Surface process, transportation, and storage / edited by Qiwei Wang.

Format:

Book

Contributor:

Wang, Qiwei, editor.

Series:

Oil and Gas Chemistry Management

Language:

English

Subjects (All):

Petroleum engineering.

Petroleum--Transportation.

Petroleum.

Petroleum--Storage.

Physical Description:

1 online resource (555 pages)

Place of Publication:

Cambridge, Massachusetts : Gulf Professional Publishing, [2023]

Summary:

The fourth reference in the series, Surface Process, Transportation, and Storage delivers the critical basics while also covering latest research developments and practical solutions. Organized by the type of challenges, this volume facilitates engineers to fully understand underlying theories, practical solutions, and keys for successful applications. Basics include produced fluids treating, foam control, pipeline drag reduction, and crude oil and natural gas storage, while more advanced topics cover CO2 recovery, shipment, storage, and utilization. Supported by a list of contributing experts from both academia and industry, this volume brings a necessary reference to bridge petroleum chemistry operations from theory into more cost-effective and sustainable practical applications.

Contents:

Front Cover

Surface Process, Transportation, and Storage

Copyright Page

Contents

List of contributors

1 Chemical scavenging of hydrogen sulfide and mercaptans

1.1 Introduction

1.2 Hydrogen sulfide and mercaptan measurement

1.3 Hydrogen sulfide and mercaptan partitioning in oil, water, and gas

1.4 Chemical scavengers

1.4.1 Solid scavengers

1.4.2 Oxidizing chemicals

1.4.3 Aldehydes

1.4.4 Formaldehyde reaction products

1.4.5 High valence metal compounds

1.4.6 Aqueous alkaline solutions

1.4.7 Hydrogen fluoride

1.4.8 Novel hydrogen sulfide scavengers from biological sources

1.5 Physical chemistry of scavengers

1.5.1 Scavenging kinetics

1.5.2 Scavenger thermodynamics

1.6 Laboratory testing of hydrogen sulfide and mercaptan scavengers

1.6.1 ASTM D5705 test methodology with modifications

1.6.2 Laboratory assessment of hydrogen sulfide and mercaptan scavengers in towers

1.6.3 Continuous gas flow apparatus

1.7 Hydrogen sulfide and mercaptan scavenging process

1.7.1 In-line injection

1.7.2 Gas lift injection

1.7.3 Capillary injection

1.7.4 Contact towers

1.7.5 Storage tanks

1.7.6 Rail cars

1.7.7 Scavengers in acidizing treatment

1.8 Case studies

1.8.1 Optimization of South Texas system

1.8.2 Optimization of scavenging cost from joint industry program

1.8.3 Scavenger automation at sour gas processing facility

1.8.4 Development of sour reservoir in giant field in Kuwait

1.8.5 Development of sour gas field in the Netherlands using scavenger with scale inhibitor

1.8.6 Scavenging dry gas pipeline in Western Oklahoma

1.8.7 Scavenging in coiled tubing drilling operations in Saudi Arabia

1.8.8 Reduction of sulfur oxide content of flare gas

1.8.9 Capillary string downhole injection in South Texas.

1.8.10 Fixed bed hydrogen sulfide removal in the North Sea

1.9 Challenges associated with scavenging treatment

1.9.1 Reaction products

1.9.2 Induced scaling problems

1.9.3 Corrosion issues

1.9.4 Formation damage

1.9.5 Emulsion problems in oil and water separation

1.9.6 Overconsumption of scavenger

1.10 New developments

1.10.1 Safe operation

1.10.2 Digital transformation

1.10.3 Environmentally friendly products

1.11 Summary and conclusions

Nomenclature

References

2 Natural gas sweetening

2.1 Introduction

2.2 Gas conditioning to satisfy sales gas quality

2.3 Natural gas sweetening methods

2.4 Chemical absorption

2.4.1 Chemical reactions between H2S and CO2 and amine

2.4.2 Amine process overview

2.4.3 Design best practices

2.4.3.1 Process unit design

2.4.3.2 Main operation issues

2.5 Physical absorption

2.5.1 Propylene carbonate process

2.5.2 Dimethyl ether of polyethylene glycol (DEPG or DMEPEG) solvents

2.5.3 N-Methyl-2-pyrrolidone

2.5.4 Refrigerated methyl alcohol (methanol)

2.5.5 Combined physical and chemical absorption

2.6 Adsorption

2.7 Permeation or membrane based technologies

2.7.1 Principle

2.7.2 Polymeric membrane type

2.7.3 Membrane module types

2.7.4 Gas pretreatment

2.8 Sulfur recovery

2.8.1 Thermal section

2.8.2 Catalytic section

2.8.3 Major equipment

2.8.4 Quality of the acid gas

2.8.5 Reduction absorption tail gas treatment

2.9 Emerging approaches for treating highly sour gas

2.9.1 Cryogenic distillation

2.9.2 Membranes for high H2S

2.10 CO2 capture technology at gas plant

2.10.1 CO2 capture from flue gas

2.10.2 CO2 captured from the acid gas stream

2.10.2.1 CO2 capture upstream of SRU

2.10.2.2 CO2 capture downstream sulfur recovery plant

2.11 Final remarks

References.

3 Emulsion separation

3.1 Introduction

3.2 Emulsion formation

3.3 Emulsion stabilization

3.4 Theory of emulsion separation

3.4.1 Settling velocity of droplets

3.4.2 Coalescence rates

3.4.3 Semi-empirical approaches

3.5 Emulsion separation techniques

3.6 Thermal demulsification

3.6.1 Effect of heating on emulsion properties

3.6.2 Heater technology

3.6.3 Case studies

3.7 Mechanical internals

3.7.1 Separator vessels

3.7.2 Perforated baffles

3.7.3 Plate packs

3.7.4 Pipe separators

3.7.5 Case studies

3.8 Chemical demulsification

3.8.1 Effect of demulsifier on separation rates

3.8.2 Mechanisms of demulsifier action

3.8.3 Demulsifier formulation

3.8.4 Case studies

3.9 Electrostatic demulsification

3.9.1 Droplet migration in electric fields

3.9.2 Droplet collisions in electric fields

3.9.3 Effect of electric field properties on droplet coalescence

3.9.4 Electrocoalescer technology

3.9.5 Case studies

3.10 Concluding remarks

4 Foam control

4.1 Introduction and overview

4.1.1 Foam basics

4.1.2 Oil-based versus water-based foams

4.1.3 Antifoaming versus defoaming

4.1.4 Antifoaming versus deaeration

4.1.5 Solid-stabilized foams

4.1.6 Overview of foam stabilizer and antifoam chemistries

4.2 Oil-based foams

4.2.1 Defoaming versus demulsification

4.2.2 Nonaqueous foaming

4.2.2.1 Presence of surfactants

4.2.2.1.1 Modified hydrocarbon-type surfactants

4.2.2.1.2 PDMS and organomodified silicones

4.2.2.1.3 Fluorocarbons

4.2.2.2 Multiphase condensed media

4.2.3 Nonaqueous foams of crude oil

4.2.3.1 Factors determining crude oil foaming

4.2.3.1.1 Volume and properties of the dissolved gas

4.2.3.1.2 Crude oil composition

4.2.3.1.3 Liquid-gas interfacial properties.

4.2.3.1.4 Presence of other (solid) phases and water

4.2.3.1.5 Viscosity

4.2.3.2 Testing methods

4.2.3.3 Crude oil foaming field case histories

4.2.3.4 Crude oil lift

4.2.4 Chemistry of antifoams for oil-based foams

4.2.4.1 Silicones (siloxanes)

4.2.4.1.1 Polydimethylsiloxane

PDMS synthesis

Physical properties of PDMS

Small PDMS molecules and cyclic siloxanes

4.2.4.1.2 Organomodified silicones

Silicone polyether copolymers

Use of organomodified silicones as antifoams

4.2.4.1.3 Fluorosilicones

Properties of fluorosilicones

Use of fluorosilicones as antifoams

4.2.4.2 Nonsilicone antifoams for oil-based foams

4.3 Water-based foams

4.3.1 Chemistry of antifoams for water-based foams

4.3.1.1 Silicones, silica-filled polydimethylsiloxane

4.3.1.1.1 PDMS as antifoam for aqueous liquids

4.3.1.1.2 Mixed (oil+solid) antifoams

4.3.1.2 Nonsilicone antifoams

4.3.1.3 Antifoam formulations

4.3.2 Water-based applications

4.3.2.1 Aqueous foams in produced water and seawater injection systems

4.3.2.2 Field examples of injection water system foaming

4.3.2.3 Cementing

4.3.2.3.1 Testing cement slurry antifoams

4.3.2.3.2 Chemistry of cement slurry antifoams

4.3.2.4 Drilling and completion

4.3.2.5 Gas dehydration

4.3.2.6 Gas sweetening

4.3.2.6.1 Foaming problems in amine units

4.3.2.6.2 Use of antifoams in amine units

4.3.2.7 Water reinjection

4.3.2.8 Steam regeneration

4.3.2.9 Foam assisted lift

4.4 Mechanical defoaming

4.5 Defoaming by chemical reaction

4.6 Mechanisms of antifoaming action

4.6.1 Antifoaming of nonaqueous foams

4.6.1.1 Thermodynamic coefficients

4.6.1.2 Mechanism of nonaqueous antifoaming

4.6.2 Antifoaming of aqueous foams

4.6.2.1 The pseudoemulsion film

4.6.2.2 Effect of hydrophobic solids and penetration depth.

4.6.2.3 Rate of antifoaming and location of oil drops inside the foam

4.6.2.4 Bridging

4.6.2.5 Antifoam deactivation (durability)

4.6.2.6 Practical aspects: effects of antifoam viscosity, drop size, and mixing

4.6.2.7 Cloud point antifoams

4.6.3 Breaking solid stabilized foams

4.7 Concluding remarks

5 Polymeric drag reduction in pipelines

5.1 Drag-reducing agent history

5.2 Basic pipeline hydraulics tutorial

5.2.1 Reynolds number

5.2.2 Laminar flow

5.2.3 Turbulent flow

5.2.4 Pressure drop

5.2.5 Static head

5.2.6 Friction pressure

5.2.7 Gradient

5.2.8 Profile

5.2.9 Pipeline pumps

5.2.10 Operating point

5.2.11 Calculating drag reduction performance in a pipeline system

5.3 Drag-reducing agent chemistry

5.4 Drag reduction mechanism

5.4.1 Misconceptions

5.5 Application to the pipeline-drag-reducing agent theory

5.5.1 Applications in oil/water or multiphase pipelines

5.6 Utilization of drag-reducing agent in pipeline operations

5.6.1 Example cases for utilization in pipelines

5.6.1.1 Multi-station pipeline de-rated in the middle segment

5.6.1.2 The production rate exceeds the design capacity

5.6.1.3 Pump station bypass

5.6.1.4 New pipeline design

5.7 Conclusion

6 Natural gas storage by adsorption

6.1 Introduction

6.2 Fundamentals of adsorption

6.2.1 Definition

6.2.2 Adsorption forces

6.2.3 Adsorption separation and storage mechanism

6.2.4 Adsorption processes

6.3 Industrial adsorbents

6.3.1 Adsorbent selection

6.3.2 Silica gel

6.3.3 Activated alumina

6.3.4 Zeolites

6.3.5 Activated carbons

6.3.6 Potential novel industrial adsorbents

6.3.7 Summary of natural gas storage adsorbents

6.4 Case study: screening activated carbon for natural gas storage.

6.4.1 Experimental.

Notes:

Includes bibliographical references and index.

Description based on print version record and other sources.

Other Format:

Print version: Wang, Qiwei Surface Process, Transportation, and Storage

ISBN:

9780128242087

0128242086