Page 6 - APPLIED PROCESS DESIGN FOR CHEMICAL AND PETROCHEMICAL PLANTS, Volume 1, 3rd Edition

Contents

reface to the Third Edition ............................................. viii Use of Base Correction Multipliers, 121; Panhandlea Gas
Flow Formula, 121; Modified Panhandle Flow Formula, 121;
1 Process Plannhg, Scheduling and Flowsheet
Design ............................................................................ 1 American Gas Association (AGA) Dry Gas Method, 121; Com-
plex Pipe Systems Handling Natural (or similar) Gas, 122;
Organizational Structure, 1; Process Design Scope, 2; Role of Example 2-13: Series System, 122; Example 2-15: Parallel Sys-
the Process Design Engineer, 3; Flowsheets-Types, 4; Flow- tem: Fraction Paralleled, 122; Two-phase Liquid and Gas Flow,
sheet Presentation, 10; General Arrangements Guide, 11; 124; Flow Patterns, 124; Total System Pressure Drop, 125;
Computer-Aided Flowsheet Design/’Drafting, 17; Flowsheet Example 2-16: Two-phase Flow, 127; Pressure Drop in Vacuum
Symbols, 17; Line ,Symbols and Designations, 17; Materials of Systems, 128; Example 2-17: Line Sizing for Vacuum Condi-
Construction for L,ines, 18; Test Pressure for Lines, 18; Work- tions, 128; Low Absolute Pressure Systems for Air, 129; Vacuum
ing Schedules, 29; Standards and Ciodes, 31; System Design for Other Gases and Vapors, 129; Pipe Sizing for Non-Newton-
Pressures, 33; Time Planning and Scheduling, 36; Activity ian Flow, 133; Slurry Flow in Process Plant Piping, 134; Pres-
Analysis, 36; Collection and Assembly of Physical Property sure Drop for Flashing Liquids, 134; Example 2-18: Calcula-
Data, 37; Estimated Equipment Calculation Man-Hours, 37; tion of Steam Condensate Flashing, 135; Sizing Condensate
Estimated Total Process Man-Hours, 39; Typical Man-Hour Return Lines, 135; Design Procedure Using Sarco Chart, 135;
Patterns, 40; Influences, 42; Assignment of Personnel, 43; Example 2-19: Sizing Steam Condensate Return Line, 139.
Plant Layout. 45; Cost Estimates, 45; Six-Tenths Factor, 47;
Yearly Cost Indices, 47; Return on Investment, 48; Accounting 3. Pumping of Liquids .......... .... 160
Coordination, 48. Pump Design Standardization, 161; Basic Parts of a Centrifu-
gal Pump, 164; Impellers, 164; Casing, 165; Bearings, 168;
2. Fluid Flow ....... 52
Centrifugal Pump Selection, 173; Single-Stage (Single
Scope. 52; Basis, 5%; Compressible Flow: Vapors and Gases, 54; Impeller) Pumps, 174; Pumps in Series, 175; Pumps in Paral-
Factors of “Safety” for Design Basis, 56; Pipe, Fittings, and lel, 177; Hydraulic Characteristics for Centrifugal Pumps, 180;
Valves, 56; Pipe, 56; Usual Industry Pipe Sizes and Classes Prac- Example 3-1: Liquid Heads, 183; Static Head, 184; Pressure
tice, 59; Total Line Pressure Drop, 64; Background Informa- Head, 184; Example 3-2: Illustrating Static, Pressure, and Fric-
tion, 64; Reynolds Number, (Sometimes used N,), 67; Fric- tion Effects, 186; Suction Head or Suction Lift, 186; Discharge
tion Factor, f, 68; Pipe-Relative Roughness, 68; Pressure Drop Head, hd, 187; Velocity Head, 187; Friction, 188; NPSH and
in Fittings, Valves, Connections: Incompressible Fluid, 71; Pump Suction, 188; Example 3-3: Suction Lift, 190; Example
Common Denominator for Use of “K Factors in a System of 3-4: NPSH Available in Open Vessel System at Sea Level, 190;
Varying Sizes of Internal Dimensions, 72; Validity of K Values, Example 3-5: NPSH Available in Open Vessel Not at Sea Level,
77; Laminar Flow, 77; Piping Systems, 81; Resistance of Valves, 191; Example 3-6: NPSH Available in Vacuum System, 191;
81; Flow Coefficients for Valves, C,, p. 81; Nozzles and Orifices, Example 3-7: NPSH.&: Available in Pressure System, 191; Exam-
82; Example 8-1: Pipe Sizing Using Kesistance Coefficients, K, ple 3-8: Closed System Steam Surface Condenser NPSH
83; Example 2-2: Laminar Flow Through Piping System, 86; Requirements, 191; Example 3-9: Process Vacuum System, 192;
Alternate Calculalion Basis for Piping System Friction Head Reductions in NPSHR, 192; Example 3-10: Corrections to
LOSS: Liquids, 86; Equivalent Feet Concept for Valves, Fittings, NPSH, for Hot Liquid Hydrocarbons and U’ater, 192; Exam-
Etc., 86; Friction ]Pressure Drop for Non-Viscous Liquids, 89; ple 3-9: Process Vacuum System, 192; Example 3-10: Correc-
Estimation of Pressure Loss Across Control Valves: Liquids, tions to NPSH, for Hot Liquid Hydrocarbons and Water, 192;
Vapors, and Gases, 90; Example 2-3: Establishing Control Valve Example 3-11: Alternate to Example 3-10, 194; Specific Speed,
Estimated Pressure Drop Using Connell’s Method, 92; Exam- 194; Example 3-12: ”Type Specific Speed,” 197; Rotative
ple 2-4: TJsing Figure 2-26, Determine Control Valve Pressure Speed, 197; Pumping Systems and Performance, 197; Example
Drop and System Start Pressure, 94; Friction Loss For Water 3-13: System Head Using Two Different Pipe Sizes in Same
Flow, 96; Example 2-5: Water Flow in Pipe System, 96; MJater Line, 199; Example 3-14 System Head for Branch Piping with
Hammer, 98; Example 2-7: Pipe Flow System With Liquid of Different Static Lifts, 200; Relations Between Head, Horse-
Specific Gravity Other Than Water, 99; Friction Pressure Drop power, Capacity, Speed, 200; Example 3-15: Reducing Impeller
For Compressible Fluid Flow, 101; Darcy Rational Relation for Diameter at Fixed WM, 203; Example 3-16: Pump Perfor-
Compressible Vapors and Gases, 103; Example 2-8: Pressure mance Correction For Viscous Liquid, 203; Example 3-1 7: Cor-
Drop for Vapor System, 104; Alternate Solution to Compress- rected Performance Curves for Viscosity Effect, 206; Temper-
ible Flow Problems, 104; Friction Drop for Air, 107; Example ature Rise and Minimum Flow, 207; Example 3-18: Maximum
2-9: Steam Flow TJsing Babcock Formula, 107; Sonic Condi- Temperature Rise Using Boiler Feed Water, 209; Example
tions Limiting Flow of Gases and Vzpors, 108; Procedure, 118; 3-19: Pump Specifications, 209; Number of Pumping Units,
Example 2-10: Gas Flow Through Sharp-edged Orifice, 119; 210; Fluid Conditions, 210; System Conditions, 210; Type of
Example 2-11: Sonic Velocity, 119; Friction Drop for Com- Pump, 210; Type of Driver, 210; Sump Design for Vertical Lift,
pressible Natural Gas in Long Pipe Lines, 120; Example 2-12: 212; Rotary Pumps, 213; Selection, 214; Reciprocating Pumps,