Acid gas extraction for disposal and related topics / edited by Ying Wu, John J. Carroll and Weiyao Zhu.

Format:

Book

Contributor:

Wu, Ying (Petroleum engineer), editor.

Carroll, John J., 1958- editor.

Zhu, Weiyao, editor.

Series:

Advances in natural gas engineering.

Advances in Natural Gas Engineering

Language:

English

Subjects (All):

Gas extraction.

Natural gas--Environmental aspects.

Natural gas.

Physical Description:

1 online resource (399 p.)

Edition:

1st ed.

Place of Publication:

Hoboken, New Jersey : Scrivener Publishing, 2016.

Language Note:

English

Summary:

This is the fifth volume in a series of books focusing on natural gas engineering, focusing on the extraction and disposal of acid gas. This volume includes information for both upstream and downstream operations, including chapters on modeling, carbon capture, chemical and thermodynamic models, and much more. Written by some of the most well-known and respected chemical and process engineers working with natural gas today, the chapters in this important volume represent the most cutting-edge and state-of-the-art processes and operations being used in the field. Not available anywhere else, this volume is a must-have for any chemical engineer, chemist, or process engineer working with natural gas. There are updates of new technologies in other related areas of natural gas, in addition to the extraction and disposal of acid gas, including testing, reservoir simulations, acid gas injection, and natural gas hydrate formations. Advances in Natural Gas Engineering is an ongoing series of books meant to form the basis for the working library of any engineer working in natural gas today. Every volume is a must-have for any engineer or library.

Contents:

Cover

Title Page

Copyright Page

Contents

Preface

1 Rate-Base Simulations of Absorption Processes

Fata Morgana or Panacea?

1.1 Introduction

1.2 Procede Process Simulator (PPS)

1.3 Mass Transfer Fundamentals

1.4 CO2 Capture Case

1.5 Conclusions and Recommendations

References

2 Modelling in Acid Gas Removal Processes

2.1 Introduction

2.2 Vapour-Liquid Equilibria

2.3 Modelling

2.3.1 Empirical Models

2.3.2 Activity Coefficient Models

2.3.3 Two (and more) Solvent Models

2.3.4 Single Solvent Models

2.3.5 Equation of State Models

2.4 Conclusions

3 Thermodynamic Approach of CO2 Capture, Combination of Experimental Study and Modeling

3.1 Introduction

3.2 Thermodynamic Model

3.3 Carbon Dioxide Absorption in Aqueous Solutions of Alkanolamines

3.4 Conclusion

4 Employing Simulation Software for Optimized Carbon Capture Process

4.1 Introduction

4.2 Acid Gas Cleaning - Process and Business Goals

4.3 Modeling Gas Treating in Aspen HYSYS®

4.3.1 Inbuilt Thermodynamics

4.3.2 Rate-Based Distillation in Aspen HYSYS

4.4 Conclusion

5 Expectations from Simulation

5.1 Introduction

5.2 Realism

5.2.1 Conclusion 1

5.2.2 Conclusion 2

5.2.3 Conclusion 3

5.2.4 Conclusion 4

5.3 Reliability of Simulation Data: What's Data and What's Not

5.3.1 Conclusion 5

5.3.2 Conclusion 6

5.3.3 Conclusion 7

5.3.4 Conclusion 8

5.4 Case Studies

5.4.1 Hellenic Petroleum Refinery Revamp

5.4.2 Treating a Refinery Fuel Gas

5.4.3 Carbon Dioxide Removal in an LNG Unit

5.4.4 Tail Gas Treating

5.5 Concluding Remarks

6 Calorimetry in Aqueous Solutions of Demixing Amines for Processes in CO2 Capture

6.1 Introduction

6.2 Chemicals

6.3 Liquid-Liquid Phase Equilibrium.

6.4 Mixing Enthalpies of {Water-Amine} and {Water-Amine-CO2}

6.4.1 Excess Enthalpies

6.4.2 Enthalpies of Solution

6.5 Acknowledgements

7 Speciation in Liquid-Liquid Phase-Separating Solutions of Aqueous Amines for Carbon Capture Applications by Raman Spectroscopy

7.1 Introduction

7.2 Experimental

7.2.1 Materials

7.2.2 Sample Preparation

7.2.3 Raman Spectroscopic Measurements

7.2.4 Methodology Validation

7.2.5 Laser Selection Optimization

7.3 Results and Discussion

7.3.1 Ammonium Carbamate System

7.3.2 Methylpiperidine Band Identification

7.3.3 (N-methylpiperidine + Water + CO2) System

7.3.4 (2-methylpiperidine + Water + CO2) System

7.3.5 (4-methylpiperidine + Water + CO2) System

7.4 Conclusions

7.5 Acknowledgements

8 A Simple Model for the Calculation of Electrolyte Mixture Viscosities

8.1 Introduction

8.2 The Expanded Fluid Viscosity Model

8.3 Results and Discussion

8.3.1 EF Model for Salts Neglecting Dissociation

8.3.2 EF Model for Ionic Species

8.4 Conclusions

9 Phase Equilibria Investigations of Acid Gas Hydrates: Experiments and Modelling

9.1 Introduction

9.2 Experimental Methods

9.3 Results and Discussion

9.4 Conclusions

9.5 Acknowledgements

10 Thermophysical Properties, Hydrate and Phase Behaviour Modelling in Acid Gas-Rich Systems

10.1 Introduction

10.2 Experimental Setups and Procedures

10.2.1 Saturation and Dew Pressure Measurements and Procedures

10.2.2 Hydrate Dissociation Measurements and Procedures

10.2.3 Water Content Measurements and Procedures

10.2.4 Viscosity and Density Measurements and Procedures

10.2.5 Frost Point Measurements and Procedures

10.2.6 Materials

10.3 Thermodynamic and Viscosity Modelling

10.3.1 Fluid and Hydrate Phase Equilibria Model.

10.4 Results and Discussions

10.5 Conclusions

10.6 Acknowledgements

11 "Self-Preservation" of Methane Hydrate in Pure Water and (Water + Diesel Oil + Surfactant) Dispersed Systems

11.1 Introduction

11.2 Experiments

11.2.1 Material

11.2.2 Apparatus

11.2.3 Experimental Procedure

11.3 Results and Discussion

11.3.1 Self-Preservation Effect without Surfactant in Low Water Cut Oil-Water Systems

11.3.2 Self-Preservation Effect without Surfactant in High Water Cut Oil-Water Systems

11.3.3 The Effect of Different Surfactants on Self-Preservation Effect in Different Water Cut Oil-Water Systems

11.4 Conclusions

11.5 Acknowledgement

12 The Development of Integrated Multiphase Flash Systems

12.1 Introduction

12.2 Algorithmic Challenges

12.3 Physical-Chemical Challenges

12.4 Why Solids?

12.5 Equation of State Modifications

12.6 Complex Liquid-Liquid Phase Behaviour

12.7 Hydrate Calculations

12.7 Conclusions and Future Work

13 Reliable PVT Calculations - Can Cubics Do It?

13.1 Introduction

13.2 Two Parameter Equations of State

13.3 Two Parameter Cubic Equations of State Using Volume Translation

13.4 Three Parameter Cubic Equations of State

13.5 Four Parameter Cubic Equations of State

13.6 Conclusions and Recommendations

14 Vapor-Liquid Equilibria Predictions of Carbon Dioxide + Hydrogen Sulfide Mixtures using the CPA, SRK, PR, SAFT, and PC-SAFT Equations of State

14.1 Introduction

14.2 Results and Discussion

14.3 Conclusions

14.4 Acknowledgements

15 Capacity Control Considerations for Acid Gas Injection Systems

15.1 Introduction

15.2 Requirement for Capacity Control

15.3 Acid Gas Injection Systems

15.4 Compressor Design Considerations.

15.5 Capacity Control in Reciprocating AGI Compressors

15.6 Capacity Control in Reciprocating Compressor/PD Pump Combinations

15.7 Capacity Control in Reciprocating Compressor/Centrifugal Pump Combinations

15.8 Capacity Control When Using Screw Compressors

15.9 Capacity Control When Using Centrifugal Compression

15.10 System Stability

15.11 Summary

Reference

16 Review and Testing of Radial Simulations of Plume Expansion and Confirmation of Acid Gas Containment Associated with Acid Gas Injection in an Underpressured Clastic Carbonate Reservoir

16.1 Introduction

16.2 Site Subsurface Geology

16.2.1 General Stratigraphy and Structure

16.2.2 Geology Observed in AGI #1 and AGI #2

16.3 Well Designs, Drilling and Completions

16.3.1 AGI #1

16.3.2 AGI #2

16.4 Reservoir Testing and Modeling

16.4.1 AGI #1

16.4.2 Linam AGI #2

16.4.3 Comparison of Reservoir between Wells

16.4.4 Initial Radial Model and Plume Prediction

16.4.5 Confirmation of Plume Migration Model and Integrity of Caprock

16.5 Injection History and AGI #1 Responses

16.6 Discussion and Conclusions

17 Three-Dimensional Reservoir Simulation of Acid Gas Injection in Complex Geology - Process and Practice

17.1 Introduction

17.2 Step by Step Approach to a Reservoir Simulation Study for Acid Gas Injection

17.3 Seismic Data and Interpretation

17.4 Geological Studies

17.5 Petrophysical Studies

17.6 Reservoir Engineering Analysis

17.7 Static Modeling

17.8 Reservoir Simulation

17.9 Case History

17.10 Injection Interval Structure and Modeling

17.11 Petrophysical Modeling and Development of Static Model

17.12 Injection Zone Characterization

17.13 Reservoir Simulation

17.14 Summary and Conclusions

References.

18 Production Forecasting of Fractured Wells in Shale Gas Reservoirs with Discontinuous Micro-Fractures

18.1 Introduction

18.2 Multi-Scale Flow in Shale Gas Reservoir

18.2.1 Multi-scale Nonlinear Seepage Flow Model of Shale Gas Reservoir

18.2.2 Adsorption - Desorption Model of Shale Gas Reservoir

18.3 Physical Model and Solution of Fractured Well of Shale Gas Reservoir

18.3.1 The Dual Porosity Spherical Model with Micro-Fractures Surface Layer

18.3.2 The Establishment and Solvement of Seepage Mathematical Model

18.4 Analysis of Influencing Factors of Sensitive Parameters

18.5 Conclusions

18.6 Acknowledgements

19 Study on the Multi-Scale Nonlinear Seepage Flow Theory of Shale Gas Reservoir

19.1 Introduction

19.2 Multi-Scale Flowstate Analyses of the Shale Gas Reservoirs

19.3 Multi-Scale Nonlinear Seepage Flow Model in Shale Gas Reservoir

19.3.1 Nonlinear Seepage Flow Model in Nano-Micro Pores

19.3.2 Multi-Scale Seepage Model Considering of Diffusion, Slippage

19.3.3 Darcy Flow in Micro Fractures and Fractured Fractures

19.4 Transient Flow Model of Composite Fracture Network System

19.5 Production Forecasting

19.6 Conclusions

19.7 Acknowledgements

20 CO2 EOR and Sequestration Technologies in PetroChina

20.1 Introduction

20.2 Important Progress in Theory and Technology

20.2.1 The Miscible Phase Behaviour of Oil-CO2 System

20.2.2 CO2 Flooding Reservoir Engineering Technology

20.2.3 Separated Layer CO2 Flooding, Wellbore Anti-Corrosion and High Efficiency Lift Technology

20.2.4 Long Distance Pipeline Transportation and Injection Technology

20.2.5 Produced Fluid Treatment for CO2 Flooding and Cycling Gas Injection Technology

20.2.6 CO2 Flooding Reservoir Monitoring, Performance Analysis Technology.

20.2.7 Potential Evaluation for CO2 Flooding and Storage.

Notes:

Description based upon print version of record.

Includes bibliographical references at the end of each chapters and index.

Description based on print version record.

ISBN:

9781118938621

1118938623

9781523109982

152310998X

9781118938652

1118938658

9781118938638

1118938631

OCLC:

936040609