rate times fluid heat capacity product, Btu/hr-°FCmax = maximum mass flow rate times fluid heat capacity product, Btu/hr-0FNTU = number of transfer units

= UA/CminU = overall heat transfer coefficient, Btu/hr-ft 2 -OFA = effective heat transfer area, ft2

This equation along with others shown in reference 2.1, were programmed in an Excel spreadsheet andsolved in the following sequence: (Note all equation references come from reference 2.1)

1. To determine the heat exchanger performance at any flow condition, the inside and outside fluid filmresistance terms are calculated with Eqns 3 & 4 respectively.

2. The new overall heat transfer coefficient, U is determined from Eqn 2.3. The effective heat transfer area is found from Eqn 5 for the assumed tube plugging percentage (for

this appendix 1.5% Is used).4. The mass flow rates and heat capacity rates are found from Eqns 6 & 7.5. The effectiveness is determined from Eqn 1

6. From the effectiveness and minimum heat capacity rate, the K-factor is calculated.

The Excel spreadsheet is presented in Table 1.

6.2 Analysis

Using the accepted model, the following parameters were evaluated:

RHRSW Temperature = 920F.Suppression Pool Temperature = 187.30FRHRSW flow = 4000 gpm per pump.RHR flow = 6500 gpm per pump.

The spreadsheet solves for heat exchanger K-factor as indicated in Table 1.

APPENDIX A

I Calculation No. MDQ099920060011 I Rev: 0 1 Plant: BFN Unit 0 1 Page: A3 of 41Subject:


f !ef _:::::(:• 1 !iiiiL -t i IIFIK&Q as function of RHR Temp. at fixed TP% and RHRSW conditions

........i iiiii . . .. ....I 71i!!!i:!ffiiZ

I subf@a6 0.0160W 0.016043Flwgp 10000 4500

Ib.e .38.1 625.010.... _qi __

-- I6500 GPM,--~ O L~n rI..... 4P A C I ... ..... t .t. r .....

inlr ....... ý! .. ................Ilbm/sec )F

121893.7808 95130j 891.4327( 95

1407 88.981.. . 9

160 88.683 95180~ 87 7.2 294 9

1 87.31 8 74 8 7

4000

40004000

Ibmlsec

55.105956A059

553.1059

553.1059553.1059553.1059

553.10595 01531059

.531059

893.78Wi 0.000942891.43271 O. (942888.90811 0.000942

883.36831 0.000942877.22941 0.000942

8015 1 0 00 09 42

_ K]

1/ho

0.0006670.000667

0.0006670 . ........6 .

0.000667

11,0 16..000-66v

Rtotal_

0.0106466i0.0048820.0048820.00488211111111-11......0.0048820.0.....8._ 82_0.004882

U

204.851S24.851

204.851S

fluid roeioulig "Fes-metal raetotal mesU ow. fiI

EPS

0.404122

0.40410.4632

0.403178

[ .. ...... ..

0.0005

K

23682223.5996223.5098223.4136

22,3'

22.8 .2 .4 .5

. . . ............... _ _Tube sw I

0.00230.0004730.004645

215.285253

..... ... ............ .... .......

atotalBtu/hr40262891.4

56347108.6

88471794.3

136530069

.. 220473396.

RHRSWotal, gpm

800C

.......... ..

. . ..... | .. .. .. .

TP

4.572807

Aleff q____ ~4~h Tot.wStufhr I

6107.34 20131445.71 113.74341 105.1103> . ... • , ,( 6107.341 28173554.31 121.22091 109.1492

........ -- 4.v - - ' i i . .. -.. -..... . .. . . . .

800

800C800C

800x

4.572807

4.572810

6107/ • •O00. tt.U I f 1 . tlflI

'.34 44235897.11 136.13461 117.21596107.341 52254815.8 143.56831 121.2431

•"f •.=____ -- .( ........................

6107.3468265034.41 1SU.3831 12g.2837

741787201 163.84631 132.2536

00048821 204 .8.. 6304 110236698 191.4233 147.3309

APPENDIX A

Calculation No. MDQ099920060011 Rev: 0 1 Plant: BFN Unit 0 1 Page: A4 of 4


7.0 Supporting Graphics

None.

8.0 Summary of Results

This calculation establishes that the heat exchanger K-factor per RHR heat exchanger that is required totransfer the design basis heat loads for the applicable event sequences is 227 BTU/sec-°F.

9.0 Conclusions

The heat exchanger K-factor derived by this Appendix was conservatively derived and is reasonable andexpected with consideration with the inputs. The result of this calculation will serve as conservative inputto containment analysis that will be used for main calculation.

SI iI~II

I I I

APPENDIX B

Calculation No. MDQ099920060011 Rev: 0 1 Plant: BFN Unit 0 1 Page: BI of 4


1.0 Purpose

The purpose of this Appendix is to calculate the heat load rate contribution of the reactor water recirculationpump motors to the containment. The result of this calculation serves as input to containment analysisthat is used in the main calculation to provide time histories of the event sequences.

2.0 References

2.1 Cameron Hydraulic Data - 19 th Edition.

3.0 Design Input Data

3.1 Rated horsepower of the reactor water recirculation pump motors is 8657 hp per page B3 of thisAppendix.

3.2 The efficiency of the reactor water recirculation pump motors is 96.1% per page B4 of thisAppendix.

4.0 Documentation of Assumptions

4.1 All horsepower lost due to inefficiencies is converted to heat that warms the drywell. Justification- This will provide the most containment heat lost due to pump motor contribution at the time ofthe ATWS and Appendix R events to predict conservative drywell cooler performance.

4.2 Two Recirculation pumps are running at 100% rated flow. Justification - This will provide themost containment heat lost due to pump motor contribution at the time of the ATWS andAppendix R events to predict conservative drywell cooler performance.

5.0 Special RequlrementslLimlting Conditions

None.

6.0 Computations and Analysis

6.1 Methodology

This Appendix takes the rated horsepower of the reactor water recirculation pump motors anddetermines how much horsepower is lost due to inefficiencies. The lost horsepower Is converted toheat rate using standard conversion factors.

6.2 Analysis

Efficiency loss = (100% - Efficiency)/1 00, thus

Efficiencyloss = (100% - 96.1%)/100

Efficiency loss = 0.039

The per pump horsepower loss is given by

Horsepower loss/pump = (Efficiency loss) x (rated horsepower)

Horsepower loss/pump = (0.039) x (8657 hp) = 337.623 hp

APPENDIX B

Calculation No. MDQ099920060011 Rev: 0 1 Plant: BFN Unit 0 1 Page: B2 of 4


The horsepower lost for two pumps = 337.623 x 2 = 675.246 hp

Converting to a heat rate (Btu/sec):

(675.246 hp) x (42.43 Btu/min) x (1 min/60 sec) = 477.5 Btu/sec

7.0 Supporting Graphics

None.

8.0 Summary of Results

This calculation establishes that the heat load rate contribution to the containment for the reactor waterrecirculation pump motors is 477.5 Btu/sec.

9.0 Conclusions

The heat load rate contribution of the reactor recirculation pump motors as determined by Appendix wasconservatively derived and is reasonable and expected with consideration with the inputs. The result ofthis calculation will provide the most containment heat lost due to pump motor contribution at the time ofthe ATWS and Appendix R events to predict conservative drywell cooler performance. The coolerperformance will serve as conservative input to containment analysis that will be used for maincalculation to provide time e histories of the event sequences.

10.0 Attachments

None

APPENDIX B

I Calculation No. MDQ099920060011 APPENDIX BRev: 0 1 Plant: BFN Unit 0 1 Page: B3 of 4


GE Industrial Systems

* -GE Motors - DATA SHEET - custom aooo RSQUIRREL CAGE MOTOR

CUSTOMER 'IVA BROWNS FERRY/ GE NUCLEAR

CUSTOMER ORDER 00001704 013431431005962

GE MODEL 291R610 DESIGN KC899R240BSO : 2880034/2880035 RI :132-14187/02/03OTY :1l1 SERIAL : 2880000421288=0043

POWER 8657 HP TYPE :KVPOLES : 04 FRAME : 8800VOLTAGE : 3965 V ENCLOSURE / COOLING : ODPFREQUENCY : 56.6 Hz SERVICE FACTOR :1.0 @ CLASS B RISEPHASES : 03 INSULATION CLASS F (POLYSEAL)TEMPERATURE RISE :73=C /TO @ SF1.0 TEMPERATURE CLASS : B

DRIVEN LOAD : PUMP MAX. ALTITUDE : 3300 ft

LOAD WK2 REF.TO MOTOR SHAFT :12872 LbftI AMB. TEMP. (MINIMAX) -18/57 C

Calculated Performanoe

RATED RPM :1682 NEMA STARTING CODE : ERATED CURRENT :10566A LOCKED ROTOR CURRENT : 570%RATED TORQUE : 26960 LbR LOCKED ROTOR TORQUE :60%RATED KVA : 7383 PULL UP TORQUE : 60%STATOR CONNECTION : Y BREAKDOWN TORQUE :175%MIN. STG .VOLTAGE : 90% V COUPLING TYPE : FIXED (')TIME RATING : CONT ARRANGEMENT : Vt - SOUD SHAFT

ROTATION : CCW FROM TOP

TOTAL WEIGHT (calckuated) : 40000 LbROTOR WK2 (calculated) :15700 Lbf2 MAX. BRG.VIBFL pk] : .12 lrnSec

BEARING TYPE :SLEEVE (M)BRO WBRIC(UPPER WER) : OIL/OILEND PLAY : 0.01 In

STATOR RESIST. @ 25C : 0.0139 Ohms L-L LOCKED ROTOR TIME (100% V)COLD: 20s

XIR RATIO : 38.700 (NEMAMG1-20.43) HOT: 15sOPEN CIRC. TIME CONSTANT : 2.6680 s

NUMBER OF STARTSOUTLINE NUMBER : M88D100134 COLD :2INSTRUCTION BOOK : LATER HOT: 1

STATOR/ROTOR (SLOTS) :96/110

NOTES ,VIBRATION UMITS BASED ON MOTOR RUNNING UNCOUPLED AND WITH BEARING TEMPERATURE STABIUZED IN STIFF BASE.(A) PROVIDED BY CUSTOMER.(M) UP THRUST RG - JV I5"M DOWN THRUST BRG- JV 15 1I2(M) UPPER SLEEVE GUIDE BRG -8' (TAPERED LAND)M") LOWER SLEEVE GUIDE RG- 10-

SERVICE FACTOR @ CLASS F RISE (LATER)SH 1 OF2

PREPARED BY : OSVALDO AK]RAAPPROVED I DS2880034

APPENDIX B

I Calculation No. MDQ099920060011 Rev: 0 1 Plant: BFN Unit 0 1 Page: B4 of 4


GE Industrlal Systems

GE Motors - DATA SHEET- custom aoo (MTSQUIRREL CAGE MOTOR

MODEL: 291R610 SO: 2880034/2880035 RI: 132-1-6167102/03

Calculated Performance

No Load i 159

100 0.91 9 6.1 106675 0.91 9610 801so 0.90 95.4 543

ACCESSORIES TESTS

6 STATOR THERMOCOUPLE COPPER CONSTANTAN-T AIR GAP MEASUREMENTS12 HEATER 3600W - 3 PH DC HIGH POTENTIAL TESTI VIBRATION DETECTOR - R. SHAW # 68-A7 HEAT RUN STATOR AND BEARINGS (DUAL FREQ) AT REDUCED LOAD4 SRG THERMOCOUPLE-COPPER CONST-DOUBLE'T HIGH POTENTIAL TEST

INSULATION RESISTANCE TO GRDNO LOAD TESTNOISEPOLARIZATION INDEX (BEFORE VPi AND FINAL ASSY)POWER FACTOR TIP-UP TEST

NOTES STATOR CORE TESTTORQUE & STARTING CURRENT

EQUIVALENT RATING: WINDING RESISTANCE (BEFORE VPI; FINAL)9177 HP - 4200 V - I066 A - 1787 rpm - 60 Hz PHASE SURGE TEST (BEFORE VPI; FINAL)

AC HIPOT (BEFORE VPI AND FINAL ASSY; FINAL)STATOR THERMOCOUPLE LOCATION SPRAY TESTTC SLOT PHASE TC SLOT PHASE SHAFT VOLTAGE#1 #1 A #7 #25 A (SPARE) LOCKED ROTOR TEST AT REDUCED VOLTAGE# 2 # 9 C #8 #33 B (SPARE) ROTOR THERMAL STABILITY TEST (COLD AND HOT#3 #17. B #9 #41 C(SPARE) . VIBRATION MEASUREMENT)# 4 #49 A BEARING INSULATION RESISTANCE TEST#5 #167 C SHAFT CRITICAL SPEED TEST (COAST DOWNN6 165 B SPEED I TORQUE AND SPEED tCURRENT

REED FREQ TEST

REVISIONS[1 Aocosdng to customer comments.[2] Accordlng to custom comments.(31 Accordlng to customer comments.[41 According to customer comments.(81 AccordIng to customer comments.[6] Accoiding to customer comments.

PREPARED BY OSVALDO AKIRA SH2 OF2

APPROVED : DS28003408-30-2006e REV : 06

APPENDIX C

Calculation No. MDQ099920060011 Rev: 0 1 Plant: BFN Unit 0 1 Page: C1 of 3


Excel Spreadsheet Computations

The spreadsheets used to develop the transient available NPSH curves and required containmentpressure curves are setup with the GE transient containment parameters in the left hand columns,followed by three columns listing the atmospheric pressure, pool vapor pressure, and temperaturedependent conversion factor for converting pressure to water head. The remaining columns to theright list the steady state NPSH case input in a block in rows 2-6 and the adjusted transientparameters below that for each pump considered for the subject event. An extract of the LOCAspreadsheet is presented on the following page and is typical of the other files.

The spreadsheet files identified as follows for each event are stored electronically as indicated onpage 6:

• EPU RAI 6 LOCA.xls* EPU RAI_6_ATWS.xls" EPU RAI 6 APPR.xls" EPURAI_6_SBO.xls

APPENDIX C

Calculation No. MDQ09920060011 Rev: 0 1 Plant: BFN Unit 0 1 Page: C2 of 3


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APPENDIX C

Calculation No. MDQ099920060011 I Rev: 0 1 Plant: BFN Unit 0 1 Page: C3 of 3APPENDIX

CSubject:


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____ HW 1__ 4A -1=fe(M0 4 $,$0G* -215 ______ 1 3043 ___ 14.1 IP103& 14U 40203"30 _37 413 ___7 __114. .4 37.0 ___ =703 00$651$7S40 =7 -50 . 00-.74 21A 2 ______=47-37 -___ 14-44P3747l -5037-S37 ___ ___

39 - 10___14.4 =144% p32.03 ___~o 05355- 421 _ ___=1430,039 ___ 14,4jP30430YLL0 40G30.830 __ _40~~~~ -440 ___ 144p(1 4 .0) __ 45+ 25______ .40____ 14 P4401.4 04.40___ __H41i _ -14 10 -"M+SS-J1- 4152 _____ 414 ___ 1.P101 4 0101___ ___

143 215 14.4___ .1"404 = 3&__ s1.1~444v144 ___40 -- 444 14.4 14. 0 __=00 5-20 004 5-.4 2014000___=41~44044 004 __

ATTACHMENT 1

Calculation No. MDQ099920060011 I Rev: 0 Plant: BFN Unit 0 Page: 1 of 2

!SULZER Traa27-t - ow

a.UI 41I iso i~ 71

Oporulng Hours

V1i July 14- 2006

ATTACHMENT I

Calculation No. MDQ099920060011 I Rev: 0 1 Plant: BFN Unit 0 1 Page: 2 of 2

!SULZER IJuly 11. 2006SU Z RTransdnt -NPSH Reltiew E12.5,12673wim Pwistm (USI hu II ,

D.01 CA 1 10 100-, 1000 00

rD

z.

z

Operating Hours

9 15 July 14. 2006

ATTACHMENT 2


D•2G11 cC~fON2'1

AfR RBCCW LATENT 1Cccs 10 OCOILS 10 CLS foCOUFLOW. INLET OULET FLOW. RIBCON RCCW SENSH.E HT. CONODENATE. SEI "LE HT, LATENT HT, TOTAL HT, CONDENSATE

CARE ACFU T.-W3 T-DB RNIl GPM IN OUT KT, BTUIMIE 5rW3 LOAIR "TUfSEC BTUGEC BiLVEC LDWScDE'4GW 102 1446 i 2 q= '115 C '27 102 129. 692 0 m % 1647987 :20r

- g1 12445 i it. 4 2 274 10 12.3 s8666 D mCO lC c6z0 22119=02 U446 113 43 '27 4 102 I2._4 661042 14318 14.76 16.4 -ZI *66 Z.4

1 1I2 *446 5 '17.1 -c 2714 102 11.4 W0662 221840 235L92 1427 6W8 204 1.63 19t= 'A4 5 '311 2 -2 74 i10 122.47 25M94 12743•6 1.10 5; 3w 42 3m66

2 c-- 1!C 144 263 12 1274 102 13C, 1 l14gXC 21026M2 21676 31 384 6160 ý6 1202 .3!Z7 'C6,1 SC 177 4 w6 t:A,3 62016 72C29 74.%6 14:J6 20C i64 1117 1IN= I2M7 1269 122 1274 A 9 121.6 37SW 163863 '742.9% 3132 4698 8079 4.8

RAI-&1 IMN 180 1152 40 IVA 13 110. 8036 254w 260 32 71 19w OUT7RM-6.2 "am 1i 1185 45 1274 I 112.45 41011M 1S 20., ow 543 2230.RAO4, lim 180 a216 50 127A la 114&16 562257 3 38,172 1534 139 2802 IMO

ATTACHMENT 2


v7-26-OOv 1:1659 PROTO-HX 4.01 by Proto-Fower Corporatio (SNt•THX-1027) Pe 1TVA

Cacuation Rqxpt for BFN2CCL-070-740 - Dqywell Air Cooler15G, F5RH, EPURM6 INIALcOND1rDN

Cakulation SpecificationsCosta Inlet Tempeu Method Was UsedEtrpolation Was to User Specified ConditionsDesign Fouling Facbrs Were Used

Test DataData DateAir Flow (acm)Air Dry Bulb Temp In ()Air Dy Bulb Temp Out (MF)ReAtive Humidity In (%)Reative Humidity OutWet Bulb Temp In F)Wet Bulb Temp Out ('F)Amuospheric Presur QDSia)Tube Flow (gpym)Tube Temp Ik ('F)Tube Temp Out (TF)Condesate Tempture ()

Extrapolation DataTube Flow (gpm) 127.40Air Flow (acfin) 19,000.00Tube lnet Temp (-F) 100.00Ai nlet Temp (-F) 150.00Inlet Retive Humidity () 50.00Inlet Wet Bulb Temp ('F 0.00AtmoVhic PArue. (pOia) 15500

'*AkMmsVeiaciy (LbmIu*), TDdbe bmdVekociy (franc);Ak Dncaxat InlT ,OderPs enies atAvrge T

ATTACHMENT 2


o7-26-200d 17:1t9 PROTO-HX 4.01 by Proto-Power Corporation (SMkTHX-102T)WA

CalculationReport for BFN2CCL-070-740 - Drywell Air Cooler15F, 50%RH, EPURAI 6DINT1ALCOND1TION

Pw 2

Extrapolation Calculation Summary

Air-Side Tube-SideMass Flow (bni'r) 68,5034 63,353.58 Tube-Side hi (BTU/hrf•-rF) 0.00Jnlet Temperature M 150.00 100.00 j Factor 0.0000Outlet Temperature (7') 121-53 114.16 Air-Side ho (BTU/br-f f-F) 0.00Inlet Specific Humidity Tube WallmResistace (hr---F/BTUr 000016250Outlet Specific Humidity Overall Fouling (hr-12-'F1BTU) 0.00412059

U Overall (T hr-f-'F)Effective Area (if) 2,046.63LMTD 0.00Total Heat Trmnsfenied (BTU/br) 922,338

Surface Effectiveness (Eta) 0.o0ooSenuble Heat Transfend (BTU/lr) 552,067Latent Heat Transferred (BTU/br) 370,265Heat to Condensate (BTUfhr) 26,889

Extrapolation Calculation for Row 1(Dry)

Air-SideMass Flow (ibmU ) 63,.50.34Inlet Tempenature (MF) 150.00Outlet Temperature (MF) 142.29Inlet Specific Humidty 0 08483gOutlet Specific H~imdity 008483Average Temp ('F) 146.14Skin Tempemtue (CF) 116.29V) *** 5.047.79Renola's Number 1.849-Pra;ndNumber 0.7253Bulk Vise Ma -thr) 0.0491Skin Visc Obm/•-r) 0.0000Density (ftm ) 0.0612Cp (BTU -bm'F) 01402K (BlTJthr-eft-) 0.0163Relative Humidity In (C.) 50.00Relative Humidity Out (%/) 60-67

Tube-Side63,353-59

111.80114.16

112.9785114.9949

6264I542,4973.91441.44071A125

61.81720.99880.3676

Tube-Side hi (BTU 1b-'-°F)j FactorAir-Side ho (BTU/hr-f-oF)Tube Wall Resistance (br-Ife-F/BTIJOverall Fouling 0zr-ftF/BTU)

U OveraU (BTU/hr-fr-*F)Effective Area (if)LMTDTotal Heat Transfmed (BTU~Ir)

Surface Effectiveness (EtaSensible Heat Transferred (BTU/hr)Latent Heat Transfered (BTU/hr)Heat to Condensate (BT/h)

1,801.200.0103

15.460.000162500.00412059

13.29341.1133.01

149,618

0.9743149,618

** R~ynod& )&-b- Owmi&d Iange afEqu ztmAffh-Wfl~iy

'**Air m-ssvelociyW (L nxi), Tage F) dve tyft&ýuc) AkDemsntyxtnkeT. OtherPnpeniesxmAvepT

ATTACHMENT 2


01.26-,26 17:-i&6 PROTO-HX 4.01 by Prato-FPwer Corporation (SN#PHX-1027)TVA

Calculation Report for BFN2CCL,070-740 - Drywell Air CooleriMF, 5MOA EPU IAI 6 IN•7IAL Ca ITION

Pw 3

Extrapolation Calculation for Row 2(Dry)

Air-Side Tube-SideMass Flow (Ibmolk) 68,85034 63,353-58 Tube-Side hi (BTU/hr-fl-t F) 1,779-92Inlet Temperature (MF) 14229 109.79 j Factor 0.0103Outlet TemperatUre ('F) 135.75 111.0 Air-Side ho (BTU/hr-ft.*F) 15.40Inlet Specif Humidity 0.084938 Tube WallResistae (hr-fi-'F/BTU, 0.00016250Outlet Specific Humidity 0.084&38 OverallFouling (hr-fl-'FIBTU) 0.00412058Average Temp ("F) 139.02 110.7941Skin Temperature ('F) 114.12 112.5236 U Overall (BTU/hr-W-OF) 13.24v c *** 5.047.79 6.2613 Effective Area (i') 341.11

Number 1.m- 41,586 LMTD 28.09Prandtl Number 0.7259 4.0087 Total Heat Tranferred (BTU~hr) 126,815Bulk Visc (ibmt-hr) 0.0487 1.4723Skin Visc (lbm/ft-hr) 0.0000 1.4472 Surface Effectiveness (Eta) 0.9744Ds (lwr 0.0618 61.87 Sensible Heat Transfed (BTU/br)15

T/m-k"F) 01402 0_9988 Latent Heat Transferred (BTU/br)K (BTUJhr-ft-'F) 0.0161 03668 Heat to Condensate (BTU/Ir)Relative Hmduky () 60.67Relative Himidity Out (%) 71.82

'q Ra&ua *- z m &Ru p OfEtptioAnra) .y

Extrapolation Calculation for Row 3(Dxy)

Air-SideMass Flow (bmir) 68,9"034Inlet Temperature (MF) 135.75Outlet Temperature (MF) 130.20Inlet Specifc Hmidity 0.04838Outlet Sped Hudty 0.0848Average Temp (M) 132.97Skin Temperature ) 111.78Vdcitv *** 5.047.7911's Number 1.880"'Prannd Number 0.7264Bulk Vise (lim/nfi-hr) 0.0483Skin Visc (lbn/ft-r) 0.0000Denity (bmf) 0.0624Cp (BTUbmý:F) O.24O2K J/by-ft-'F) 0.0160Relative Humidity In C%) 718.2Relative Hfumidity Out ('/.) 83.16

Tube-Side63,353-58

108.09109.79

108.9416110.4243

6258740,8194.09171.49991.4777

61.87490.99850.3662

Tube-Side hi (BTU/h-1.fr-MF)j FactorAir-Side ho (BTU/hr4-*wF)Tube Wall Resistane (hr f -OF/BTU,Overall Foling (hrf--v'F/BTIJ)

U Overall (BTUbnr-W.OF)Efkctm Are (fe)LMTDTotal Heat Tanseed (BTU4ir)

Surface Effectiveness (Eta)Sensible Heat Transferred (BTU/br)Latent Heat Transferred (BTU/hr)Heat to Cmdensate (BTU/br)

1,761.820.0102

15-350.000162500.00412058

13.19341.1123.92

107,615

0-9745107,615

" Ray4ds& N-9- ut=& Kni afBqpiim Applcability

'~'AirMas Vlocty J~mliS9,I~e I dVelocay sec) Aff Density a -t aTOtherPwpezresatAveageT

ATTACHMENT 2


*7-26-,O 17:1639 PROTO-HX 4.01 by Froto-Power Corporation (SN#ITHX-1027)TVA

Calculation Repo for BFN2CCI070-740- D-ywell Air CoolerU1F, 50%RH, 33 RKI 6 IDITJAL CMOnK

P] 4

Exrapolation Calculation for Row 4(Dry)

Air-Side Tube-SideMass Flow obmnhr) 6 50.34 63,353.58 Tube-Side hi (BTU/br-fl'-'I) 1,74640Inlet Temperature (MF) 130.20 106.65 j Factor 0.0102Outlet Temperature MF) 125-49 108-09 Air-Side ho (BTU/hr-f-oF) 15-31Inlet Specific Hmidity 0.084838 Tube Wall-Resistae (hr-f'-`F/BTUQ 0.00016250Outlet Specific Humidity 0-084838 Overall Fouling (hr-ifi-F1BTU') 0.00412058Average Temp ('F) 127.14 1073689Skin Tem=erare ('F) 109.79 108.6395 U Overall (BhU -JP.Wfl-F) 13.15Velocity 5.047-79 62565 Effective Am (Wf) 341-11Reyiows Number 1.93** 40,171 LMTD 2038

Pant uber 0-7268 4.1643 Total Heat Transferred (BTU/hr) 91,416Bulk Vise (Ibm, t-hr) 0.0480 1-5241Skim Visc ( -inft-br) o.oooo 1-5045 Surfac Effectiveness (Eta) 0-9746

"De~y (Run/) 0.0629 61.896 Sensible Heat Transfemed (BTU/Hr) 91,416M tUbm=.'F) 02402 0.9989 Latent Heat Transerred (BTU/hr)

K (BT ~u/r-ft-4 F) 0.0159 03656 Heat to Condensate (BTU/lr)Relative Humidity In (' 9 3-16Relative Humidity Out CYh) 94-42

*4 s N]- Oauf Rsu p o n gA zl. oon for oow ry)iy

Extrapolation Calculaton for Row 5MDzy)

Mas Flow Obmi~)Inlet Temiperature M'F

Outlet Temperaure (MInlet Specifi ThinndityOutlet Specific HumdityAverage Temp (T')Skin Temperature (M)

PrandU NumberBulk Vis (Rn/ft.Ihr)Skin Vis (IbmM-hr)Density (An/)Cp (BTUftbm-"')K TUhr-f--*F)Relative Humidity LIn(.Relative Hunidity Out C(1)

Air-Side6%850.34

125.4912339

0.0848380.084838

124.44108.47

5.047.79

0.72710.04780.O0000.06290.24020.015894.42

100.00

Tube-Side63,353_U

106.00106.65

106-3245107-4529

6.255039.743421371.54051.5228

61_91110.99890.3652

Tube-Side hi (BTU/br-flr-F)j FactorAir-Side ho (BTU/hr-fl1-F)Tube Wall Resistance (hr-Wft-F/BTUOverall Fouling (r-w--w iTU)

U Overall (BThfr-fWt.F)Effective Ame (ft)LMTDTotal Heat Transferred (BTUfar)

Surfa•ce Ffectiveness (Eta)Sensi&e Heat T-ansferred (BTUihr)Lateat Heat Tran•sfered (BTUhr)Heat to Condensate (BTU/br)

1,736.140.0102

15280.000162500.00412058

13-12171.6418.09

40,753

0.974640,753

" R~nl& NAb~rumd 0=& p aiR utm AFplkabi~Iy

-Ak Mass vejodzy(J~mu-, Tube iutd Veocity W-tiec AirDmnstyazhxtbdtr Otherk~rupiu st Aver T

ATTACHMENT 2

I Calculation No. MDQ099920060011 I o 0 Plant: BFN Unit 0 1 Page: 6 of 7

o0-200o0 17m:ms PROTO-ZX 4.01 by Prato-Power Corporation (SNAlHX-1027)TVA

Calculation Repmt for BFN27CCL-740 - Drywell Air CoolerOF, W0%RKBPURAI 6 INITIALCONDnIO

pw s

Extrapolation Calculation for Row 5(Wet)

Air-Side Tube-SideMass Flow (Obm• r) 68,85034 63,353.58 Tube-Side hi (BTU/br-r-Ok) 1,730.22Inlet Temperature M 12339 104-12 j Factor 0.0102Outlet Tenqmerature (7F) 122-12 106.00 Air-Side ho (BTU/ar-f1-*F) 75.22Inlet Specific Huaidity 0.084838 Tube Wall Resistance hrr -F/BTLU, 000016250Outlet Specific Hmnidity 0.083331 Overall Fouling (hrmf-'F/BTU) 0.00412051Average TemopC ) 123.10 105.0625Skin Temperature ('F) 111.17 108.6458 U Overall (BMfiUr-fF-OF) 41.70Veloctyv *** 5.047.79 6.2533 Effective Area ( 169.47Reynlaos Number 1.905" 39,228 LMTD 12.02Prxnl Number 0.-7272 42746 Total Heat Tnafderred (ETU•hr) 127,362Bulk Visc (bmfti-hr) 0.0477 15608Skin Visc (lbmlft-hr) 0.0000 1-5044 Surface Effectivees (Eta) 0.8902fljo (l ) 0.0633 61.92S2 Sensile Heat Tmsfrred (BTU/hi) 1O,997

Bt = F) 02402 0.9989 Latent Heat Transferred (BTU/br) 116,371K (BTU/hr-fl-OF) 0.0158 0.3647 Heat to Cmdensate (BTUI-r) 85WRelative Humidity In (%) 100.00Relative Humidity Out (%) 100.00

Rqh ads WNwut O~u&sd Razg ofEq-= oAV~I*-Wnliy

Extrapolation Calculation for Row 6(Wet)

Mas Flow (bmn4r)Inlet Temperature C'F)Outlet Temperature (F)Inlet Specific HumidityOutlet Specific HumidityAverage Temp MSkin Temperature ('F)

RyodsNumberPnmdt NumberBula Vise (HuMitur)Skin Visc (lbmlft-hr)Densit (IbmWf)Cp (BTU/lbm-0F)K (BT~f=-ft-*F)Relative Humidity In C%)Relative Humidity Out C1.)

Air-Side698950.34

122.82121.53

0.0833310.080042

122.17109-55

5.047-791.907*

0.72730.04760.00000.0638014020.0157100.00100.00

Tube-Side63,353.58

100.01104.12

102.0691106.0385

6-24933s,0154.42501.61061.5451

61.96780.99890.3636

Tube-Side hi (BTUI/hr- -OF)j FactorAir-Side ho (BTU/Tru'•r-IF)Tube Wall Resistance (hr f-'-/BTUrOverall Fouling (hr-W-*F/BTU)

U Overall (B¶fhr-t.'F)Effective Area (W')LMTDTotal Heat Transferred (BTU/br)

Surface Effectiveness (Eta)Senmible Heat Trxnferred (BTU/hr)Latent Heat Tranferred, (ETUEhr)Heat to Condensate (BTU&b)

1,702.670.0102

72.770.000162500.00412058

40.80341.11

20.03278,758

0.893224,852

253,8931 ,300

" ldnaI&W-A- Outsi R-p aq= A~pich-ifliy

-Air mas vewMd (Lbmur-", Itiie Flui Valobm (ftauc Air Denmiy at Wne T. OlberPnaeriies st Asuzug T

ATTACHMENT 2


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Documents

Calculation MDQ099920060011, Rev. 0, 'Transient NPSH ... · TRANSIENT NPSH/CONTAINMENT PRESSURE EVALUATION OF RHR AND CORE SPRAY PUMPS 2.14 EPU FTR T0400 R1, Containment System Response