Petroleum Refinery Process Modeling : Integrated Optimization Tools and Applications /: Integrated Optimization Tools and Applications. (2018)

• Record Type: Book
• Further Information: Note: Y. A. Liu, Ai-Fu Chang, Kiran Pashikanti.
• Authors: Liu, Y. A; Chang, Ai-Fu; Pashikanti, Kiran
• Contents: About the Authors xiii Foreword by Lawrence B. Evans xv Foreword by Steven R. Cope xvii Preface xix Acknowledgments xxiii Scope of Textbook xxv Software Selection and Copyright Notice xxvii 1 Characterization and Physical and Thermodynamic Properties of Oil Fractions 1 1.1 Crude Assay 1 1.1.1 Bulk Properties 2 1.1.2 Fractional Properties 6 1.1.3 Interconversion of Distillation Curves 7 1.2 Boiling Point-Based Hypothetical or Pseudocomponent Generation 8 1.3 Workshop 1.1 – Interconvert Distillation Curves 13 1.4 Workshop 1.2 – Extrapolate an Incomplete Distillation Curve 13 1.5 Workshop 1.3 – Calculate MeABP of a Given Assay 13 1.6 Workshop 1.4 – Represent an Oil Fraction by the Old Oil Manager in Aspen HYSYS Petroleum Refining 16 1.7 Workshop 1.5 – Represent an Oil Fraction by the New Petroleum Assay Manager in Aspen HYSYS Petroleum Refining 25 1.8 Workshop 1.6 – Conversion from the Oil Manager to Petroleum Assay Manager and Improvements of the Petroleum Assay Manager over the Oil Manager 32 1.9 Property Requirements for Refinery Process Models 33 1.10 Physical Properties 36 1.10.1 Estimating Minimal Physical Properties for Pseudocomponents 36 1.10.2 MolecularWeight 37 1.10.3 Critical Properties 38 1.10.4 Liquid Density 40 1.10.5 Ideal Gas Heat Capacity 42 1.10.6 Other Derived Physical Properties 43 1.11 ProcessThermodynamics 45 1.11.1 Process Thermodynamics 47 1.11.2 Mixed or Activity Coefficient-Based Approach 47 1.11.3 Equation-of-State Approach 49 1.12 Miscellaneous Physical Properties for RefineryModeling 50 1.12.1 Two Approaches for Estimating Fuel Properties 51 1.12.2 Flash Point 52 1.12.3 Freeze Point 52 1.12.4 PNA Composition 53 1.13 Conclusion 54 Nomenclature 55 Bibliography 56 2 Atmospheric or Crude Distillation Unit (CDU) 59 2.1 Introduction 59 2.2 Scope of the Chapter 60 2.3 Process Overview 60 2.3.1 Desalting 61 2.3.2 Preheat Train and Heat Recovery 62 2.3.3 Atmospheric Distillation 62 2.4 Model Development 65 2.4.1 MESH Equations 66 2.4.2 Overall Column Efficiency and Murphree Stage Efficiency 66 2.4.3 Recommendation for Correctly Handling the Efficiency 68 2.4.4 Inside-Out Algorithm for Distillation Column Calculation Convergence 69 2.5 Feed Characterization 72 2.6 Data Requirements and Validation 73 2.7 A Representative Atmospheric Distillation Unit 76 2.8 Building the Model in Aspen HYSYS Petroleum Refining 77 2.8.1 Entering the Crude Information 78 2.8.2 Selection of aThermodynamic Model 84 2.8.3 Crude Charge and Prefractionation Units 87 2.8.4 Atmospheric Distillation Column – Initial 88 2.8.5 Atmospheric Distillation Column – Side Strippers 95 2.8.6 Atmospheric Distillation Column – Pumparounds 98 2.8.7 Atmospheric Distillation Column – Adding Custom Stream Properties 101 2.8.8 Post-Convergence 104 2.9 Results 105 2.10 Model Applications to Process Optimization 109 2.10.1 Improve the 5% Distillation Point for an Individual Cut 109 2.10.2 Change Yield of a Given Cut 109 2.10.3 Workshop 2.1 – Perform Case Studies to Quantify the Effects of Stripping Steam Rate and Product Draw Rate 111 2.11 Workshop 2.2 – Rebuild Model Using “Backblending” Procedure 114 2.11.1 Import Distillation Data into Aspen HYSYS Oil Manager 115 2.11.2 Define a New Blend of the Backblended Crude Feed 116 2.11.3 Build the CDU Model Based on the Backblended Feed 120 2.11.4 Converging Column Model 120 2.11.5 Comparison of Results 123 2.12 Workshop 2.3 – Investigate Changes in Product Profiles with New Product Demands 126 2.12.1 Update Column Specifications 126 2.12.2 Vary Draw Rate of LGO 127 2.13 Workshop 2.4 – Investigate the Effects of Process Variables on Product Qualities 129 2.14 Workshop 2.5 – Application of Column Internal Tools (Column Hydraulic Analysis) 131 2.15 Workshop 2.6 – Application of the Petroleum Distillation Column 140 2.16 Conclusions 144 Nomenclature 145 Bibliography 145 3 Vacuum Distillation Unit 147 3.1 Process Description 147 3.2 Plant Data Reconciliation 149 3.2.1 Required Data 149 3.2.2 Representation of the Atmospheric Residue 149 3.2.3 Makeup of Gas Streams 152 3.3 Model Implementation 154 3.3.1 Plant Data and Modeling Approaches 155 3.3.2 Workshop 3.1 – Build the Simplified VDU Model 157 3.3.3 Workshop 3.2 – Build the Rigorous Model from a Simplified Model 165 3.4 Model Application – VDU Deep-Cut Operation 172 3.5 Workshop 3.3 – Simulation of the VDU Deep-Cut Operation 176 Bibliography 180 4 Predictive Modeling of the Fluid Catalytic Cracking (FCC) Process 183 4.1 Introduction 184 4.2 Process Description 185 4.2.1 Riser–Regenerator Complex 185 4.2.2 Downstream Fractionation 187 4.3 Process Chemistry 188 4.4 Literature Review 190 4.4.1 KineticModels 190 4.4.2 Unit-LevelModels 193 4.5 Aspen HYSYS Petroleum Refining FCC Model 195 4.5.1 Slip Factor and Average Voidage 196 4.5.2 21-Lump Kinetic Model 197 4.5.3 Catalyst Deactivation 198 4.6 Calibrating the Aspen HYSYS Petroleum Refining FCC Model 199 4.7 Fractionation 200 4.8 Mapping Feed Information to Kinetic Lumps 203 4.8.1 Fitting Distillation Curves 203 4.8.2 Inferring Molecular Composition 205 4.8.3 Convert Kinetic Lumps to Fractionation Lumps 208 4.9 Overall Modeling Strategy 209 4.10 Results 211 4.11 Applications 220 4.11.1 Improving Gasoline Yield 220 4.11.2 Increasing UnitThroughput 223 4.11.3 Sulfur Content in Gasoline 224 4.12 Refinery Planning 225 4.13 Workshop 4.1 – Guide for Modeling FCC Units in Aspen HYSYS Petroleum Refining 231 4.13.1 Introduction 231 4.13.2 Process Overview 231 4.13.3 Process Data 231 4.13.4 Aspen HYSYS and Initial Component and Thermodynamics Setup 231 4.13.5 Basic FCC Model 238 4.13.6 FCC Feed Configuration 241 4.13.7 FCC Catalyst Configuration 246 4.13.8 FCC Operating Variable Configuration 250 4.13.9 InitialModel Solution 252 4.13.10 Viewing Model Results 253 4.14 Workshop 4.2 – Calibrating Basic FCC Model 258 4.15 Workshop 4.3 – Build the Model for Main Fractionator and Gas Plant System 267 4.15.1 T201_MainFractionator 267 4.15.2 OverheadWet Gas System, Primary Stripper Column T302_Stripper, and Debutanizer or Gasoline Stabilization Column T304_Stabilizer 275 4.15.3 T301_Absorber, Primary Absorber and T303_ReAbsorber, Sponge Oil Absorber, or Reabsorption Column 281 4.16 Workshop 4.4 – Perform Case Studies to Quantify Effects of Key FCC Operating Variables 285 4.17 Workshop 4.5 – Generate Delta-Base Vectors for Linear Programming (LP)-Based Planning 291 4.18 Conclusions 297 Nomenclature 298 Bibliography 299 5 Predictive Modeling of Continuous Catalyst Regeneration (CCR) Reforming Process 303 5.1 Introduction 304 5.2 Process Overview 304 5.3 Process Chemistry 311 5.4 Literature Review 313 5.4.1 KineticModels and Networks 314 5.4.2 Unit-LevelModels 317 5.5 Aspen HYSYS Petroleum Refining Catalytic Reformer Model 319 5.6 Thermophysical Properties 323 5.7 Fractionation System 323 5.8 Feed Characterization 324 5.9 Model Implementation 328 5.9.1 Data Consistency 329</
• Edition: 1st
• Publisher Details: Wiley-VCH
• Publication Date: 2018
• Extent: 1 online resource (312 pages)
• Languages: English
• ISBNs: 9783527813384
• Access Rights: Legal Deposit; Only available on premises controlled by the deposit library and to one user at any one time; The Legal Deposit Libraries (Non-Print Works) Regulations (UK).
• Access Usage: Restricted: Printing from this resource is governed by The Legal Deposit Libraries (Non-Print Works) Regulations (UK) and UK copyright law currently in force.