Koh / Sum Natural Gas Hydrates in Flow Assurance

1. Auflage 2010
ISBN: 978-1-85617-946-1
Verlag: Elsevier Science & Techn.
Format: EPUB
Kopierschutz: 6 - ePub Watermark

E-Book, Englisch, 224 Seiten

With millions of kilometres of onshore and offshore oil and gas pipelines in service around the world, pipelines are the life's blood of the world. Notorious for disrupting natural gas production or transmission, the formation of natural gas hydrates can cost a company hundreds of millions and lead to catastrophic equipment breakdowns and safety and health hazards. Written by an international group of experts, Natural Gas Hydrates in Flow Assurance provide an expert overview of the practice and theory in natural gas hydrates, with applications primarily in flow assurance. Compact and easy to use, the book provides readers with a wealth of materials which include the key lessons learned in the industry over the last 20 years. Packed with field case studies, the book is designed to provide hands-on training and practice in calculating hydrate phase equilibria and plug dissociation. In addition readers receive executable programs to calculate hydrate thermodynamics. - Case studies of hydrates in flow assurance - The key concepts underlying the practical applications - An overview of the state of the art flow assurance industrial developments

Autoren/Hrsg.

Koh, Carolyn Ann

Sum, Amadeu

Inhaltsverzeichnis

1;Front Cover;1
2;Natural Gashydrates in Flow Assurance;3
3;Copyright Page;5
4;About the Authors;6
5;Contents;8
6;List of Figures;14
7;Preface;22
8;Chapter 1: Introduction;24
8.1;1.1. Why Are Hydrates Important?;24
8.2;1.2. What Are Hydrates?;25
8.3;1.3. Four Rules of Thumb Arising from Crystal Structure;27
8.4;1.4. Chapter Summary Application: Methane Hydrate Formation on an Emulsified Water Droplet;32
8.5;References;34
9;Chapter 2: Where and How Are Hydrate Plugs Formed?;36
9.1;2.1. Where Do Hydrates Form in Offshore Systems?;36
9.2;2.2. How Do Hydrate Plugs Form? Four Conceptual Pictures;39
9.2.1;2.2.1 Hydrate Blockages in Oil-Dominated Systems;40
9.2.1.1;2.2.1.1 Rules of Thumb for Hydrate Formation in Oil-Dominated Systems;41
9.2.1.2;2.2.1.2 A Model for Hydrate Formation in Oil-Dominated Flowlines;42
9.2.2;2.2.2 Hydrate Formation in Gas-Condensate Systems;45
9.2.2.1;2.2.2.1 Case Study 1: Tommeliten-Gamma Field;45
9.2.2.2;2.2.2.2 Case Study 2: Werner-Bolley Field Hydrate Formation;47
9.2.2.3;2.2.2.3 Hypothesized Mechanism for Gas-Dominated Systems;49
9.2.3;2.2.3 Hydrate Blockages in Condensate Flowlines;50
9.2.4;2.2.4 High-Water-Cut (Volume) Systems;54
9.3;2.3. Risk Management in Hydrate Plug Prevention;55
9.4;2.4. Relationship of Chapter to Subsequent Content;58
9.5;References;58
10;Chapter 3: Safety in Hydrate Plug Removal;60
10.1;3.1. Two Safety Case Studies;60
10.1.1;3.1.1 Case Study 1: One-Sided Depressurization;60
10.1.1.1;3.1.1.1 The Cause and Effect of Hydrate Projectiles;61
10.1.1.2;3.1.1.2 Predicting Plug Projectile Effects;64
10.1.1.2.1;3.1.1.2.1 Example Calculation;67
10.1.1.3;3.1.1.3 The Effect of Multiple Plugs;68
10.1.2;3.1.2 Case Study 2: Heating a Plug;68
10.2;3.2. Common Circumstances of Plug Formation and Plug Removal Safety;69
10.2.1;3.2.1 Common Circumstances of Plug Formation;69
10.2.2;3.2.2 Plug Removal Safety Recommendations;69
10.3;3.3. Relationship of Chapter to Subsequent Content;70
10.4;References;70
11;Chapter 4: How Hydrate Plugs Are Remediated;72
11.1;4.1. Introduction;73
11.2;4.2. Safety Concerns;74
11.3;4.3. Blockage Identification;75
11.3.1;4.3.1 Determining Cause of Blockage;76
11.4;4.4. Locating Blockage;77
11.5;4.5. Determining Blockage Size;78
11.6;4.6. Blockage Removal Options;79
11.6.1;4.6.1 Pressure;80
11.6.2;4.6.2 Chemical;81
11.6.3;4.6.3 Mechanical;81
11.6.4;4.6.4 Thermal;82
11.6.4.1;4.6.4.1 Heated Bundle;83
11.6.4.2;4.6.4.2 Electrical Heating;84
11.6.4.3;4.6.4.3 Heating Tent;84
11.6.4.4;4.6.4.4 Mud or Fluid Circulation;84
11.6.4.5;4.6.4.5 External Heat Tracing;85
11.6.4.6;4.6.4.6 Guiding Principles for Thermal Remediation;85
11.7;4.7. Removal Strategies;86
11.7.1;4.7.1 Pipelines/Flowlines Strategy;86
11.7.1.1;4.7.1.1 Recommended Order of Consideration;87
11.7.1.2;4.7.1.2 Detailed Discussion of Pipelines/Flowlines Strategy;87
11.7.1.2.1;4.7.1.2.1 Pressure Method;87
11.7.1.2.2;4.7.1.2.2 Chemical Management;88
11.7.1.2.3;4.7.1.2.3 Mechanical Method;88
11.7.1.2.4;4.7.1.2.4 Thermal Method;89
11.7.2;4.7.2 Wells Strategy;89
11.7.2.1;4.7.2.1 Recommended Order of Consideration;90
11.7.2.2;4.7.2.2 Detailed Discussion of Well Strategy;90
11.7.2.2.1;4.7.2.2.1 Pressure Method;90
11.7.2.2.2;4.7.2.2.2 Chemical Method;91
11.7.2.2.3;4.7.2.2.3 Mechanical Method;91
11.7.2.2.4;4.7.2.2.4 Thermal Method;91
11.7.3;4.7.3 Risers Strategy;92
11.7.3.1;4.7.3.1 Recommended Order of Consideration;92
11.7.3.2;4.7.3.2 Detailed Discussion of Riser Strategy;93
11.7.3.2.1;4.7.3.2.1 Pressure Method;93
11.7.3.2.2;4.7.3.2.2 Chemical Method;93
11.7.3.2.3;4.7.3.2.3 Mechanical Method;94
11.7.3.2.4;4.7.3.2.4 Thermal Method;94
11.8;4.8. Case Studies;98
11.8.1;4.8.1 Export Pipeline (BP Pompano);98
11.8.1.1;4.8.1.1 Strategy Employed to Dissociate the Plug;99
11.8.2;4.8.2 Gas Condensate Pipeline (Chevron);100
11.8.3;4.8.3 Well (Gas Condensate);101
11.8.4;4.8.4 Equipment (BP Gulf of Mexico);101
11.9;References;104
11.10;Appendix;105
12;Chapter 5: Artificial and Natural Inhibition of Hydrates;110
12.1;5.1. How Thermodynamic Hydrate Inhibitors Function and How They Are Used;111
12.2;5.2 The Low-Dosage Hydrate Inhibitors (LDHIs);115
12.2.1;5.2.1 Kinetic Hydrate Inhibitors;115
12.2.2;5.2.2 Anti-Agglomerants;118
12.3;5.2. The Low-Dosage Hydrate Inhibitors (Ldhis);115
12.3.1;5.2.1 Kinetic Hydrate Inhibitors;115
12.3.2;5.2.2 Anti-Agglomerants;118
12.4;5.3. Naturally Inhibited Oils;120
12.4.1;5.3.1 Viscosity of Suspension;121
12.4.2;5.3.2 Viscosity of Aggregated Suspension;121
12.4.3;5.3.3 Methodology;123
12.4.4;5.3.4 Prediction;124
12.5;5.4. Conclusion;126
12.6;References;126
13;Chapter 6: Kinetic Hydrate Inhibitors Performance;128
13.1;6.1. Introduction;128
13.2;6.2. Study 1: Miniloop Flowing KHI Hold Time;129
13.3;6.3. Study 2: Autoclave Testing Methodology;134
13.3.1;6.3.1 Introduction;135
13.3.2;6.3.2 Miniloop Equivalence Requirements;137
13.3.3;6.3.3 Device Design;139
13.3.4;6.3.4 Test Procedures and Data Interpretation;143
13.3.4.1;6.3.4.1 Teq Tests;143
13.4;6.4. Hold-Time Tests;151
13.4.1;6.4.1 Autoclave Study Summary;155
13.5;6.5. Study 3: Correlation of Miniloop, Large Loop, and Rocking Cell Results;155
13.6;6.6. Study 4-Correlation of Large Loop and Field Results;156
13.7;6.7. Conclusion;157
13.8;References;158
13.9;Appendix;159
14;Chapter 7: Industrial Operating Procedures for Hydrate Control;168
14.1;7.1. Introduction;168
14.2;7.2. Deepwater System Design;169
14.3;7.3. Applications of Chapters 1 through 6;170
14.4;7.3.1 Question 1: When and Where Are Hydrates Likely to Form in the Production System?;171
14.5;7.3.2 Question 2: What Can I Control in Order to Prevent Hydrates from Forming?;171
14.6;7.3.3 Question 3: What Are the Monitoring Points in the System That Will Give Indication of Hydrates?;172
14.6.1;7.3.3.1 Risk of Hydrate Plugging;173
14.6.2;7.3.3.2 Signs of Hydrate Plugging;173
14.7;7.3.4 Question 4: If a Hydrate Plug Forms in the Production System, How Can It Be Remediated?;174
14.7.1;7.3.4.1 Inject Chemical;175
14.7.2;7.3.4.2 Stop Flow;175
14.7.3;7.3.4.3 Reduce Flow;175
14.7.4;7.3.4.4 Increase Flow;175
14.8;7.4. Generation of Operating Procedures for Hydrate Control;176
14.8.1;7.4.1 Detailed Design—Customer : Engineering;176
14.8.2;7.4.2 Operating Guidelines—Customer : Engineering and Operations;176
14.8.3;7.4.3 Operating Procedures—Customer : Operations;177
14.9;7.5. Operating Procedure Details;178
14.9.1;7.5.1 Who Is the Customer?;179
14.9.2;7.5.2 Writing an Operating Procedure;180
14.10;7.6. Sample Operating Procedure: Cold Well Startup into Cold System;183
14.10.1;7.6.1 Pre-Startup Checklist;184
14.10.2;7.6.2 Restart Guidelines;184
14.11;7.7. Relationship of Chapter to Others in This Book;185
14.12;References;185
15;Chapter 8: Conclusion;186
15.1;8.1. Chapter 1. Basic Structures and Formation Properties;187
15.2;8.2. Chapter 2. How Hydrate Plugs Form and Are Prevented;188
15.3;8.3. Chapter 3. Hydrate Safety during Remediation;189
15.4;8.4. Chapter 4. Industrial Methods for Hydrate Plug Dissociation;190
15.5;8.5. Chapter 5. Inhibitor Mechanisms and Naturally Inhibited Oils;190
15.6;8.6. Chapter 6. Certifying Hydrate Kinetic Inhibitors for Field Performance;192
15.7;8.7. Chapter 7. Offshore Production Operating Procedures for Hydrate Control;192
16;Appendix: Six Industrial Hydrate Blockage Examples and Lessons Learned;194
17;Index;216