Page 8 - APPLIED PROCESS DESIGN FOR CHEMICAL AND PETROCHEMICAL PLANTS, Volume 1, 3rd Edition

Contents

Preface to the Third Edition ... . ... . .... ... . ... . ... . ... . ... .... . . .. . ... .. viii Use of Base Correction Multipliers, 121; Panhandle-A Gas
Flow Formula, 121; Modified Panhandle Flow Formula, 121;
1. Process Planning, Scheduling and Flowsheet American Gas Association (AGA) Dry Gas Method, 121; Com-
Design............................................................................ 1 plex Pipe Systems Handling Natural ( or similar) Gas, 122;
Organizational Structure, I; 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, IO; General Arrangements Guide, 11; 124; Flow Patterns, 124; Total System Pressure Drop, 125;
Computer-Aided Flowsheet Design/Drafting, 17; Flowshcet 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 Lines, 18; Test Pressure for Lines, 18; Work- tions, 128; Low Absolute Pressure Systems for Air, 129; Vacuum
ing Schedules, 29; Standards and Codes, 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, 16 l : 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, 52; 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, Re (Sometimes used NRE), 67: Fric- tion Effects, 186; Suction Head or Suction Lift, 186; Discharge
tion Factor, f, 68; Pipe-e-Relative Roughness, 68; Pressure Drop Head, h<l, 187; Velocity I-lead, 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: NPSI-1 Available in Open Vessel System al Sea Level, 190;
Varying Sizes of Internal Dimensions, 72: Validity of K Values, Example 3-5: NPSI-1 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 2-1: Pipe Sizing Using Resistance Coefficients, K, ple 3-8: Closed System Steam Surface Condenser ::slPSH
83; Example 2-2: Laminar Flow Through Piping System, 86; Requirements, 191; Example 3-9: Process Vacuum System, 192;
Alternate Calculation Basis for Piping System Friction Head Reductions in NPSHR, 192; Example 3-10: Corrections to
Loss: Liquids, 86; Equivalent Feet Concept for Valves, Fittings, NPSI-IR for Hot Liquid Hydrocarbons and 'Nater, 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 NPSI-IR 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 Cormell's Method, 92; Exam- 194; Example 3-12: "Type Specific Speed," 197; Rotative
ple 2-4: Using 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; Water 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 RP:\-1, 203; Example 3-16: Pump Perfor-
Compressible Vapors and Gases, 103; Example 2-8: Pressure mance Correction For Viscous Liquid, 203; Example 3-17: 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: Stearn Flow Using Babcock Formula, 107; Sonic Condi- Temperature Rise Using Boiler Feed Water, 209; Example
tions Limiting Flow of Gases and Vapors, 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, 21 O; 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,

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