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STANDARDS f o rSTEAM SURFACECONDENSERS

TENTH EDITION"Copyright September 2006 byHeat Exchange Institute1300 Sumner AvenueCleveland. Ohio 44115-2851

Reproduction of any portion of this standard without written permission of theHeat Exchange Institute is strictly forbidden.

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HEATEXCHANGEINSTITUTE , INC .STEAM SURFACE CONDENSERSDC Fabricators, Inc.Florence, New Jersey

Thermal Engineering International(USA) Inc.Santa Fe Springs, CaliforniaYuba Heat Transfer, LLCTulsa, Oklahoma

Holtoo InternationalMarlton. New Jersey

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CONTENTSPage1.0 NOMENCLATURE 1

2.0 DEFINITIONS2.1 Absolute Pressure 32.2 Circulating Water Velocity 32.3 Cleanliness Factor 32.4 Condensate Depression 32.5 Condenser Duty............................................................ 32.6 Condenser Heat Transfer Coefficient 32.7 Condenser Pressure.................... 32.8 Condensing Steam Temperature 32.9 Effective Surface 32.10 Effective Tube Length 32.11 Hotwell Capacity 32.12 Initial Temperature Difference 32.13 Logarithmic Mean Temperature Difference 32.14 Static Pressure 32.15 Temperature Rise 32.16 Terminal Temperature Difference........................... 3

3.0 SYMBOLS AND UNITS......... 4-54.0 CONDENSER PERFORMANCE................................................................ 64.1 General Considerations 6

4.2 Heat Transfer Rates.............................................................................. 64.3 Oxygen Content of Condensate 134.4 Performance Curves................................................................................................... 154.5 Hydraulic Loss-Circulating Water Pressure Loss....... .. .. .. ... .. .. .. .. .. ... .. .. .. ... .. .. . 154.6 Condensate Temperature Depression inMulti-Pressure Condensers 174.7 Geothermal Applications.... 28

5.0 SERVICE CONNECTIONS ,. 295.1 General Considerations 295.2 Flow Data 295.3 Connection Locations 295.4 Connection Design Guidelines 305.5 Turbine Bypass Guidelines......... 30

6.0 VENTING EQUIPMENT CAPACITIES.................................................................................... 326.1 Venting Requirements............... 326.2 Design Suction Pressure................................................................... 326.3 Design Suction Temperature 326,4 Calculation of Water Vapor Load Component 326.5 Minimum Recommended Capacities 326.6 Rapid Evacuation Equipment 33

7.0 ATMOSPHERIC RELIEF DEVICES 387.1 General " 387.2 Atmospheric Relief Valves 387.3 Rupture Devices 38

8.0 CONSTRUCTION .. 398.1 General................. 39R.1.1 Design Philosophy 398.1. 2 Materials of Construction 398.1.3 Design Prcssurea.... 398.1.4 Hydrostatic Testing. 39

8.1.5 Corrosion Allowances.................. 408.2 Design And Construction Methods 418.2.1 Design Factors of Safety...................................... 418.2.2 Design By More Exact Analyses and By Empirical Formula and Testing............... 418.2.:3 Shell Design 41H.2.4 Support Plate Design Guidelines .. '" 43

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CONTENTS (continued)8.2.5 Water Box Thickness Design Guidelines 478.2.6 Design Procedures For Flanges and Bolting........................ 49R2.7 Tubesheet Design Guidelines 498.2.8 Condenser Tube Ends.................................................................................... 538.2.9 Tubesheet and Support Plate Hole Criteria 538.3 \Velding.................................................................................................................. 558,4 Lagging for Extraction Lines and Feedwater Heaters.................................................... .. 558.5 Fabrication for Geothermal Service.............................................................................. 578.6 Condenser Support Systems 58

9.0 INSPECTION, QUALITY, TRANSPORTATION, AND FIELD INSTALLATION .9.1 Inspection and Quality of Welding Standards ..9.2 Surface Preparation Requirements ..9.3 Painting, Coating, Linings, and Corrosion Protection .9.4 Quality Assurance ..9.5 Dimensional Tolerances ..9.6 Shipping and Site Storage .9.7 Field Installation .9.8 Erection Superintendent Duties .9.9 Post Erection Walk Down .

APPENDICESAPPENDIX AAPPENDIXBAPPENDIXCAPPENDIXDAPPENDIXEAPPENDIXFAPPENDIXGAPPENDIXH

TABLESTABLE 1TABLE 2TABLE 3TABLE 4TABLE 5TABLE 6TABLE 7TABLE 8TABLE 9ATABLE 9BTABLE 9CTABLE 10TABLE 11TABLE 12TABLE 13TABLE 14TABLE 15TABLE 16TABLE 17TABLE 18FIGURES

FIGURE 1FIGURE 2FIGURE 3FIGURE 4FIGURE 5FIGURE 6FIGURE 7FIGURE 8

Typical Specification for Steam Surface Condensers .Metric Conversion Factors ..Areas of Circular Segments .Procedure for Calculating Allowable Nozzle External Forces andMoments in Cylindrical Vessels ..Air and Water Vapor Mixture Data (Dalton's Law) ..Mechanical Characteristics of Tubing .Troubleshooting Guide .HEI Surface Condenser Data Sheet ..

Uncorrected Heat Transfer Coefficients U1 .Inlet Water Temperature Correction Factor Fw ..Tube Material and Gauge Correction Factors FM ..Venting Capacity and Oxygen Content ..Gauge Correction Factor for Friction Loss R2 ..Materials for Condenser Tubes .Tube Characteristics .Rapid Evacuation Equipment Capacities ..Venting Equipment Capacities: One Condenser Shell .Venting Equipment Capacities: Two Condenser Shells .Venting Equipment Capacities: Three Condenser Shells ..Atmospheric Relief Valve Sizes .Typical Materials of Construction .Correction Factor K1 .Correction Factor K2 .Correction Factor K3 .Support Plate Hole Size Limits .Tubesheet Hole Size Limits .Weld Acceptance Criteria .Condenser Surface Preparation Requirements .

Uncorrected Heat Transfer Cofficeints U1.. 8Inlet Water Temperature Correction Factor Fw 10Absolute Pressure Limit Curves for Oxygen Content.......................................... 14Sample Performance Curve 15Absolute Pressure Limit Curves..................................................................... 16Friction Loss for Water Flowing in 18 BWG TUbes RT 18Temperature Correction for Friction Loss in Tubes R 1 19Water Box and Tube End Losses Single Pass Condensers RE 20

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FIGURE 9FIGURE 10FIGURE 11FIGURE 12-13FIGURE 14FIGURE 15FIGURE 16FIGURE 17FIGURE 18FIGURE 19FIGURE 20FIGURE 21FIGURE 22FIGURE 23-24FIGURE 25FIGURE 26-28FIGURE 29FIGURE 30FIGURE 31FIGURE 32FIGURE 33FIGURE 34FIGURE 35FIGURE 36-42FIGURE 43FIGURE 44FIGURE 45FIGURE 45M

CONTENTS (continued)Water Box and Tube End Losses Two Pass Condensers RE .Water Box and Tube End Losses Three Pass Condensers RE .Water Box and Tube End Losses Four Pass Condensers RE .Point Support - Pipe .Point Support - Double Clips .Point Support - Single Clips .Ribs .Design Nozzle Loading on Flat Plate .Spacing of Longitudinal Stiffeners .Cylindrical Condenser Shell Thickness .Stiffening Rings Required Moment ofInertia I .Determination of Lu .Rib Supported Panels .Bolting of Flat Faced Flanges .Gasket Seating Pressure .Required Flange Thickness .Idealized Representation of Tubesheet Loading .Tubesheet Showing Beam-Strip Locations ..Beam-Strip for a Tube Pattern of Triangular Pitch .Beam-Strip for a Laned Tube Pattern of Triangular Pitch ..Section AA through Beam-Strip of Figure 32 ..Structural Model for Beam-Strip of Figure 33 .Moment and Deflection Curves for Beam-Strip of Figure 32 ..Typical Condenser Welds ..Weld Geometries .Welding Nomenclature ..Standard Tolerances for Interfaces and Supports _ English Units ..Standard Tolerances for Interfaces and Supports - Metric Units .

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FOREWORDThe Tenth Edition of the "Standards for Steam Surface Condensers" represents another step in the HeatExchange Institute's continuing program to provide Standards that reflect the latest technological advance-ment in the field of condensing equipment.The Tenth Edition of "Standards for Steam Surface Condensers" has incorporated all information fromthe 9th Edition of Steam Surface Condensers as well as the Addendum to the 9th Edition. Also included inthe l .O" Edition is a new Table 3, which provides tube material and gauge correction factors. A sample ther-mal calculation has been added as Section 4.2.6. Table 6, entitled Materials for Condenser Tubes, has beenupdated and revised. Section 6.5.1.8 has been added to give users an example of sizing venting equipmentas stated in Table 9. Section 7.0, Atmospheric Relief Devices, has been completely rewritten and updated.Information on clad tubesheets and condenser support systems has been incorporated into Section 8.0 ofthe standard. Section 9.0 has been expanded to include information on dimensional tolerances, shippingand site storage, field installation, erection superintendent duties, and post erection walk down. AppendixA has been completely revised from the previous edition. Appendix D has been updated, providing informationon the procedure for calculating allowable nozzle external forces and moments in cylindrical vessels. Two

new appendices, Appendix G and Appendix H, have been added to the 10t.bEdition. Appendix G is a trou-bleshooting guide that has been added to assist operators of steam surface condensers, and Appendix H isa newly developed HEI surface condenser data sheet. The HE! Condenser Section has also developed aCondenser Rating Program. Please visit the HEI website, www.heatexchange.org, for more information.The Heat Exchange Institute anticipates a continuing program to extend and amplify the coverage pre-sented in these Standards and this may require the periodic issuance of addenda to these Standards. ARaresult, users of these Standards should make sure that they are in possession of all such addenda by enquiryto the Heat Exchange Institute offices.The Heat Exchange Institute solicits comments from all interested parties regarding areas where fur-ther treatment or more detailed treatment is desired for felt necessary. Contact the Institute at 1300Sumner Ave., Cleveland, OH, 44115, or visit the HEI website at www.heatexchange.org.

Heat Exchange Institute1300 Sumner AvenueCleveland, Ohio 44115 USAFax: 216-241-0105E-mail: hei@heatexchange.orgURL: www.heatexchange.org

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1.0 NOMENCLATURE

OPTIONAL SPRING SUPPORTIN UEU OF EXHAST NECKEXPANSION JOINT

I~ .r------,101I III, IF====='101I II II II I-.---,-

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1. STEAM INLET CONNECTION2. EXTENSION NECK3. TRANSITION PIECE~. VENT OUTLET CONNECTION5. CONDENSAT~~OUTLETCONNECTIONIi. CIRClTLATINCiWATER INLETOROUTLET7. TUBES

8. INLET-OUTLET WATERBOX 16. EXHAUST NECK EXPANSION JOINT9. RETURN WATERBOX 17. WATERBOXPASS PARTITION10. SHELL 18. SPRING SUPPORTS11. HOTWELL 19. SUPPORT FEET12. TIJRESHEETS 20. SOLl': PLATES13. TUBE SUPPORT PLATES 21. ANTI-VORTEX BAFFLE14. ACCESS ORINSPECTION OPENINGS 22. WATERBOXCOVER PLATE15. SHELL EXPANSION JOINT 23. WATERBOXDIVISiON PLATE

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TUBE AND SHELL CIRCUIT SCHEMATICS

{ _ n _ _ j - ONE SHELL ONE PASS

ONE SHELL S INGLE PRESSURE rwo PASS NON DIVIDED

S ING LE PR ESSUR E NON DIV IDEDi- - - - - - t------~ ~ - - - - - - - - E-----~----- ------_------ ONE SHE ll ONE PASS ONE SHELL SINGLE PRESSURE rwo PASS DIV IDED SING LE PR ESSUR E D IV ID ED ~ - n - - n t-------r - - - - - - - - -IG H P RE SS UR E(--------I--------L OW P RE SS UR E-------- ~ - - - - - - - t~----- rwo SHELLS MULTI PRESSURE ONE PASS W /CROSSOVER DIV IDED TWO SHELLS SINGLE PRESSURE ONE PASS DIVIDED

H IG H P RE SS UR E 1_ J -- -- - -1-- - ---H IG H P RE SS UR E I LO W PR ESS UR E- - - - - -1-- - - - -INTERMEDIATEPRESSURE ONE SHELL ONE PASS

MULn PRESSURE D IV ID ED

L OW PR ES SU RE

THREE SHELLS MULn PRESSURE ONE PASS W /CROSSOVER DIVIDED

2

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2.0 DEFINITIONS2.1 Absolute PressureAbsolute pressure is the pressure measured fromabsolute zero.2.2 Circulating Water VelocityCirculating water velocity is the average velocity ofcirculating water through the tubes.2.3 Cleanliness FactorCleanliness factor is the ratio of the condenserheat transfer coefficient to the clean heat transfercoefficient.2.4 Condensate DepressionCondensate depression is the difference betweenthe condensing steam temperature and the tempera-ture of the condensate in the hotwell,2.5 Condenser DutyCondenser duty consists ofthe net heat transferredto the circulating water. Unless otherwise specified,condenser duty is assumed to be the quantity of steam,in pounds per hour, entering the condenser multi-

plied by 950 Btu per pound for turbine service, or1000 Btu per pound for engine service.2.6 Condenser Heat Transfer CoefficientCondenser heat transfer coefficient is the averagerate of heat transfer from the steam to circulatingwater.2.7 Condenser PressureCondenser pressure is the absolute static pressuremaintained within the condenser shell at locations notgreater than one foot from the first tube. The distri-bution of measurement points shall conform withASME PTC 12.2, Steam Condensing Apparatus, latestedition.2.8 Condensing Steam TemperatureCondensing steam temperature is the saturationtemperature corresponding to the absolute static pres-sure of the steam.

2.9 Effective SurfaceEffective surface is the total surface measured onthe outside of the tubes between the inside surfacesof the tube sheets and includes internal and/or exter-nal air cooler surfaces.

2.10 Effective Tube LengthEffective tube length is the distance between inside

surfaces of the tube sheets.2.11 Hotwell CapacityHotwell capacity is condensate storage volume. Theminimum recommended hotwell capacity is the volumesufficient to contain all of the condensate produced inthe condenser in a period of one minute under condi-tions of design steam load.2.12 Initial Temperature DifferenceInitial temperature difference is the differencebetween the condensing steam temperature and theinlet circulating water temperature.

2.13Logarithmic MeanTemperature DifferenceLogarithmic mean temperature difference is theratio of the temperature rise to the natural logarithmof the ratio of initial temperature difference to terminaltemperature difference.

2.14 Static PressureStatic pressure is the pressure of a fluid at rest.2.15 Temperature RiseTemperature rise is the difference between outletand inlet circulating water temperatures.2.16 Terminal Temperature DifferenceTerminal temperature difference is the differencebetween the condensing steam temperature and theoutlet circulating water temperature.

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3.0 SYMBOLS AND UNITSAD Minimum Required Flow Area in2 Mn,Mc Moments in-lbAE Turbine Exhaust Flow Area f t 2 MG, MuAs Surface Area f t 2 MR Resultant Moment in-lbAT Inside Tube Flow Area ft2/pass MWNc Molecular Weight ofNon-Condensible GasBWG 'Iube Gauge MWwv Molecular Weight of Water VaporC Geometric Constant N Number of BoltsCA Corrosion Allowance III Number ofThbe Side PassesCc Column Slenderness Ratio NpP Beam Load lbCFM Gas Flow ft3/min PA Relieving Pressure psiaCp Specific Heat Btw1boF Pc Column Load lbD 'TUbe Outside Diameter in Po Design Pressure psigDr Tube Inside Diameter in PE End Load on Beam Strip lbDp Pipe Diameter in

PG Pressure Required toE Modulus of Elasticity psi Compress Gasket psiF Force Ib Ph Hydrostatic Test Pressure psigFe Correction Factor for Cleanliness Ps Saturation Pressure inHgAFM Correction Factor for Material PT Test Pressure psigand Gauge Pt Absolute "Total" Pressure atFR Resultant Force Ib Condenser Vent Outlet inHgAFS Factor of Safety Pw Absolute "Water Vapor"Fw Correction Factor for Water PressureCorresponding toFl, F2, Force Loading lb/in Temperature at CondenserFa Vent Outlet inHgAG Cutoff Point inHgA Pi Saturation Pressure atH Enthalpy Btu/lb Sonic Strata psiaI Moment of Inertia in4 Q Heat Duty BtuJhrlTD Initial Temperature Difference of R Radius inJ Zero Load Back Pressure inHgA R E Friction Loss (Water Boxand 'Iube Ends) ft of waterK Column End Condition Factor R r Friction Loss (Tubes) ft of water/KD Discontinuity Factor ft length(Geometry Dependent) RTr Friction Loss (Total) ft of waterKl Pressure, O.D. and Gauge Rl Correction FactorCorrection Factor (Water Temperature)K2 D.D. and Pitch Correction Factor R2 Correction FactorK3 Material Correction Factor (Tube O.D. and Gauge)1 \4 Flow Coefficient SCFM Gas Flow at StandardLc Column Height (Unsupported) ft Conditions of PressureLE Effective Tube Length ft and Temperature ft3/minLMTD Logarithmic Mean Temperature S Stress psiDifference of SA Allowable Stress psiLn Natural Logarithm SBOLTS Total Bolt Stress psiLb Beam Length in SG Specific GravityLu Uncorrected Support Plate Spacing in St Tensile Stress psiLs Shell Unsupported Length in Su Ultimate Stress psiLsp Support Plate Span in Sy Yield Stress psiLSP1 Intermediate Support Plate Spacing in T Temperat.ure ofLsP2 End Support Plate Spacing in TR Temperature Rise OFLT Total 'lUbe Length ft TID Terminal Temperature Difference O FLl Tube Length Between Tubesheet Tl Inlet Water Temperature ofand First Support Plate in T2 Outlet Water Temperature of

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Ts Saturation Temperature (Steam) of aG Area of Gasket in2TCHP Temperature ofCondensate aM Area in2Leaving High Pressure Shell of Tube Flow Area in28FTSHP Saturation Temperature Higherl ceIL Cubic Centimeter Per LiterHighest Pressure Shell ofTSIP Saturation Temperature d1 Diameter inIntermediate Pressure Shell OF dH Tube Hole Diameter inTSLP Saturation Temperature Lowerl e Efficiency Factor (Welds)Lowest Pressure Shell of es Ligament EfficiencyU Heat Transfer fG, fH Correction FactorsCoefficient Btulhrft2.oF g Acceleration of Gravity ftlsec2U1 Uncorrected Heat h Tube Ligament mTransfer Coefficient Btulhrft2.oF k Thermal Conductivity Btulhrft2oF/ftVs Velocity of Steam It/sec ks. kT Spring Constants lb/inVw Velocity ofWater ftlseeW Pounds ofWater Vapor per n IntegerPound ofNoncondensible Gas p Tube Pitch inW e Weight Per Unit Length ppb Parts per Billionor the Tube lb/in r Radius ofGyration inWm Weight Per Unit Length tp,tH Thickness (No Corrosion Included) inofthe Tube Material lb/in ts Thickness of Support Plate inWt Weight Per Unit Length of the tw Tube Wall Thickness inTube Side Fluid lblin Specific Volume ft31lbWs Steam Flow lb/hr Width inWG Water Flow gpm 81.b1.Cl Linear Dimensions and Measure inWLP Total Fluids Entering gh hI, It Linear Dimensions and Measure inLowerlLowest PressureCondenser Shell lblhr el, e2 Linear Dimensions and Measure 10W1P Total Fluids Entering Xl, Yl Linear Dimensions and Measure inIntermediate Pressure a Coefficient ofThermalCondenser Shell lblhr Expansion in/in-oFWHP Thtal Fluids Entering Higher/ p Density lb/in"Highest Pressure Condenser v Poisson's RatioShell lblhrZ Section Modulus in3 \jJ Reduced Geometry Factor

Tensile Area of Bolts in2 {) Deflection inBBOLTSac Metal Area ofColumn in2

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4.0 CONDENSER PERFORMANCE4.1 General Considerations4.1.1 It i~ recognized that the performance of a con-denser cannot be exactly predicted under each one ofa number of possible operating conditions. Con-sequently, curves or tabulations of condenser perfor-mance data are only approximate, except for onespecific condition termed the "Design Point."Performance checks should be made only when thesystem has been stabilized and reproducible valuesare attainable.4.1.2 Commercial operating conditions are recog-nized as involving uncontrollable variations in airand gas tightness of the condenser and its relatedsystem under vacuum. These variations, while negli-gible under some conditions, render the exact predic-tion of condenser performance impractical where theterminal temperature difference is less than 5F. Inaddition, terminal temperature differences of lessthan 5F are not considered sufficient to give deter-minative and predictable heat transfer performanceand are not recommended.4.1.3 Condenser tube water velocities under 3 feet persecond do not build up resistance sufficient to insurea uniform quantity of water through all the tubes;therefore, condenser performance under such condi-tions cannot be exactly predicted and such predic-tions are not recommended.4.1.4 As a general rule and within the degree of accu-racy expected in steam condensers, the effect of seaor brackish water as opposed to fresh water is com-paratively insignificant with respect to performance.If environmental laws require strict limitation on thewater temperature discharged from condensers tonatural sea water or brackish water sources, it maybe necessary to allow for the effect of such waters onthe circulating water temperature rise through con-densers inborderline cases. In instances where thisis necessary or where it is otherwise considered nec-essary, the following allowance for corrected specificheat and specific gravity of such circulating watermay be made. The Purchaser shall furnish specificweight flow or specific gravity and specific heat.w - QG - 500 X SG X Cp x TR

QVw = AT X 3600 X 62.4 x SG X Cp x TR

4.1.5 Due to its effect on condenser performance, thelocation of heaters and/or extraction piping should besubject to the condenser Manufacturer's approvalafter the turbine flow distribution diagram has beenmade available.

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4.1.6 Performance information as generated from thesestandards is based on venting equipment having a capac-ity at one inch mercury absolute pressure of not lessthan that listed in Section 6, and the actual air and non-condensibles being removed from the system notexceeding 50% of those values.4.1.7 It should be recognized that at reduced duties.a terminal temperature difference less than 5F willunpredictably affect condenser performance.4.1.8 HEI has established a condenser rating program.for further information please visit the HEI website.4.2 Heat Transfer Rates4.2.1 The design of a steam surface condenser mustconsider the effects of non condensible gases which arepresent in the condenser, pressure drop of the steamas it flows around and through the tube bundle, and tubeinundation as condensate falls through the bundle.Due to these effects, the heat transfer coefficient of atypical, commercial operating condenser is less thanthat attainable in laboratory tests.The heat transfer rates published by the HEI areOVERALL TUBE BUNDLE "u" VALUES to beobtained by the condenser under actual operating con-ditions and not single tube "U" values. Because thesevalues take into account parameters other than thebasic heat transfer across the wall of the tube, they arenot meant to be used by designers as specific individ-ual tube "U" values.The Heat Exchange Institute has conducted testsfor the purpose of arriving at heat transfer coefficientsfor surface condensers. The following is the HeatExchange Institute's method for calculating condenserheat transfer coefficients. Other methods of calculat-ing heat transfer coefficients are available.This method includes an allotment for the steamsideeffects described above. It is the responsibility of thecondenser designer to develop tube bundle and shellconfigurations which result in the heat transfer coef-ficients calculated by this Standard.The general heat transfer equations are:Q =U X As X LMTDQ = (H.team - HO(}nllenR"te)WS +Auxiliary heat loadU '- U1 X Fw X FM X Fe

U1 - Figure 1or Table 1Fw - Figure 2 or Table 2FM - Table 3Fe - Cleanliness FactorLMTD = __ T_R_

Ln (~~)TR = T2 - TllTD =Ts - TlTTD = T s - T2

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4.2.2 Table 1 and Figure 1 are based on clean 18BWG Admiralty metal tubes with 70F inlet circu-lating water temperature.4.2.3 For inlet circulating water temperatures otherthan 70F, the basic heat transfer coefficients shouldbe multiplied by the corresponding design correctionfactors shown in Figure 2 or Table 2.4.2.4 For any tube gauge or material other than 18BWG Admiralty, basic heat transfer coefficientsshould be multiplied by the appropriate correctionfactors from Table 3.

4.2.5 In actual operation, both the circulating waterand condensing steam will produce heat transfer resis-tance films on the tube surfaces which will have char-acter iat.ics related to the type uf fluid. A designcleanliness factor should be selected by the Purchaserthat suitably reflects the probable operating conditionthe tubes will experience in service. Non-copper bear-ing tube materials are more susceptible to bio-foulingthan tubes with high copper content.

U1UNCORRECTED HEATTRANSFER COEFFICIENTSTUBE DIAMETER TUBE VELOCITY

3.0 3.5 4.0 4.5 5.0 5.5 6. 0 6.5 7.00.625 & 0.75 462.5 499.5 534.0 566.4 597.0 626.2 654.0 680.7 706.40.875 & 1.00 455.0 492.0 526.0 557.9 588.1 616.8 644.2 670.5 695.81.125 & 1.25 448.6 484.5 518.0 549.4 579.1 607.4 634.4 660.3 685.21.375 & 1.50 441.7 477.1 510.0 540.9 570.2 598.0 624.6 650.1 674.71.625 & 1.75 434.7 469.6 502.0 532.5 561.3 588.6 614.8 639.9 664.11.875 & 2.00 427.8 462.1 494.0 524.0 552.3 579.8 605.0 629.7 653.5

TUBE DIAMETER TUBE VELOCITY7.5 8.0 8.5 9.0 9.5 10.0 10.5 11.0 11.5 12.0

0.625 & 0.75 731.2 755.2 775.5 795.3 814.1 831.9 848.9 865.2 880.7 895.60.875 & 1.00 720.3 743.9 763.9 783.2 801.6 819.0 835.6 851.5 866.6 881.11.125 & 1.25 709.3 732.6 752.0 770.7 788.4 805.3 821.4 836.7 851.3 865.31.375 & 1.50 698.3 721.2 740.4 758.7 776.1 792.6 808.3 823.2 837.5 851.21.625 & 1.75 687.4 709.9 727.8 745.7 762.7 778.8 794.1 808.8 822.7 836.01.875 & 2.00 676.4 698.6 716.8 734.4 751.0 766.8 781.8 796.2 B09.8 822.9

Table 1

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UIUNCORRECTED HEAT TRANSFER COEFFICIENTS

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FwINLET WATER TEMPERATURE CORRECTON FACTORInlet Water Inlet Water Inlet WaterO F F w of F w of F w

30 0.650 60 0.923 90 1.07531 0.659 61 0.932 91 1.07832 0.669 62 0.941 92 1.08033 0.678 63 0.950 93 1.08334 0.687 64 0.959 94 1.08535 0.696 65 0.968 95 1.08836 0.706 66 0.975 96 1.09037 0.715 67 0.982 97 1.09238 0.724 68 0.989 98 1.09539 0.733 69 0.994 99 L09740 0.743 70 1.000 100 1.10041 0.752 71 1.005 101 1.10342 0.761 72 1.010 102 1.10543 0.770 73 1.015 103 1.10844 0.780 74 1.020 104 1.11045 0.789 75 1.025 105 1.11346 0.798 76 1.029 106 1.11547 0.807 77 1.033 107 1.11748 0.816 78 1.037 108 1.11949 0.825 79 1.041 109 1.12150 0.834 80 1.045 110 1.12351 0.843 81 1.048 111 1.12552 0.852 82 1.051 112 1.12753 0.861 83 1.054 113 1.12954 0.870 84 1.057 114 1.13155 0.879 85 1.060 115 1.13356 0.888 86 1.063 116 1.13557 0.897 87 1.066 117 1.13758 0.905 88 1.069 118 1.13959 0.914 89 1.072 119 1.141

120 1.143Table 2

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FwINLET WATER TEMPERATURE CORRECTION FACTOR

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-

- \ -I- \ -\I- ' " -I- ~ -, -f- \ .. :r' \I- \~ -I- \ .;f- - , --. _----'I:- -.I .I .I .I ,I ,I .I .1 .1 ,I .t ,I0 ll:) 0 '" g '" ' ~ ~ Q I r . > 0 u :o 0 It}t"I . . . . . . . . Q a. G O e- "': < : C I '" ll:), . . . ; , . . . ; , . . . ; , . . . ; , . . . ; 0 0 0 0 0 < :> 0 0 0~

i lFigure 2

10I :

0" "' " " "

'". . . . .. . . . .0-;. . . . .

~':>,0. . . .0,0. . . . . .

It:>m

0m

It:>C()

< :>C()

." b-0t--

It:>

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FMTUBE MATERIAL AND GAUGE CORRECTION FACTORSTube Wall Gauge (BWG) &Wall Thickness tw(in)

Tube Material k 25 24 23 22 20 18 16 14 120.020 0.022 0.025 0.028 0.035 0.049 0.065 0.083 0.109eu Fe 194 150 1.042 1.041 1.039 1.038 1.034 1.028 1.020 1.010 0.997Arsenical Cu 112 1.038 1.037 1.035 1.033 1.029 1.020 1.010 0.997 0.979Admiralty 64 1.029 1.027 1.024 1.021 1.013 0.998 0.981 0.961 0.932Al Brass 58 1.027 1.025 1.021 1.018 1.010 0.993 0.974 0.952 0.921AI Bronze 46 1.021 1.018 1.014 1.009 0.999 0.979 0.956 0.930 0.892Carbon Steel 27.5 1.002 0.998 0.990 0.983 0.967 0.936 0.901 0.863 0.810Cu Ni 90-10 26 1.000 0.995 0.987 0.980 0.963 0.930 0.893 0.854 0.800co Ni 70-30 17 0.974 0.967 0.957 0.946 0.922 0.876 0.828 0.777 0.710SS (UNS S43035) 14.0 0.959 0.951 0.938 0.926 0.898 0.846 0.792 0.736 0.664Titanium Grades 1 & 2 12.7 0.951 0.942 0.928 0.915 0.885 0.830 0.772 0.714 0.640SS (UNS 844660) 10.5 0.932 0.922 0.906 0.891 0.857 0.795 0.732 0.669 0.59188 (UNS 844735) 10.1 0.928 0.917 0.901 0.886 0.851 0.787 0.723 0.659 0.581S8 TP304 8.6 0.910 0.897 0.879 0.862 0.823 0.754 0.685 0.619 0.539SS TP 316 / 317 8.2 0.904 0.891 0.872 0.854 0.815 0.744 0.674 0.607 0.527SS (UNS N08367) 6.8 0.879 0.864 0.843 0.823 0.779 0.702 0.628 0.558 0.477

Table 3

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4.2.6 SampleThermal CalculationThe following is a sample thermal calculation usingthese methods. Based on the sample data providedbelow, the required surface area of a condenser willbe calculated.

Design Information:Condenser Pressure, PsCondenser Temperature, TsCondenser Heat Duty, QTurbine Exhaust Steam Flow Rate, WsCirculating Water Flow Rate, WGCirculating Water Inlet Temperature, TlTube Water Velocity, VwCleanliness Factor, FeTubeO.D., DTube LD., DrTube MaterialCirculating Water TypeCirculating Water Density, ACirculating Water Specific Heat, Cp

1.177" Hg(a)84.01 of1032.8 MM BTUlhr1,064,000 lb/hr253,900 GPM60.0 O F9.0 fils0.801.00 inch0.944 inch (22 BWG 'lUbes)A249-316 (Stainless Steel 316)Fresh Water62.4lb/ft31.00 BTU lIb O F

Determine Circulating Water Outlet Temperature:T2= Q +TJ= 1032.8106BTU/hr

Wa .P' Cp (253,900' Gal). (60' min).( 1 f t 3 ) .(62.4 .lb) .h .BTU)min 1 . hr 7.48 . Gall {t3 \ lb . O F

Determine the LogMean Temperature Difference:(68.1 F - 60.0 F)-~c-:-=----:-::-:=---=-=--::-::-::=:- '" 19.7FLn (84.010 F - 60.0F)(84.010 F - 68.1F)

Calculate the Overall Heat Transfer Coefficient:From Section 4.2;U 1 = 783.2 BTU/ft2 OF hr (Table 1, Page 7)Fw = 0.923 (Table 2, Page 9)FM = 0.854 (Table 3, Page 11)

783.2 .BTU BTUU = U J Fw . FM . Fc = 2 . 0.923 0.854 . 0.80 = 493.9 . ----ft . "F> hr f t 2 . O F . hrCalculate the surface area of the condenser:As=-~Q--ULMTD

1032.8 . 106 . BTU I hr = 106,148 . ft 2493.9 BTU 19.7Fft2 "F> h r

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4.3 Oxygen Content of Condensate4.8.1 Under practical operating conditions, thecondenser can be expected to produce condensate withan oxygen content not exceeding 42 parts per billion.Wi th certain conditions of stable operation and suitableconstruction, as the application may require, an oxy-gen content not exceeding 14 parts per billionor as low as 7 parts per billion may be obtained asfollows:4.3.1.1 Condenser pressures should not be lower thanthe values shown on the curves in Figure 3, CurveA for 7 parts per billion and Curve B for 14 parts perbillion.4.3.1.2 The ratio of the actual non-condensible loadremoved from the system to the design capacity of theventing equipment should be no greater than the val-ues in Table 4.4.3.1.3 There should be zero air leakage directly intothe condensate below the condensate level in thehotwell. The arrangement and location of all entrancepoints into the condenser for water vapor or othergases should be subject to the approval of theManufacturer.Examples ofthe potential sources ofair are as follows:

4.3.1.3.1 Leakage into the vacuum side of the systemthrough leaks in welds, packing glands, gauge glasses,salinity cells, instrumentation leads, etc.4.3.1.3.2 Low pressure heater condensate drains andvents, particularly when operating below atmospher-ic pressure.4.3.1.3.3 Make up, which is usually saturated withoxygen.4.3.1.3.4 Condensate surge tank, when utilized inclosed cycles.4.3.1.4 Total water introduced into the condensershell at a temperature lower than the inlet steam tem-perature should not be more than 5% of the steambeing condensed for 14ppb or more than 3% for 7ppb.4.3.2 Where condensate from processing systemsand/or cogeneration systems is introduced to the con-denser, it shall be assured that the oxygen content ofthe returned condensate is no greater than that spec-ified for hotwell condensate. If this is not the case, spe-cial internal deaerating provisions may be requiredand/or returns shall be deaerated externally prior tobeing returned to the condenser. The specific oxygenlevel in returning condensate and the quantity of con-densate being returned must be specified for theManufacturer's considerations.

VENTING CAPACITY AND OXYGEN CONTENTVenting Equipment Design Actual Load/ Expected Oxygen Content InCapacities (SCFM)(a) Design Capacity Ratio(b) Condensate ppb (ceIL)

0.50 42 (0.03)0-20 0.35 14 (0.01)0.25 7 (0.005)0.50 42 (0.03)20-40 0.24 14 (0.01)0.15 7 (0.005)

42 (0.03)Greater than 40 See note 14 (0.01)(c) 7 (0.005)Notes:a. The design capacity of the venting equipment should be in accordance with Section 6.b. These ratios are for venting equipment rated at 1 in. HgA. The venting equipment in operation should alsohave a minimum capacity of 40% of the free dry air (stated in Section 6) at 0.5 in. HgA suction pressure anda temperature of 51.3F when operation is lower than 1 in. HgA .c. For venting equipment with design capacity exceeding 40 SCFM, the non-condensibles removed should notexceed the following definitive values:20 SCFM for 42 ppb10 SCFM for 14 ppb6 SCFM for 7 ppb

Table 4

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ABSOLUTE PRESSURE LIMIT CURVES FOR OXYGEN CONTENT

2.4 r - - - - - ~ ~ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -2.2 1 ppb (CURVE AI

ANO14 ppb (CURVE S)

2.3

2.1

2.0

0 . 9

0.8

0. 7

0.6

0.5

0.4

0.3 .

30 40 50 60 70 80 9 0 1 0 0

Ij

Figure 314

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4.3.3 In the case of nuclear power cycles in which addi-tional non-condensible gases such as oxygen andhydrogen are present in the condenser, the expectedoxygen content of the condensate will be appreciablyhigher than those power cycles where air is the onlynon-condensible present in the condenser. The HeatExchange Institute has conducted a field survey of anumber of condensers for Boiling Water Reactor powerplants and has reached the conclusion that conden-sate oxygen levels of 10-50 ppb over a fairly widerange of operation are to be expected with this typeof plant.4.3.4 It is recognized that a subcooled liquid hasgreater potential for dissolving gases that might bepresent in the hotwell reheat area. This factor increas-es the importance of eliminating sources of noncon-densible gases in the hotwell area (Par. 4.3.1.3). Therestrictions of paragraph 4.3.1.4 are not applicable tocondensate cascaded from the lower pressure shell tohigher pressure shell since this condensate has beeneffectively deaerated in its respective shell prior tobeing cascaded.4.4 Performance Curves4.4.1 Having established the overall heat transfercoefficient for a given condenser, it is then possible toplot performance curves showing absolute pressuresfor varying condenser duties and inlet circulatingwater temperatures. A sample performance curve isshown (Figure 4).4.4.2 It is recognized that at lower heat duties thecurves must be modified due to the limitations of theventing equipment. This modification begins at PointJ and proceeds as a straight line to Point G. Point Jis determined from Figure 5, (Curve A) and is com-monly referred to as the cut-off point. Point G is theminimum absolute pressure zero duty and is provid-ed by Figure 5, (Curve B).4.4.3 It should be recognized that a terminal tem-perature difference less than 5F will unpredictablyaffect condenser performance.4. 5 Hydraulic Loss - Circulating WaterPressure LossThe circulating water pressure loss through thecondenser is calculated using the following equations.RTT = LT CRT X R2 X R1) + ~ RE

RTT = Total LossLT * = Tube Length"Multiply by number of tube passes.RT =Tube Loss, Figure 6Or use:

R~x RT = 0.00642 VW175D1I.25

S AM PLE PE RF OR MA NC E C UR VE

o 20 40 60 80 1 0 0 120Q(PERCENT)Figure 4

(Note: Correct Vw for Average Water Temperature)Rl = Temperature Correction Factor,Figure 7&..l = Tube O.D . & Gauge CorrectionFactor, Table 5RE** = Water Box and Tube End Losses

**See Figures 8, 9, 10, and 11 for appropriatenumber of water passes.Figures 8 and 9 cover the head losses to be expect-ed in waterboxes and tube entrances and exits of sin-gle pass and two pass condensers, respectively. Forsingle pass condenser, the inlet and outlet waterboxlosses should be determined from the curves in Figure8 using the actual nozzle water velocity in each case.The tube inlet and outlet losses are combined in onecurve in Figure 8 and the value for these losses shouldbe taken directly from the curve using the actualwater velocity in the tubes.For two pass condensers, the above procedureshould be followed using the curves of Figure 9. It

should be noted that the tube inlet and outlet loss isdouble that of Figure 8 and the value obtained there-from should only be used once in the head loss com-putations. Similar procedures should be used for threeand four pass condensers.The values given by Figure 6 are based on a clean18 BWG tube with an average cooling water inlettemperature of 70F with a 15F temperature rise.Factors should be adjusted using this as a base.

15

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ABSOLUTE PRESSURE LIMIT CURVES

P s

0.70.6

0.5

0.40.3

30 40 50 70 10000 90

Figure 516

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~GAUGE CORRECTION FACTOR FOR FRICTION LOSSTube 12BWG 14BWG 16BWG 18BWG 20BWG 22BWG 23BWG 24BWG 25BWGo.n.re.0.625 1.38 1.21 1.10 1.00 0.94 0.91 0.90 0.89 0.88~ 0.750 1.28 1.16 1.06 1.00 0.95 0.93 0.92 0.90 0.900.875 1.25 1.13 1.06 1.00 0.96 0.94 0.93 0.92 0.911.000 1.19 1.11 1.05 1.00 0.96 0.94 0.94 0.93 0.931.125 1.16 1.09 1.04 1.00 0.97 0.95 0.94 0.94 0.931.250 1.14 1.08 1.04 1.00 0.97 0.96 0.95 0.94 0.941.375 1.13 1.07 1.03 1.00 0.97 0.96 0.95 0.94 0.951.500 1.12 1.06 1.03 1.00 0.97 0.96 0.96 0.95 0.951.625 1.10 1.05 1.02 1.00 0.97 0.96 0.96 0.95 0.951.750 1.10 1.05 1.02 1.00 0.98 0.97 0.96 0.96 0.961.875 1.09 1.05 1.02 1.00 0.98 0.97 0.97 0.96 0.962.000 LOS 1.04 1.02 1.00 0.98 0.97 0.97 0.96 0.96

Table 5

4.6 Condensate Temperature Depression inMulti-PressureCondensers -With multi-pressurecondensers, reheat of condensate from lower pressureshells is achieved by the cascading oflower pressureshell condensate into the higher pressure shell. Thiscascading is accomplished either by gravity flow orpumping. A well designed reheat system should, under

design conditions of operation, be capable of achiev-ing a reheat rate of SO%or better of the temperaturedifference between the respective pressure zones. Thefollowing formula provides a simple method of estab-lishing expected high pressure shell outlet condensatetemperature.

DUAL PRESSURE CONDENSERST - WLP {TsLP + [.S (TsHP - TsLP)]} + (WHP X TsHP)CHP - WLP +WHP

TRIPLE PRESSURE CONDENSERST - WLP ITsLP + (.8 [TSHP - TSLP])} + WIP {TSIF + (.8 [TSHP - TsIP])) + (WHP X TsHP)eHP - WLP + WIP + WHP

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.. ,; .

.'-..'. ';. . . ~~.: .. ~.~~: .. '.,.-',~ .. . , . . . ',,, .. . ~

RrFRICTION LOSS FOR WATER FLOWINGIN HIBW(~TUBES

_ ..... _._....... t-~ _._. _ -i ~ I ..

RT.10.0 9.08.07.0 6.0 5.04

.0 3

, - - ; -. . ~. , ': .. ;'1"" . t I"';~ i ."-t...... , .. , I " : ' . .

.01--t----.......-t-----+--t-..,.-+~_+_+w..----'1 - , . . . - .f-- - -

, .. ", - ~I ..

. .... ,.. " ...,.. . fl .......1 2 3 4 5 6 7 8 9 10 20

VwFigure 6

18

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-.~. .~R JTEMPERATURE CORRECTION FOR FIUCTION

LOSS IN TUBES

1.14

1.12

1.10

1.08

1.06

1.04

1.02

1.00

.98

.96

.94

.92

.90

. 8 1 ' \

~.'

: i O 1 0 \ 10 io o 1\(1 L'l)TI tT,

.J

Fig-lin' 71' 1

~,~,'

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4.0

3.8

3.6

3.4

3.2

3.0

2.8

2.6

2.4

2.2R E

2.0

1.8

1.6

1.4

1.2

1.0

0.8

0.6

0.4

0.2

0.0

" .. ,',.,' .. ;.,

HEWAT"~I{BOX AND TUBE END LO:-;SESSINGLE PASS ('ONDENSEHS

t H E : : ! ; ! ; jH:Hi i!!!jn;l [Ijlif! lllii:!;, ;:Ii:::'\ :il:f;;::!;!;:::::: :::;!;::: :::::::;J:l::;!;; :l. i i U n n ~! : 1 ~ ~ ! 1 1 ~i l l i f ! ! i l i 1 ! 1 ! i i ; ~ ; ~ ! 1 1 ! ! !l l l m f !~ m ~! 1 1 ! 1 :! : . ~ j f u f ~ l ; ~ : ~ l . ! ~ : f : l : ! ~ i ;: : ; ) I ! : : : : : : : : : : , : : : : : : : : : : : : ; : : . : . '. ." ,... "'." r; .. ~ ,. r, ' , - I-. , , ,..... ,.:::::::::~::::::::':J!::~~~::;;::!:. ::::::::: ::::;:.:: ~::;::::;:::::~::.:;::::::: ;.:::;:': :::::::;:::::;::: :~:::::::;:::>:::~: : : : : : : ~ :; ; : ; ; : ; ; i i i ; i j ~ i i :; ii it : fh M i ; : ; ; ;; ;: ; :~ ; i ; i i ; i ii i : i ; : U ; L : r ; ; ; i ; ; i : : i ; i : jifjrt~ ;;;;;;;}jjj; . , : . : . : . . ; " . : . ; . . : : ; i , i i i ' i i i ' ! , ; . . " i i : . " , g , ' "!,:,':;,,';:;I . i i i I i ! i ' ~ l , i/ ' 1 1 1 , " " , j : ' l ' I . ' l l i ~ I ! I m t @

. . . . . . . . . . .. . 1 . . . . . ~ ..... j..,j"'".................- 1 +. ~ . - r, . I., . .....~.. ....... ,..

o 2 G IIin 12 155

Figure 820

-..-liIiiiliiiii --.------- .....- .....---- ...........,....-- ................ ~ ~- ,_ ~ .. ,. ,- -' r~ ~ ': . ..~ , ~ - . . . . . , .~T ..-,. ..''I';~'fI_..! l i ' ' r ' ' ' . I ' ! 1 8 ' ' ' e ~ , . I I I I I I . I I I I I . . . U f f _ ..__. ~ " -"\!iJ q.

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6.0

5.6

5.2

4, R

4, 4

4. 0R E

3.6

3.2

2.8

2.42,0

1.6

1.2

0, 8

0.4-

0,0

REWATER BOX AND TUBE END LOSSESTWO PASS CONDENSERS

~ : : ! ::: ! : t : : i : : : :: : : : : : ; : t !~:: i :H: 4 _, ........ ; .t: .~ : , ; _ ; ; g~ n 1 i ~ ~ ; ~~ ; ; ; ~ g : : : : : : : : : : : : : : ; ~ : : :~!::::::: : ! : : : : : : ::::::~~!:~!~:~:' : : : : : : : : : : : : : : :: : : : : : : :; : : : : : : : H ~ H l~H j l l n i H 1 H H H ~ H \ B m H H H H

.; : ~: : : :: ::::::::: ::::::::: ::::: ~: :: t I 0-', ~.... """ f

..,. . .~o 2 5 (j 7 9 10 11 14 15:. ! 13

Figur(' H

21

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p

R~:WATER BOX AND TUBE END LOSSESTHREE PASS CONDENSERS

1 ! ' : : i : ~ : . : .: . i . . .' ! " ! ; : ; ! . ' ! " l ': . : . ' . . , m .: . : .; .: ~:;: ; , : r r;,! I : , : : . 1 . m . , 1 , : i ' ! T : ; . m . ~. U . : . : . ~ ; : ' : , : ! T ':, :1 : : : : ; m . I , : ,' ' ! ' T r : ' ! , : : ! ' ! ' ! , ~ T T; ~ ! " I ' ! :!m ; ; " I" ! ', : r ! ' T ! ~ ' ! ' ! ' : ; 1m : , ' T T l' ! T ; m ! p " ! ' l ' : : T ' ! '!: : , m : : " ! ' I ' : : m ~ \ l ~ q ' ! ' ! ' , ~ r : " ;' 0 '1 " : : : ! " I" I : : ; " " ; ' I " I ' i : , I T ' l l : ' 1 "\ : I ' ! ' i : 1 " ; ! ' ! " ! ' : ; " ' d ! ' " ; ' ! " ! ' : 1mT n " ' ! ; T 'I " ;! " " ; :~l"I"' Ii ; T !' p T r. : : : ~ : ' ! " !' ; : ~ :~ : " ': : ! r I " ! : ' !' I" " " . 1( 1~ . H ~ ~ H ~ : : n H ~ H H H ~ H ~ d ~ ~ ; H ~H ~ H ~ ; ~~ ~ H ~ ~ ; \ ~H ) i j n ~ H i H H H ~ i ~ ~ H HH _ .8.07.67.2

6.8

6.4

6.0

5.65.2

RE 4.84.4

4.0

3.6

3.2

2.8

2.4

2.0

1.6

1.2

0.8

0.4

0,00

~ l i ~ l t ~ l jm ! 1 1 ! ! 1 1 1 : : : : m " ~ : l j ' i ) ~ i n : ~: j ' ~ l l l ~l l l l : : : i~ ~ j ~ T l ;m l l ~ j : ; ' ~ l : t j ) ~~ ~ ~ i [ m 1 l 1 m ,I ~ ; ; i ~ j ~ ~ : ~:', ':; ! 1 1 1 m l 1 1 1 1 1 T ! : i ~ ~ : ' U ~ ~ i ~ ; l t l ll i i i : ! ~ i~ \ : i ; : j t i : ! ' ) : ~ " l l ~ l l l : ; ~ :l : H ~ l : ; : T : ~ :r l ~ l m i m W l l l \ 1 1 : 1 : f ~ ; ~ ~ j 1 [ .i l H l :

~ W i t m ! 1 1 1 1 1 W; ! i l i : i l m ! l ~ ] l l l ! l W ~ i i l m ~ m t l 1 1 ~ ~ d i I W ~ I ~ ; ! m~ lilim l ! lm m m m m w m m m m~ j ! ' ! !. : : \ . j ! I ! . ! : ! ! . ! ! ! f i j i i ! ! I I ! i..! ! ' : : ! ' f ~ ' ! : : ~ ~ ~ ! ! . l ' [ ' :~ l j~~~~~!! . ~ ! . : ,.... '" '''''' )~ j:'I_ .. I I JV~~;~: ;:: 1 4 K ~ 't . . . . . .' m m ) : i ; : : , ' ! j ' , 1 : : j : . : i ' , 'm : ' : j i ' . : . d ~ , ~ 1 ; ~~~ i m ~ m ; : : ~ ~ H~~~llm : m : : m ' :;:::::::::::::;::::::::::::::::::,::::...7'~l~:!l(~.::::.~11fR?~1~;; ::::::::!::::: :::;:::::~ i i i j " ' : i : m : i : . I @ 1 : ) i i . . : : : . ' , i i i l 1 1 m ! i l l ~ ) i ~ ~; i 1 1 ; l ; ;~ i ; : t 1~ f I Tl m 1 ; 11 m ; ! : : i ~ ' i : : j i '. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . H t d / , i < v A f J~H: :: :; gi : :.e"l~ ::::::::: ;:::::::: ::;:::::: ::::::::;::;::::::::::::;;::::::::::::::::::Ii!:~'.~":::I0::::~' " " .l i i " I i i i ' l l i : : i i l i i : : : : ! i i ! ! ; [ ~ ~ ~ ~ ~j ;~~~'j~~~ ' i i i . !1 1 ' 1 1 1 ' / i i l t l l i i ! i l i l l J l l iI I ! 1 1 1 1 f l J ~ ~ ~ ~ m m ; 1 1 m ~ ! I I ~t W J ! ! ; m m il t l i l l l l W l i W I ! ! m W l i J l l l l i i l I I I i~ i

9 ] 08 ns 12 14

Figure 1022

a .s

:Il;

:14

3 . : 2

30

2.8

2.6

2. 4 H I

2,2

2.0

1.8

1. 6

1 . 4

12

1.0

0.8

0.6

0.4

0.2

0.0] 5

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REWATER BOX AND TUBE END LOSSESFOUR PASS CONDENSERS

l i H 1... ' . !!i!!! HI; ! H ; ~ ; ~ ;. . , . . . . t'

10.5

10.0

9.5

9.0

8.fl

8.0

7.5

7.0

6.5

6.0R ]l

5.5

5. 0

4.5

4.0

~.5

3.0

2.5

z .o1.:)

l.ll

0.;;

0(1o

!ii'. t ~:;.. 4.0. . . . . ,

: ........ 3.8.. .. .....: : . _ :.....: . . : : .,.. 3.6: :

::::: ::::::::::::,;,:::::::::::;:::::::::::::::::;:::::::::::::::j:l::; .~ ii : : T i !: :: :U : / : : Y : ; : ; T H ! ! : : Y T :~!H~l/: ::::: .. . : : : : : : : J

"".,,'. . .. ... .,1 :3 I'

. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . : : : : : : : : : : : : : : : : : ; : : : : : : : : : : : : : : : : : 1 : : : : : : : < : : : : : : : : :T H ! i Y Y H \ Y 1 T T : \ : /:!< .. : : : : : .: . '. : .: . :. :.:.,:.'.::.:.'::.:.':...:.:.:.':.:.:.,:,:,.:~,::.".::.':.;.'.:'.::.:.:::.:..:.).:.':.:.:...':.:.:.:,-::::~::: ::::::: :::~::::::;:::::: ::;:::;:: ::::::::. :~

-u4$"2$ , : .i.! .:Z: [ 4S! I. ! i s .dUPUiS; is .. : JijSJWfliLL:; '*"'.0;;-"4.;0:':;::0.;.'4: 1" ,, .til!;;.; Al uP." .;

3.4

3.2

3.0

2.8

2.6

2,4RE

2.2

2.0

1.8

1. 6

1.4

1 .2

1.0

0.8

0.6

0.4

0.2

0.010 II I~ If >i !I:l 4

Figur(' 11

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,-:,', ,,:, -' '.' ' ".

MATERIALS FOR CONDENSER TUBES

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TUBE CHARACTERISTICSODof Inside Surface Length in Water-GPMTubing BWG Thickness Diameter External, Feet for at One Foot(Inches) (Inches) (Inches) Sq. Ft. Per One Sq. Ft. Per SecLinear Foot Surface Velocity

12 0,109 0.407 0,1636 6,112 0.40613 0,095 0,435 0,1636 6,112 0.46314 0,083 0.459 0,1636 6.112 0.51615 0.072 0.481 0.1636 6.112 0.56616 0.065 0.495 0.1636 6.112 0,60017 0,058 0,509 0.1636 6,112 0.634o / s 18 0.049 0.527 0,1636 6.112 0.68019 0,042 0.541 0,1636 6,112 0.71620 0,035 0.555 0,1636 6,112 0,75421 0.032 0.561 0.1636 6.112 0.77022 0.028 0.569 0.1636 6.112 0.79323 0.025 0.575 0.1636 6.112 0.80924 0.022 0.581 0.1636 6.112 0.82625 0.020 0.585 0.1636 6.112 0.83812 0.109 0.532 0.1963 5.094 0.69313 0.095 0.560 0.1963 5.094 0.76814 0.083 0.584 0.1963 5.094 0.83515 0.072 0,606 0,1963 5,094 0.89916 0.065 0.620 0.1963 5,094 0.94117 0.058 0.634 0,1963 5.094 0.984% 18 0.049 0.652 0.1963 5.094 1.04119 0.042 0.666 0.1963 5.094 1.08620 0.035 0.680 0.1963 5.094 1.13221 0.032 0,686 0.1963 5.094 1.15222 0,028 0.694 0.1963 5.094 1.17923 0,025 0.700 0.1963 5.094 1.20024 0.022 0.706 0.1963 5.094 1.22025 0.020 0.710 0.1963 5.094 1.23412 0.109 0.657 0.2291 4.367 1.057...13 0.095 0,685 0.2291 4,367 1.149..14 0,083 0.709 0.2291 4.367 1.23115 0,072 0.731 0,2291 4,367 1.30816 0.065 0.745 0,2291 4.367 1.35917 0.058 0.759 0.2291 4.367 1.410% 18 0.049 0.777 0.2291 4,367 1.47819 0.042 0,791 0.2291 4.367 l.53220 0.035 0.805 0.2291 4.367 1.58621 0,032 0,811 0.2291 4,367 1.6102 2 0.028 0.819 0,2291 4,367 1.64223 0.025 0.825 0,2291 4.367 1.66624 0.022 0.831 0.2291 4.367 1.69025 0,020 0,Hg5 0.2291 4.367 1.70712 0,109 0,782 0.2618 :3.817 1.49713 0,095 O,HIO 0,2618 3,817 1.60614 0,0;;18 0.H:14 O.:'1618 3.817 1.70315 0,072 U,KGB 0,2(H8 3,1117 179416 0,065 0.870 0.2618 :3.817 1.85:317 0.05H O.RM O.2(il8 3,817 1.91:3

.1 18 O.(W) 0,902 (),2(i18 :1.SI7 1.~9219 O.lH2 O.HIG O.2G18 :3,817 2,Of)420 0.0;15 0,9;10 (),2(i18 ;1."1. 2.11721 0,0;12 O.!,;W o.zrns ;L~17 2,145 .~22 (J,(l28 O.!',4 O.:biI8 :L~17 2,IH21--- 2:1 0.02'-) o.nso O,:Uilfl :1.S17 2.20\)-f--. ()2(';18 :U{1' 22374 0 .022 (UI,,!;25 O.O2l l O\HiO (l.2mB :1.817 :L25().-

Table 7

25

' - - ' . . . . . . . _ _ . . _ _ ~ I ! I I I I J I I I - l i I ! I I I ' P . ' " - . . . . , . . " ' ". t . i,; i2 ! 4 4 J 2 . i l J .1;;;,12.1 !2P.PM

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TUBE CHARACTERISTICS--. ---

ODof Inside Surfuce Lcnth in Watt'l" - (;PI\ITubing BWG Thickness Diameter Exter-nal, Feet fnr nt Om' Font(Inches)

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TUBE CHARACTERISTICSon er Inside Surface Length in Water-GPMTubing BWG Thickness Diameter External, Feet for at One Foot(Inches) (Inches) (Inches) Sq. Ft. Per One Sq. Ft. Per SeeLinear Foot Surface Velocity

12 0.109 1.407 0.4254 2.351 4.84013 0.095 1.435 0.4254 2.351 5.03514 0.083 1.459 0.4254 2.'351 5.20515 0.072 1.481 0.4254 2.351 5.36316 0.065 1.495 0.4254 2.351 S46517 0.058 1.509 0.4254 2.351 5.5671% 18 0.049 1.527 0.4254 2.351 5.70119 0.042 1.541 0.4254 2.351 5.80620 0.035 1.555 0.4254 2.351 5.91221 0.032 1.561 0.4254 2.351 5.95822 0.028 1.569 0.4254 2.351 6.01923 0.025 1.575 0.4254 2.351 6.06524 0.022 1.581 04254 2.351 6.11125 0.020 1.585 0.4254 2.351 6.15012 0.109 1.532 0.4581 2.183 5.73813 0.095 1.560 0.4581 2.183 5.95014 0.083 1.584 0.4581 2.183 6.13515 0.072 1.606 0.4581 2.183 6.30616 0.065 1.620 0.4581 2.183 6.41717 0.058 1.634 0.4581 2.183 6.5281% 18 0.049 1.652 0.4581 2.183 6.67319 0.042 1.666 0.4581 2.183 6.78620 0.035 1.680 0.4581 2.183 6.90121 0.032 1.686 0.4581 2.183 6.95022 0.Q28 1.694 0.4581 2.183 7.01623 0.025 1.700 0.4581 2.183 7.06624 0.022 1.706 0.4581 2.183 7.11625 0.020 1.710 0.4581 2.183 7.15812 0.109 1.657 0.4909 2.037 6.71313 0.095 l.685 0.4909 2.037 6.94214 0.083 1.709 0.4909 2.037 7.14115 0.072 1.731 0.4909 2.037 7.32616 0.065 1.745 0.4909 2.037 7.44517 0.058 1.759 0.4909 2.037 7.5651% 18 0.049 1.777 0.4909 2.037 7.72119 0.042 1.791 0.4909 2.037 7.84320 0.035 1.805 04909 2.037 7.96621 0.032 1.811 0.4909 2.037 8.01922 0.028 1.819 0.4909 2.037 8.09023 0.025 1.825 0.4909 2.037 8.14324 0.022 1.831 0.4909 2.037 8.19725 0.020 Ul35 0.4909 2.037 8.24312 0.109 1.7H2 0.5236 1.910 7.76413 0.095 uno O.1i236 1.910 8.01014 0.083 Ula4 0.5236 1.910 8.22415 0.072 1.1'156 0.5236 1.910 8.42216 0.065 1.K70 0.5236 1.910 8.55017 0.058 UltH O.G2a6 1.910 8.6792 18 0.049 U)O:! () !)236 1.910 8.84519 0.042 1.!1Il; 0.52:36 1.910 8.97620 D.03S 1.!I:1O (Ui236 1.910 9.107- . _ .. _ 21 0.032 l.!1:m 0.5236 UllO 9.184_-,--22 0.028 l.!lll O.52:3fi uno 9.:!4023 0.025 1.950 0.1'".2:36 1.910 ~).29!{24 0.022 1.9{.(i O.f>2:36 uno ~1.;lfj4

'---- 25 0.020 i . n n n O.fiZ:36 uno 9.404Table 7 (Continued)

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4.7 Geothermal Applications4.7.1 Condensers which are intended for use with steamfrom geothermal sources require special considerationsin design due to substantial differences between geother-mal steam and the steam in conventional equipment.The most significant differences are listed be low ,4.7.1.1 Conventional units have gas fractions of'less than0.005% by weight while geothermal units have gas frac-tions which can be several orders ufmagnitude greater.4.7.1.2 Geothermal fluids contain elements and chem-ical compounds in gaseous, dissolved, and particulat-ed forms which can be aggressive in both chemical andmechanical actions in promoting corrosion and erosion.The same constituents may also create fouling films orscaling on both the outside and inside of tubing.Due to these complexities, the HEJ is not in a positionto establish design criteria for such equipment.However, the following sections will provide guidelinesand information helpful in the selection, rating, andconstruction of geothermal condensers.4.7.2 Thermal Design and Rating - The heat transfercoefficients which are established from paragraph 4.2are not considered valid for geothermal applicationsbecause of the high non condensible gas fractions. Usethe following guidelines to correct for the presence ofnoncondensibles.4.7.2.1 Cleanliness Factor Correction Method - Whenoperating experience is available, test data can determinean overall fouling equivalency or overall heat transfercoefficient. When such data are available, the Purchasershould specify the factor or overall rate for design. Thismethod is suggested only when the equipment andconditions are exact or near duplicate of an existingcondenser.4.7.2.2 Analytical Procedures - When gas fractions arehigh or test information is not available, the effect uponcondensation inthe presence of the gases must be treat-ed by more sophisticated heat and mass transfer anal-ysis. Methods have been developed by variousManufacturers which have been demonstrated to pro-vide reasonable solutions of the heat transfer phe-nomenon. Any of the analytical methods must besupplemented by a Purchaser specified factor to account

for tube OD and III fuuling. The analytical procedurshould account for gradients in condensing temperture caused by the variation in partial pressurethe condensing vapor.4.7.3 Venting Equipment4.7.3.1 Capacity of Gas Removal Equipment - 1'1capacity of venting equipment should be based upiactual gas content analysis of the source of tIgeothermal steam, plus an allowance for air leaka,into the system. Also, there is evidence that geothcmal wells wil l have an increasing gas content with ag'therefore, the Purchaser should specify a suitahidesign factor for this condition.4.7.3.2 Design Suction Pressure and TemperatureThe large amounts of none onden sibles in geotherm:condensers require special treatment of the non c o idensible-vapor mixture. Condensing and cooling the vented gases and vapor can be accomplished inte:nally or externally to the condenser. The suction pre.sure and temperature at the vent outlet should bbased on the system operating conditions and not 0the guidelines of Sections 6.2 and 6.3.4.7.4 Other Performance Related Characteristics4.7.4.1 Condensate Temperature - The high gas Ira.tion in geothermal steam will result in significansubcooling of the condensate below the apparent saluration temperature of the condenser. Generally, ;geothermal hotwell will not provide reheating of th -condensate. Condensate temperature depression 03F, or more, can be expected.4.7.4.2 Dissolved Gas in Condensate - The amounofnoncondensibles in the condensate is dependent OJthe amount and composition of the initial gas, the phof the condensate, the degree of subcooling, and th roperating pressure. In addition, both mechanicalentrainment and chemical combinations contribute tothe gas content and gas partitioning. Data is not avail-able in the condenser manufacturing industry to per-mit prediction of the dissolved gas content.4.7.5 Performance levels shall be mutually agreedupon between the Purchaser and Manufacturer.

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. ' 1" , ,,c j -~_;_ ' '! ' '. I II I . . .. .4_q4 '' ' 'q : ; :pss... " " . i . . . . . . . . . . . ' ! I " ! P ~ , , 4 . , " " '. . . . I I ! I . . , . " ' i ." t l ! l! . = I I ! ' ) I I I I !W " a w l ! ll l ll l '' ' , U I I I I ; P l l l li l 'J l ' : i . '' ' l' : ' A l I I li , ' I '! ! . ! . ; .2 . 1 1 ' . . . I .. t . . .. . .. . .. d l l l . _ _ ! 1 1 1 1 . . .. . .

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,.'.:. "',,',", ' ": : ' , ' , ". >

Noll':a. Low Tl-mpornt ure refers to flows with a maximum temperature of lOO"F over '1\ (saturation)b. 1 = first preference. 2 := second, 3 = thirdc. When ll.~inghi" location, consideration must il(' given to available space and to the effert of water leveldist urbances and water pick-upd. Any drain" requiring dcaeration should he located above the tube bundle centerline.e. Locate approxinwtcly in the lower' 1/3 of exhaust neck

5.4 Connection Design Guidelines5.4.1 Complete conditions (pressure, temperature,enthalpy and flow) must be provided at each connec-tion. In addition, service conditions shall be supplied(i.e .. continuous, intermittent, start-up, etc.),5.4.2 Limit the enthalpy of entering steam to no morethan 1225 Btu/lb. Acceptance of flows with enthalpyhigher than 1225 Btu/lb may be considered depend-ing upon specific conditions of service.5.4.3 Limit pressures to a maximum of 250 psia.Pressures should be lower, where possible, especially forliquid flows. Special considerations for higher pressuresshould be reviewed with individual Manufacturers.5.4.4 Ventilator valve (and other high energy shortduration sources) discharges should be to the atmo-sphere; however, if they are directed to the condenser,limitations as described above will apply.5.4.5 Where conditions exceed the above require-ments, external desuperheating must be provided bythe purchaser for both the higher flow connections andfor the lower flow connections that are in operationwhen exhaust steam flow is absent. Desuperheatingshall be accomplished in a manner that ensures thatthe condition of the fluid at the condenser wall has25 - 75QF of superheat.5.4.6 It is recommended that drains requiring deaer-ation have a pressure of at least 5 psia.5.4.7 Design ofcondenser connections and/or locationsshould be such that the steam release volumes fromthe additional steam loading will not result in veloc-ities in excess of 500 It/sec anywhere on the periph-ery of the tube bundle or on lagging. The latter willbe determined from fluid conditions and availablespace in the area of connection (i.e., space betweensupport plates, etc.).5.4.8 Thermal sleeves should be provided on connec-tions designed for flow conditions of 450F and higher,except for instrumentation connections.5.4.9 Under no circumstances should steam flashingdrains be admit.ted to the condenser unless circulationwater flow is established and non-condensible gasremoval equipment is in operation.5.4.10 Consideration should be given, in dividedwaterbox condensers, to the possibility that operationwith one bundle out of service could cause high tem-perature steam drains to impinge on the non-operat-ing bundle and cause severe thermal and mechanicalproblems. Provisions such as locating drains wherethis condition cannot occur are recommended.

. 1

5.4.11 Connections should not be located below tlwater level in the hot well and at, or near, suppoiplate lines. field weld lines, any flexible diaphragm(exhaust steam inlet expansion joints, s he ldiaphragm. heater diaphragm, etc.) or corners.Discharge should not be directed into separate curdenser compartments such as the areas below fals.bottoms in multi pressure units unless this is considered in the design.

5.4.12 Do not locate a series of connections. excep:gauge and control, in close proximity so that high flowconcentrations and/or interferences from discharge,from all of the connections will result. High energxdrain effluent lines must be kept away from liquioreturn lines to prevent moisture pick-up and associ-ated erosion.5.4.13 If insufficient volume is available within thecondenser for the introduction of steam dump flows,a separate external steam dump condenser should beconsidered.5.4.14 The use of external tanks is recommended forhigh temperature, high pressure drain flows prior tobeing admitted to the condenser. This would usuallyapply to units where a large number of small con-nections with higher energy levels exist. Minor steamdrains or vents may exceed specified conditions inparagraphs 5.4.2 and 5.4.3 provided flow from themain turbine exists and the locations are acceptableto the Manufacturer,5.4.15 Piping upstream of all flowing connectionsshall be properly trapped and drained to prevent dam-aging water slugs being introduced into connections.5.4.16 The external location shall be such that re-rout-ing of internal piping is not required, since internalpiping will interfere with normal steam distributionwithin the condenser.5.5 Turbine Bypass Guidelines5.5.1 General5.5.1.1 Complete evaluation of the design parametersfor main steam bypass lines is important for the safeoperation of the condenser. Operating requirementsand special customer requirements could affect thecondenser design. It is imperative that customerscooperate with the condenser Manufacturer to assureall conditions are examined prior to the final design.5.5.1.2 Operation ofturbine bypass should occur with100% c.irculating water flow. Other circulating wateroperating modes are possible. Careful design andplanning are essential, and customer specificationsmust clearly outline all expected operational modes.

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F

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5.5.1.3The total amount ofenergy released to the con-dt~nser can vary over a wide range. Condenser:Manufacturers do not guarantee performance for thisservice, but rather make accommodations for the safedispersion of the incoming fluid.5.5.1.4 Noise abatement measures such as the use ofa special noise attenuating valve or noise attenuatinginsulation should be considered by plant designers.Such valves may reduce noise levels to below plantoperating background levels. No noise guarantee canbe made by condenser Manufacturers during bypassoperations.5.5.2 Steam Conditioning5.5.2.1 Steam inlet design values are not to exceed1225 Btu/lb and 250 psia to ensure the discharge is avapor,and not a moisture laden mixture capable of cre-ating impingement problems on internal components.External desuperheating devices that reduce enthalpyto 1225 Btu/lb must be located sufficiently upstreamof the condenser to ensure adequate mixing of theattemperation fluid, such that when the steam reach-es the condenser, super-heated conditions are main-tained. Superheat within the dispersion device shouldbe in the 2S-75F range. Wet steam is not permitted.5.5.2.2 Occasionally turbine Manufacturers set spe-cificguidelines for maximum temperature at the inter-faceofthe turbine with the condenser. Main expansionjoint suppliers may also have temperature limits,which need to be taken into account. When such lim-itations are encountered, a cooling water spray cur-tain may be required within the condenser transitionarea to reduce local temperature excursions. Thewater spray should reduce temperatures below 200F.System delivery rate, pressure, and connection sizemust be coordinated with the condenserManufacturer.5.5.3 Condenser Operations5.5.3.1 The condenser Manufacturer must be providedwith total flow, pressure, temperature, enthalpy andduration of the discharge. A complete understandingof all relevant information such as simultaneous dis-charges of main exhaust flow and HP, IP, LP bypass-es is essential for proper condenser design.5.5.3.2 The preferred location for bypass discharge isillthe transition section. Discharge shall not be direct-l'd toward the steam turbine exhaust opening. Asec-ondary location may be the hotwell, but this area maynot be large enough to accept the total quantity of,.;l\'nIll. The discharge should maximize distributioninsido the condenser to allow rapid reduction of thestl'a m velocities.

" -~" I ,i : 'itt j , i4

5.5.3.3 The entrance points of turbine bypass to thecondenser should be discussed with the condensersupplier. Consideration must be given to high steamvelocity regions, internal impingement, and tube pro-tection.5.5.3.4 When the condenser is multi-shell and/ormulti-pressure configuration, it may be necessary tosplit the bypass flows between shells and/or pressurezones so that differential pressure/temperature limi-tations are not exceeded.5.5.3.5 Design philosophy for the steam bypass dis-persion device will differ for each condenserManufacturer. However, all Manufacturers must takecare to ensure a safe distance is maintained bet.weendischarge of the spray pipe and the condenser tubesin order to reduce the potential for tube vibration anderosion. Condenser neck height shall be sized toensure safe bypass operation. In general, the steamshould be discharged to avoid direct impingement onthe tubes. Tubing can be protected with grating,impingement rods, etc.5.5.4 Dispersion Device5.5.4.1 Internal piping should be designed to simpli-fy the bypass pipe support structure and allow forthermal expansion. The piping should have a mini-mum number ofbends and fittings. Where more thanone connection is used, the connections should belocated so as to ensure proper steam distributioninside the condenser.5.5.4.2 If the inlet flow temperature is 450 O F orabove a thermal sleeve should be provided. See Section5.4.8.The pipe size is dependent on the desuperheatingdevice and allowable velocities of the incoming steam.

Normal steam velocities within the pipe are in the 200-400 ftlsec range.5.5.4.3 Dispersion device design pressures are to beestablished such that blockage of the main turbineexhaust flow is minimized. Maximum line pressureshall be 250 psia.5.5.4.4 Typical hole size range is 114"- 1" in diame-ter depending on steam flow rate. Hole spacing is afunction ofline pressure and available space inside thecondenser.

5.5.4.5The condenser Manufacturer will provide ade-quate drain provisions, internal supports, thermalsleeves, and other specified design details to meetplant design needs.5.5.4.6 Piping upstream of all flowing connectionsshall be properly trapped and drained to prevent dam-aging water slugs being introduced into connections.

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6.0 VENTING eQUIPMENT CAPACITIES6.1 Venting Requirements6.1.1 Venting equipment must be capable of removingall ncn-condensibles and associated water vapor fromthe condenser to produce the minimum steam COIl-densing pressure consistent with physical dimensionsand heat transfer and to provide for deaeration ofcondensate. The sources of the non-condensibles to beremoved include. hut are not limited to:6.1.1.1 Air leakage into all system components oper-ating at sub-atmospheric pressure.6.1.1.2 Gases released from feedwater drains andvents admitted to the condenser.6.1.1.3 Gases released from make up admitted to thecondenser.

[II:,

6.1.1.4 Condensate surge tank, when utilized in aclosed cycle.6.1.1.5 Disassociation offeedwater into oxygen, hydro-gen, and other non-condensibles in certain types ofnuclear fueled cycles.6.1.2 In addition to non-condensibles, an adequateamount of associated water vapor must be vented toinsure proper performance ofthe condenser and to pro-duce reasonable velocities to minimize steam side cor-rosion within the condenser.6.2 Design Suction Pressure - In order to coordi-nate the performance of the venting equipment to beinstalled with a surface condenser serving a turbine,it is recommended that the design suction pressure bein accordance with the following:6.2.1 Electric Generating Service - The venting equip-ment design pressure is 1.0 inch HgA or the condenserdesign pressure, whichever is lower. Final selectionshould consider compatible operation of the condenserand its venting equipment over the full range of antic-ipated condenser operating pressures. In addition,the physical location of the equipment should be con-sidered when the design suction pressure is selected.6.2.2 Pumps, Compressors, and Other MechanicalDrives - The venting equipment design pressure isthat for which the condenser is designed minus 1.0inch Hg or the lowest required operating pressure,whichever is lower. Minimum is to be 1.0 inch HgA.6.3 Design Suction Temperature - The saturationtemperature of the gas vapor mixture shall be con-sidered as the steam temperature corresponding to thedesign pressure of the venting equipment less thegreater of the following:

either0.25 (Ts - T1)or7.5FThe 7.5F temperature differential and the 25% fac-tor are design values utilized to physically size theventing equipment. The actual temperature of thevapor at the vent outlet during operation is influ-

enced by the operating characteristics. till' 11011-tdensihle load. and the capacity churucterist ics (Ifventing equipment and may not nccessarilv be t'qto the 7.5GF and/or the 25(!t, differeutinl.6.4 Calculation ofWater Vapor Load ComponeiThe amount of water vapor to saturate t he n o n -c on dsibles can be calculated from the following formuln

w = _1_8 _ X ~p-,\ 'C_v_MWNc P, - PwWhen the non-condensible is dry ail' (molecuweight = 29), the weight of the water vapor callobtained from Appendix E.

6.5 Minimum Recommended Capacities - Itis nommended that the capacity of the venting equipmebe not less than the values shown in Table 9 at tdesign suction pressure to insure adequate rernovcapacity under commercial operating conditions.6.5.1 Procedure for Sizing Venting Equipment6.5.1.1 Determine the total steam flow of the unit Iadding the main turbine exhaust flow and any auxilia Iturbine exhaust flow entering all shells ofthe condense6.5.1.2 Determine the total number of MAIN turbirexhaust openings of all shells. Do not include auxiiary turbine exhaust openings.6.5.1.3 Divide flow obtained in 6.5.1.1 by exhau-opening number obtained in 6.5.1.2. The resultannumber is the EFFECTIVE STEAM FLOW EACIMAIN EXHAUST OPENING.6.5.1.4 Enter the appropriate section of Table 9 base:on whether unit is a single shell, twin shell or tripl-shell condenser and locate the flow obtained in Ste]6.5.1.3 in the left vertical column.6.5.1.5 Determine TOTAL NUMBER OF EXHAUS1OPENINGS for all shells by adding the total numberof main turbine exhaust openings to the total numberof auxiliary turbines exhausting into the condenserSplit auxiliary turbine exhaust ducts coming fromone auxiliary turbine count as one auxiliary turbineexhaust.6.S.1.6 Locate the appropriate column and capacityusing the number obtained in 6.5.1.5,6 .5 .1 . 7 If independent venting systems are utilizedfor each shell of a multi-shell condenser, the capacityof each system is determined by dividing the totalcapacity obtained from the appropriate table by thenumber of independent venting systems.6.5.1.8 The following is an example of sizing the vent-ing equipment6.5.1.S.1 Example No.1: The condenser design param-eters are the following: 'Ibtal Steam Flows From Main Turbine Exhausts =1,600,000 lblhr Total Steam Flows From Turbine Auxiliary Exhausts= Olblhr

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Number of Main Turbine Exhaust Openings = One (1) Number of Auxiliary Turbine Exhaust Openings '"Zero (0) Number of Condenser Shells One (1)6.5.1.1 The total steam flow of the unit is the sumof the main turbine exhaust and auxiliary

exhausts. [This value is 1,600,000 lb/hr.]6.5.1.2 The number of main turbine openings is one

(1).6.5.1.3 Divide 1,600,000 Ib/hr by one (1). The resultis 1,600,000 lhlhr which is the effective steamflow for each main exhaust opening.6.5.1.4 Enter Table 9A since only one condensershell is used. Usn the row listed for theEffective Steam Flow Each Main ExhaustOpening of 1,000,001 to 2,000,000 lb/hr,6.5.1.5 The total number of exhaust opening is one(1). This is determined by the sum of thetotal number main exhaust openings andauxiliary turbine openings. Since there isonly one (1) main turbine exhaust opening,use the values from the column marked "1".6.5.1.6 The intersection of this column and rowresults in a venting capacity of 15 SCFM.

6.5.1.8.2 Example No.2: The condenser design param-eters are the following: Total Steam Flows From Main Turbine Exhausts '"950,000 lblhr 'Ibtal Steam Flows From Turbine Auxiliary Exhausts= 200,000 lbihr Number of Main Turbine Exhaust Openings =Four (4) Number of Auxiliary Turbine Exhaust Openings =Two (2) Number of Condenser Shells = Two (2)6.5.1.1 The total steam flow of the unit is the sumof the main turbine exhaust and auxiliaryexhausts. [This value is 1,150,000 lb/hr.]6.5.1.2 The number ofmain turbine openings is four

(4).6.5.1.3 Divide 1,150,000 lblhr by four (4). The resultis 287,500 lb/hr which is the effective steamflow for each main exhaust opening.6.5.1.4 Enter Table 9B since two condenser shellsarc used. Use the row listed for the EffectiveSteam Flow Each Main Exhaust Opening of250,001 to 500,000 lblhr.6.5.1.5 The total number of exhaust opening is six

(6), This is determined by the sum of thetotal number main exhaust openings andauxiliary turbine openings. Since there is atotn 1of six (6 ) turbine exhaust openings, usethe values from the column marked "6".6.5.1.6 The intersect.inn of this column and rowresults in a venting capacity of30 BCFM.

6.5.2 Single Pressure Multiple Shell Units - Operatingconditions may require that each shell in a singlepressure multiple shell condensing plant have its ownindependent venting equipment for normal operation.In a multiple shell condensing plant with a singleventing system, unequal air leakage into one of thecondenser shells, unequal tube side fouling, unequaltube side water flows, and unbalanced pressure lossin the piping between either of the condenser shellsand their single unit venting system will result in apartial non-condensible pressure build-up in the con-denser shell operating at a lower pressure. Pressurein all of the shells will equalize at the pressure levelof the poorest performing shell, causing a build-up ofoxygen level in the condensate [rom the combinedmultiple shell condensing system.6.5.3 Multi-Pressure Units6.5.3.1 Multi-Pressure Units, Single Shell- The vent-ing capacity of multi-pressure condensers with pres-sure stages contained within a single shell should beconsidered the same as a single shell.6.5.3.2 Multi-Pressure Units, Multiple Shells - Theventing capacity of multi-pressure condensers withpressure stages in separate shells shall be in accor-dance with paragraph 6.5.1.6.5.3.3 Consideration should be given to the appli-catiun of independent venting equipment or othermeans to insure adequate venting.6.5.3.4 When steam jet ejectors are used, the tem-perature of the condensate entering the ejector con-densers should correspond to the pressure in thehighest pressure shell.6.5.4 Nuclear Plant Units - The selection of ventingequipment to be used with condensers for nuclearpower cycles in which additional non-condensiblegases are present should be carried out in accordancewith Section 6.0 and Table 9 with allowance for thequantity of such gases specified.6.5.5 Steam Dump (Bypass) Application - When sus-tained steam dump operation is required, ventingequipment must also be suitable to handle the designquantities of non-condensibles saturated at a tem-perature 7.5F below that corresponding to the satu-ration steam pressures at the highest condensingpressure likely to occur with full steam dump loadwith all or partial number of circulating water pumpsoperating.6.6 Rapid Evacuation Equipment - When start-ing a turbine, it is desirable to reduce the condenserpressure from atmospheric to some lower value. Thiscan be done by means of si ng le stage ejector ormechanical vacuum pump. The capacity of the deviceis dependent on the effectiveness ofthe turbine glandseals, tho volume of the condenser shells, turbine cas-ing-s, and associated duct.ing as well as the timedc,.;ired for such reduction. Where specific values arenut listed, refer to Table 8.

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1 RAPID EVACUATIONEQUIPMENT CAPACITIESTotal Steam Condensedlbs/hour *SCFM - Dry Air at 10 in HgADesign Suction Pressure

Up to 100,000100,001 to 250,000250,001 to 500,000500,001 to 1,000,0001,000,001 to 2,000,0002,000,001 to 3,000,0003,000,001 to 4,000,0004,000,001 to 5,000,0005,000,001 to 6,000,0006,000,001 to 7,000,0007,000,001 to 8,000,0008,000,001 to 9,000,0009,000,001 to 10,000,000

5010020035070010501400175021002450280031503500

Note: In the range of 500 ,000 lbs/hr steam condensed and above, the above table provides evacuation of the.in the condenser and L.P. turbine from atmospheric pressure to 10 in. HgA in about 30 minutes if the volu:of condenser and L.P. turbine is assumed to be 26 cu ft / 1000 lb/hr of steam condensed.*SCFM - 14.7 psia at 70F - to convert to lbs./hr, multiply above values by 4.5.Table 8

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1000"

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7.0 ATMOSPHERIC RELIEF DEVICES7.1 General7.1.1 The size of atmospheric relief devices is depen-dent upon the local operating conditions. Itis alwaysunderstood that they must be of sufficient size to passall of the steam which can be admitted to a condenserthrough any openings, except from the lines which arealready protected by relief devices set to open at pres-sures not exceeding lO psig.7.1.2 The size and location of atmospheric reliefdevices should be based onthe following criteria:7.1.2.1 Device size and associated piping should beselected to prevent pressure in condenser from exceed-ing 10 psig.7.1.2.2 Relief'deviccs should be located and installedso they are readily accessible for inspection and repair.The protective devices need not be directly installedon the condenser but may be installed on the turbineexhaust hood.7.1.3 Exhaust from all relief devices must be prop-erly vented by purchaser to avoid injury to personnelor damage to equipment.7.1.4 Reliefdevices should be supported by purchas-er and provisions made to keep discharge thrustand/or thermal expansion forces from being trans-mitted to condenser shell.7.2 Atmospheric Relief Valves7.2.1 Install a water seal around the valve disc ofample depth to ensure proper sealing of the seat withprovision for adequate drainage.

7.2.2 Valve should be equipped with a manual liftin,or opening device for maintenance purposes.7.2.3 For valve size selection sec Table 10.7.3 Rupture Devices7.3.1 A rupture disc is a non-reclosing pressure relictapparatus actuated by static pressure and designedto function by the bursting of a pressure containingdisc.7.3.2 Every rupture disc shall have a burst pressuretagged in accordance with the design requirements.7.3.3 Rupture discs may be located on the condenserfor ease of replacement. A removable protective cageor an equivalent design must be installed by pur-chaser to protect plant personnel and avert acciden-tal disc damage.7.3.4 The following equation may be used to size rup-ture discs based on dry saturated steam:AD = 70Ws~A3600Where,

An =minimum required flow areaWs = discharge flow rate~ = flow coefficient, use value of 0.62PA = relieving pressure7.3.5 Rupture discs shall be designed to operate sat-isfactorily, and without leakage under full vacuum.

ATMOSPHERIC RELIEF VALVE SIZESSize Maximum Relief Flow (pounds per hour)6 75008 20 00010 30,00012 4500014 6200016 8200018 12000020 17000024 25000030 380 00036 550,000

Sizes with flows listed are for reference only

Table 10

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rI

8.0 CONSTRUCTION8.1 General8.1.1 Design Philosophy - This standard contains~encral rules for the structural design of surface con-denser shells, waterboxes, and tubesheets. In thoseinstances where complete details and procedures arenot specified, it is intended that the Manufacturerwill utilize design and construction procedures whichhave been demonstrated as being adequate for the ser-vice intended and conform to accepted engineeringpractices. Because of their unique structure, largesteam surface condenser components are usuallydesigned by application ofconventional elastic designprocedures. The methods utilized are those that havebeendeveloped and/or applied based on the experienceofthe various Manufacturers. The steam side oflargesteam surface condensers is under an essentially stat-ic loading condition, and is constructed using ductilematerials; the structural design lends itself alterna-tively to the application of limit analysis techniqueswhich may supplement and/or replace conventionalelastic design procedures.8.1.2 Materials of Construction - Table 11 indicatestypical acceptable construction materials for con-denser shells and water boxes. Application ofa designprocedure based on conventional elastic analysis ofthestructure, together with the allowable stress value(SA), will provide a factor ofsafety (FS) against exten-sive yielding.FS = Sy

SAExcept where specifically Doted, the designformulaepresented in these standards are to beused in conjunction with the allowable stressvalues taken from Section n, Part Dofthe lat-estASMEPressure VesselCode.8.1.3 Design Pressures8.1.3.1 Condenser Shell- The design pressure oftheshell shall be 30 in Hg vacuum and suitable for anemergency internal pressure of 15 psig with anallowance, if necessary, for static head developed dur-ing hydrostatic test (refer to Section 8.1.4) ofthe shellwhen the units exceed 34 feet in height. If limit anal-ysis is employed as a design technique, subject to therequirements of Section 8.2.2, then the limit designpressure shall be no less than 15 psig times the loadfacto!' ofsafety as defined in Section 8,2.2.2. A similardefinition of the limit load shall apply where theh.vctrnstatie test condition governs the design.8.1.3.2 Water Box - The water box design pressureat tilt' bottom of the box shall be specified by thel'ul'cha:;er, It is defined as the pressure to be used intIll' ctl'Hignof the water box for the purpose of deter-uri !ling' tilt' minimum permissible thickness and/or"t . ruct U 1 ' < 1 t churacter ist.ic of the ('(IIII pouent. The!'ul'l'ha,;er in determining the pressure should includel'ol)t>iol'l'ation for, but not be limited to, normal opet-;Iti ng pressure and/or vacuum and temperuture atwhich the component will function. The de::;ig;npressure

should include the range of operating pressures asaffected by system characteristics; e.g., considerationof static heads, pump shut off heads, pressure surges,etc. The Purchaser, however, shall design the circu-lating water system to eliminate pressure surges suchas water hammer.The Purchaser shall specify the magnitude anddirection of external loadings on the water box noz-zles and shall design the circulating water piping sothat unacceptable loads are not imposed upon thewater box. Consideration shall be given to the use oftics across the circulating water nozzle expansionjoints, or an equivalent load limiting device givingdue consideration to thermal movements. The resul-tant luad distribution shall be mutually agreed uponby Manufacturer and Purchaser.8.1.4 Hydrostatic Testing - All shop hydrostatic testsshall be performed prior to applying any paint, coat-ings or linings to pressure boundary joints. Durationof test shall be that established by Manufacturer'sQuality Assurance Department as necessary to deter-mine leakage or deficiency. Itis recommended that theshell and/or water box not be subjected to hydrostatictest conditions where the material temperatures willbe below 60QF. lfthe Purchaser anticipates lower testtemperatures, he shall also specify the material to beused for the shell and/or water box.8.1.4.1 Condenser Shell8,1.4.1.1 One-piece, shop-tubed condensers shall betested by filling with clean water.8.1.4.1.2 Field assembled condensers shall be testedin the installed position by filling with clean water.The water level shall be maintained approximatelyune foot above final joint of condenser exhaust neckto turbine. The temperature of the water used to testthe shell shall not be below 60F unless materials ofconstruction have sufficiently low Nil DuctilityTransition Temperature. Ifthe total height of the unitexceeds 34 feet, a suitable design and/or test proce-dure should be agreed upon by Manufacturer andPurchaser. The shell side and the water side testsshall not be conducted simultaneously.8.1.4.1.3 Side exhaust units require special hydro-static field test procedures because of possible dam-age to the turbine. The test procedure shall be asagreed upon by the Manufacturer and Purchaser.8.1.4.2 Waler Box8.1.4.2.1 Hydrostatic test pressure for water boxesshall be 1.3 times design pressure except that theminimum shall be 2 1 1 psig. If analyses as described inSection 8.2.2 are used, special consideration should begiven to establishing hydrostatic test pressure.8.1.4.2,2 Hydrostatic test shall be performed in thefield after completion of the condenser erection. Thefield hvdrust