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- Herausgeber: John Wiley & Sons
- Kategorie: Wissenschaft und neue Technologien
- Sprache: Englisch
Gasification is one of the most important advancements that has ever occurred in energy production. Using this technology, for example, coal can be gasified into a product that has roughly half the carbon footprint of coal. On a large scale, gasification could be considered a revolutionary development, not only prolonging the life of carbon-based fuels, but making them "greener" and cleaner. As long as much of the world still depends on fossil fuels, gasification will be an environmentally friendlier choice for energy production. But gasification is not just used for fossil fuels. Waste products that would normally be dumped into landfills or otherwise disposed of can be converted into energy through the process of gasification. The same is true of biofeedstocks and other types of feedstocks, thus making another argument for the widespread use of gasification. The Handbook of Gasification Technology covers all aspects of the gasification, in a "one-stop shop," from the basic science of gasification and why it is needed to the energy sources, processes, chemicals, materials, and machinery used in the technology. Whether a veteran engineer or scientist using it as a reference or a professor using it as a textbook, this outstanding new volume is a must-have for any library.
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Table of Contents
Cover
Preface
Part 1: SYNTHESIS GAS PRODUCTION
1 Energy Sources and Energy Supply
1.1 Introduction
1.2 Typical Energy Sources
1.3 Other Energy Sources
1.4 Energy Supply
1.5 Energy Independence
References
2 Overview of Gasification
2.1 Introduction
2.2 Gasification Processes
2.3 Feedstocks
2.4 Power Generation
2.5 Synthetic-Fuel Production
2.6 Advantages and Limitations
2.7 Market Developments and Outlook
References
3 Gasifier Types – Designs and Engineering
3.1 Introduction
3.2 Gasifier Types
3.3 Designs
3.4 Mechanism
3.6 Gasifier-Feedstock Compatibility
3.7 Products
References
4 Chemistry, Thermodynamics, and Kinetics
4.1 Introduction
4.2 Chemistry
4.3 Thermodynamics and Kinetics
4.4 Products
References
Part 2: PROCESS FEEDSTOCKS
5 Coal Gasification
5.1 Introduction
5.2 Coal Types and Reactions
5.3 Processes
5.4 Product Quality
5.5 Chemicals Production
5.6 Advantages and Limitations
References
6 Gasification of Viscous Feedstocks
6.1 Introduction
6.2 Viscous Feedstocks
6.3 Gas Production
6.4 Products
6.5 Advantages and Limitations
References
7 Gasification of Biomass
7.1 Introduction
7.2 Biomass Types and Mixed Feedstocks
7.3 Chemistry
7.4 Gasification Processes
7.5 Gas Production and Products
7.6 The Future
References
8 Gasification of Waste
8.1 Introduction
8.2 Waste Types
8.3 Feedstock Properties and Plant Safety
8.4 Fuel Production
8.5 Process Products
8.6 Advantages and Limitation
References
9 Gas Cleaning
9.1 Introduction
9.2 Gas Streams
9.3 Water Removal
9.4 Acid Gas Removal
9.5 Removal of Condensable Hydrocarbons
9.6 Tar Removal
9.7 Particulate Matter Removal
9.8 Other Contaminant Removal
9.9 Tail Gas Cleaning
References
Part 3: APPLICATIONS
10 Gasification in a Refinery
10.1 Introduction
10.2 Processes and Feedstocks
10.3 Synthetic Fuel Production
10.4 Sabatier-Senderens Process
10.5 The Future
References
11 Hydrogen Production
11.1 Introduction
11.2 Processes Requiring Hydrogen
11.3 Feedstocks
11.4 Process Chemistry
11.5 Commercial Processes
11.6 Catalysts
11.7 Hydrogen Purification
11.8 Hydrogen Management
References
12 Fischer-Tropsch Process
12.1 Introduction
12.2 History and Development of the Process
12.3 Synthesis Gas
12.4 Production of Synthesis Gas
12.5 Process Parameters
12.6 Reactors and Catalysts
12.7 Products and Product Quality
12.8 Fischer-Tropsch Chemistry
References
13 Fuels and Chemicals Production
13.1 Introduction
13.2 Historical Aspects and Overview
13.3 The Petrochemical Industry
13.4 Petrochemicals
13.5 The Future
References
14 Gasification – A Process for Now and the Future
14.1 Introduction
14.2 Applications and Products
14.3 Environmental Benefits
14.4 Gasification – The Future
14.5 Market Development
14.6 Outlook
References
Conversion Factors
Glossary
About the Author
Index
Also of Interest
End User License Agreement
List of Tables
Chapter 2
Table 2.1 Brief descriptions of the various types of coal.
Table 2.2 Simplified differentiation between conventional crude oil, tight oi...
Chapter 3
Table 3.1 Categories of gasification processes (Braunstein
et al.
, 1977).
Table 3.2 Summary of the characteristics of the various types of gasifier.
Table 3.3 Coal gasification reactions.
Table 3.4 Comparison of products from combustion and gasification processes.
Table 3.5 Gasification products.
Chapter 4
Table 4.1 Comparison of the products of combustion and gasification.
Table 4.2 Gasification reactions.
Table 4.3 Effects of temperature of the product distribution.
Table 4.4 Gasification products.
Chapter 5
Table 5.1 Products from synthesis gas.
Table 5.2 The four main types (ranks) of coal*.
Table 5.3 Coal gasification reactions.
Table 5.4 Coal gasification products.
Table 5.5 Products (% w/w) from coal carbonization.
Chapter 6
Table 6.1 Types of refinery feedstocks available for gasification on-site.
Table 6.2 Options for resid processing in a refinery.
Table 6.3 The gasification process flow for crude oil coke.
Table 6.4 Illustration of the production of petrochemical starting materials ...
Chapter 7
Table 7.1 Gasification products.
Table 7.2 Advantages and disadvantages of using biomass as a gasification fee...
Table 7.3 Reactions that occur during gasification of a carbonaceous feedstoc...
Table 7.4 Acidic and alkaline methods for biomass treatment.
Table 7.5 Summation of the methods for the pretreatment of biomass feedstocks...
Table 7.6 Characteristics of the different types of gasifiers.
Table 7.7 Biomass properties that influence the gasification process.
Table 7.8 Predominant reactions occurring during biomass gasification.
Chapter 8
Table 8.1 General composition of municipal solid waste.
Table 8.2 Sources and types of waste.
Table 8.3 General classification of tars.
Chapter 9
Table 9.1 Common methods for the removal of carbon dioxide and hydrogen sulfi...
Chapter 10
Table 10.1 Options for resid processing in a refinery.
Table 10.2 Range of products from the Fischer-Tropsch process.
Table 10.3 Benefits of Fischer-Tropsch synthetic fuels.
Chapter 11
Table 11.1 Summary of typical hydrogen application and production process in ...
Table 11.2 Hydroprocessing parameters.
Chapter 12
Table 12.1 Reactions that occur during gasification of a carbonaceous feedsto...
Table 12.2 History and evolution of the Fischer-tropsch process.
Table 12.3 Reactions that occur during the Fischer-Tropsch synthesis.
Table 12.4 Carbon chain groups of the range of Fischer-Tropsch products which...
Chapter 13
Table 13.1 The various distillation fractions of crude oil.
Table 13.2 Properties of hydrocarbon products from crude oil (excluding liqui...
Table 13.3 Illustration of the production of petrochemical starting materials...
Table 13.4 Examples of products from the petrochemical industry.
Table 13.5 Naphtha production.
Table 13.6 Range of products from the Fischer-Tropsch process.
Table 13.7 Benefits of Fischer-Tropsch synthetic fuels.
Table 13.8 Alternative feedstocks for the production of petrochemicals.
List of Illustrations
Chapter 1
Figure 1.1 Types of energy resources.
Chapter 2
Figure 2.1 Potential products from the synthesis gas.
Chapter 3
Figure 3.1 The principal types of gasifiers. (a) Moving-bed (dry-ash) gasifi...
Chapter 6
Figure 6.1 The gasification process can accommodate a variety of carbonaceou...
Figure 6.2 The distillation section of a refinery.
Figure 6.3 Flexicoking process.
Figure 6.4 Relative distribution of heteroatoms in the various fractions of ...
Chapter 7
Figure 7.1 The gasification process can accommodate a variety of carbonaceou...
Figure 7.2 Potential products from heavy feedstock gasification.
Chapter 10
Figure 10.1 The gasification process can accommodate a variety of feedstocks...
Figure 10.2 Potential products from the synthesis gas.
Chapter 11
Figure 11.1 Example of the relative placement of hydroprocesses in a refiner...
Chapter 12
Figure 12.1 Routes to chemicals from synthesis gas and methanol.
Chapter 13
Figure 13.1 Schematic of a refinery showing the production of products durin...
Figure 13.2 Potential products from synthesis gas produced from gasification...
Figure 13.3 Representation of the various isomers of butylene (C
4
H
8
).
Guide
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Scrivener Publishing100 Cummings Center, Suite 541JBeverly, MA 01915-6106
Publishers at ScrivenerMartin Scrivener ([email protected])Phillip Carmical ([email protected])
Handbook of Gasification Technology
Science, Processes, and Applications
James G. Speight
This edition first published 2020 by John Wiley & Sons, Inc., 111 River Street, Hoboken, NJ 07030, USA and Scrivener Publishing LLC, 100 Cummings Center, Suite 541J, Beverly, MA 01915, USA© 2020 Scrivener Publishing LLC
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Library of Congress Cataloging-in-Publication Data
ISBN 9781118773536
Cover images: Background Texture - Dave Bredeson, Fuel Transport Image - Fastof | Dreamstime.comCover design by Kris Hackerott
Preface
Gasification of carbonaceous materials has been reliably used for decades as an alternative to combustion of solid or liquid fuels on a commercial scale to produce heat, industrial chemicals, fertilizers, in the refining industry, and in the electric power industry. Furthermore, it is easier to clean gaseous mixtures than it is to clean solid fuels or high-viscosity liquid fuels. Clean gas can be used in internal combustion-based power plant that would suffer from severe fouling or corrosion if solid or low quality liquid fuels were burned instead.
Gasification is a time-tested, reliable, and flexible technology that converts carbon-containing materials, including waste and biomass, into electricity and other valuable products, such as chemicals, fuels, substitute natural gas, and fertilizers. Gasification does not involve combustion (burning), but instead uses little or no oxygen or air in a closed reactor to convert carbon-based materials directly into a synthetic gas, or syngas. It is this intermediate product, synthesis gas (syngas), that makes gasification so unique and different from combustion. The gasification process breaks these materials down to the molecular level, so impurities like nitrogen, sulfur, and mercury can be easily removed and sold as valuable industrial commodities. Gasification can also recover the energy locked in biomass and municipal solid waste, converting those materials into valuable products and eliminating the need for incineration or landfilling. Biomass can also be blended with coal as a feedstock for electricity generation to lower its carbon footprint.
The chemistry of the gasification process is based on the thermal decomposition of the feedstock and the reaction of the feedstock carbon and other pyrolysis products with oxygen, water, and fuel gases such as methane and is represented by a sequence of simple chemical reactions. However, the gasification process is often considered to involve two distinct chemical stages: (i) devolatilization of the feedstock to produce volatile matter and char, (ii) followed by char gasification, which is complex and specific to the conditions of the reaction – both processes contribute to the complex kinetics of the gasification process.
The book also presents the elements of the Fischer-Tropsch process, which is a catalytic chemical reaction in which carbon monoxide (CO) and hydrogen (H2) in the synthesis are converted into hydrocarbon derivatives of various molecular weights. The process is a tried-and-true process that has been commercially demonstrated internationally The process for more than 75 years using synthesis gas. As an abundant resource in many non-oil producing countries, coal has long been exploited as a solid fossil fuel. As oil and natural gas supplanted coal throughout the last two centuries, technologies developed to convert coal into other fuels. Proponents of expanding the use of the Fischer-Tropsch process argue that the United States and many other countries could alleviate its dependence on imported petroleum and strained refinery capacity by converting non-petroleum feedstocks to transportation fuels.
This book deals with (i) gasification chemistry, thermodynamics, (ii) gasification feedstocks – such as coal, petroleum resids, biomass, waste, and other feedstocks, (iii) gasification processes and the suitability of different feedstocks, (iv) underground coal gasification, (v) gas cleaning, (vi) synthesis gas and hydrogen production, (vii) the Fischer-Tropsch process leading to the production of fuels and chemicals, and (viii) the potential for gasification in the future.
Furthermore, it is the purpose of this book to promote a better understanding of the role that gasification can play in providing the power, chemical and refining industries with economically competitive and environmentally conscious technology options to produce electricity, fuels, and chemicals while adhering to environmental regulations.
Dr. James G. Speight,Laramie, WyomingDecember 2019
Part 1SYNTHESIS GAS PRODUCTION
1Energy Sources and Energy Supply
1.1 Introduction
The Earth contains a finite supply of fossil fuels – the major fossil fuels are natural gas, crude oil, and coal – although there are debates related to the actual amounts of these fossil fuels remaining and the time left for use of these fuels (Speight, 2011c; Speight and Islam, 2016). In fact, at the present time, the majority of the energy consumed worldwide is produced from the fossil fuels (crude oil: approximately 38 to 40%, coal: approximately 31 to 35%, natural gas: approximately 20 to 25%) with the remainder of the energy requirements to come from nuclear sources and from hydroelectric sources. As a result, fossil fuels (in varying amounts depending upon the source of information) are projected to be the major sources of energy for the next fifty years (Crane et al., 2010; World Energy Council, 2008; Gudmestad et al., 2010; Speight, 2011a, 2011b, Khoshnaw, 2013; BP, 2014; Speight, 2014a; BP, 2019).
The current estimates for the longevity of each fossil fuel is estimated from the reserves/ production ratio (BP, 2019) which gives an indication (in years) of how long each fossil fuel will last at the current rates of production. The estimates vary from at least fifty years of crude oil at current rates of consumption with natural gas varying upwards of 100 years. On the other hand, coal remains in adequate supply and at current rates of recovery and consumption, the world global coal reserves have been variously estimated to have a reserves/ production ratio of at least 155 years. However, as with all estimates of resource longevity, coal longevity is subject to the assumed rate of consumption remaining at the current rate of consumption and, moreover, to technological developments that dictate the rate at which the coal can be mined. But most importantly, coal is a fossil fuel and an unclean energy source that will only add to global warming. In fact, the next time electricity is advertised as a clean energy source just consider the means by which the majority of electricity is produced – almost 50% of the electricity generated in the United States derives from coal (EIA, 2007; Speight, 2013).
In addition, the amounts of natural gas and crude oil located in tight sandstone formations and in shale formations has added a recent but exciting twist to the amount of these fossil fuels remaining. Peak energy theory proponents are inclined to discount the tight formations and shale formation as a mere aberration (or a hiccup) in the depletion of these resources while opponents of the peak energy theory take the opposite view and consider tight formations and shale formations as prolonging the longevity of natural gas and crude oil by a substantial time period (Speight and Islam, 2016). In addition, some areas of the Earth are still relatively unexplored or have been poorly analyzed and (using crude oil as the example) knowledge of in-ground resources increases dramatically as an oil reservoir is exploited.
Energy sources have been used since the beginning of recorded history and the fossil fuel resources will continue to be recognized as major sources of energy for at least the foreseeable future (Crane et al., 2010; World Energy Council, 2008; Gudmestad et al., 2010; Speight, 2011a, 2011b, Khoshnaw, 2013; Speight, 2014a; BP, 2019). Fossil fuels are those fuels, namely natural gas, crude oil (including heavy crude oil), extra heavy crude oil, tar sand bitumen, coal, and oil shale produced by the decay of plant remains over geological time represent an unrealized potential, with liquid fuels from crude oil being only a fraction of those that could ultimately be produced from heavy oil and tar sand bitumen (Speight, 1990, 1997, 2011a; 2013d, 2013e, 2014a).
Fuels from fossil fuels (especially the crude oil-based fuels) are well-established products that have served industry and domestic consumers for more than one hundred years and for the foreseeable future various fuels will still be largely based on hydrocarbon fuels derived from crude oil. Although the theory of peak oil is questionable (Speight and Islam, 2016), there is no doubt that crude oil, once considered inexhaustible, is being depleted at a measurable rate. The supposition by peak oil proponents is that supplies of crude oil are approaching a precipice in which fuels that are currently available may, within a foreseeable short time frame, be no longer available. While such a scenario is considered to be unlikely, the need to consider alternate technologies to produce liquid fuels that could mitigate the forthcoming effects of the shortage of transportation fuels is necessary and cannot be ignored.
Alternate fuels produced from source other than crude oil are making some headway into the fuel demand. For example, diesel from plant sources (biodiesel) is similar in performance to diesel from crude oil and has the added advantage of a higher cetane rating than crude oil-derived diesel. However, the production of liquid fuels from sources other than crude oil has a checkered history. The on-again-off-again efforts that are the result of the inability of the political decision-makers to formulate meaningful policies has caused the production of non-conventional fuels to move slowly, if at all (Yergin, 1991; Bower, 2009; Wihbey, 2009; Speight, 2011a, 2011b, Yergin, 2011; Speight, 2014a).
In the near term, the ability of conventional fuel sources and technologies to support the global demand for energy will depend on how efficiently the energy sector can match available energy resources (Figure 1.1) with the end user and how efficiently and cost effectively the energy can be delivered. These factors are directly related to the continuing evolution of a truly global energy market. In the long term, a sustainable energy future cannot be created by treating energy as an independent topic (Zatzman, 2012). Rather, the role of the energy and the inter-relationship of the energy market with other markets and the various aspects of market infrastructure demand further attention and consideration. Greater energy efficiency will depend on the developing the ability of the world market to integrate energy resources within a common structure (Gudmestad et al., 2010; Speight, 2011b; Khoshnaw, 2013).
As the 21st Century matures, there will continue to be an increased demand for energy to support the needs of commerce industry and residential uses – in fact, as the 2040 to 2049 decade approaches, commercial and residential energy demand is expected to rise by considerably – by approximately 30 percent over current energy demand. This increase is due, in part, to developing countries, where national economies are expanding and the move away from rural living to city living is increasing. In addition, the fuel of the rural population (biomass) is giving way to the fuel of the cities (transportation fuels, electric power) as the life-styles of the populations of developing countries changed from agrarian to metropolitan. Furthermore, the increased population of the cities requires more effective public transportation systems as the rising middle class seeks private means of transportation (automobiles). As a result, fossil fuels will continue to be the predominant source of energy for at least the next fifty years.
Figure 1.1 Types of energy resources.
However, there are several variables that can impact energy demand from fossil fuels. For example, coal (as a source of electrical energy) faces significant challenges from governmental policies to reduce greenhouse gas emissions and fuels from crude oil can also face similar legislation (Speight, 2013a, 2013b, 2014a) in addition to the types of application and use, location and regional resources, cost of energy, cleanness and environmental factors, safety of generation and utilization, socioeconomic factors, as well as global and regional politics (Speight, 2011a). More particularly, the recovery of natural gas and crude oil from tight sandstone and shale formations face challenges related to hydraulic fracturing.
Briefly, hydraulic fracturing is an extractive method used by crude oil and natural gas companies to open pathways in tight (low-permeability) geologic formations so that the oil or gas trapped within can be recovered at a higher flow rate (Speight, 2015a). When used in combination with horizontal drilling, hydraulic fracturing has allowed industry to access natural gas reserves previously considered uneconomical, particularly in shale formations. Although, hydraulic fracturing creates access to more natural gas supplies, but the process requires the use of large quantities of water and fracturing fluids, which are injected underground at high volumes and pressure. Oil and gas service companies design fracturing fluids to create fractures and transport sand or other granular substances to prop open the fractures. The composition of these fluids varies by formation, ranging from a simple mixture of water and sand to more complex mixtures with a multitude of chemical additives. Hydraulic fracturing has opened access to vast domestic reserves of natural gas that could provide an important stepping stone to a clean energy future. Yet questions related to the safety of hydraulic fracturing persist and the technology has been the subject of both enthusiasm and increasing environmental and health concerns in recent years, especially in relation to the possibility (some would say reality) of contaminated drinking water because of the chemicals used in the process and the disturbance of the geological formations (Speight, 2015a).
It is the purpose of this chapter to present to the reader an overview of the current energy sources and, hence, the need for other sources of fuels and chemicals. Therefore, a brief comment related to each of the potential energy sources is presented below. In addition, the potential for the gasification of carbonaceous feedstocks is also presented as an option for the production of fuels and chemicals (Speight, 2019a).
1.2 Typical Energy Sources
The widespread use of fossil fuels has been one of the most important stimuli of economic growth and has allowed the consumption of energy at a greater rate than it is being replaced and presents an unprecedented risk management problem (Yergin, 1991; Hirsch, 2005; Hirsch et al., 2005; Yergin, 2011). A peak in the production of crude oil will happen, but whether it will occur slowly or abruptly is not certain – given appropriate warnings, the latter is likely to be the case. The adoption of alternate technologies to supplant the deficit in the production of crude oil will require a substantial time period on the order of at least ten-to-twenty years.
Global energy consumption is increasing and is expected to rise by 41% over the period to 2035 – compared to a 52% rise over the last twenty years and 30% rise over the last decade. Ninety five per cent of the growth in demand is expected to come from the emerging economies, while energy use in the advanced economies of North America, Europe and Asia as a group is expected to grow only very slowly – and begin to decline in the later years of the forecast period (BP, 2019). The data for reserve estimates indicate that there are sufficient reserves to cover this trend at least to and even beyond the year 2035.
1.2.1 Natural Gas and Natural Gas Hydrates
It is rare that crude oil and also heavy crude oil do not occur without an accompanying cover of gas (Speight, 2014a, 2019b). It is therefore important, when describing reserves of crude oil, to also acknowledge the occurrence, properties, and character of the natural gas. In recent years, natural gas has gained popularity among a variety of industrial sectors. Natural gas burns cleaner than coal or crude oil, thus providing environmental benefits. Natural gas is distributed mainly via pipeline, and some in a liquid phase (LNG) transported across oceans by tanker.
Assuming that the current level of natural gas consumption for the world is maintained, the reserve would be enough to last for another 64 more years. However, in this estimation of natural gas longevity, factors such as the increased in annual consumption, the discovery of new reservoirs, and advances in discovery/recovery technology, and utilization of natural gas hydrates are not included. As a result of discoveries of gas in in tight shale formations – which has offset more than the annual consumption – the world reserves of natural gas have been in a generally upward trend, due to discoveries of major natural gas fields.
Natural gas liquids (NGLs) – which are the higher boiling constituents of natural gas separated from natural gas at a gas processing plant, and includes ethane, propane, butane, and pentanes – have taken on a new prominence as shale gas production has increased and prices have fallen (Ratner and Tiemann, 2014). As a result, most producers are accepting the challenges with the opportunism and have shifted production to tight formations, such as the Bakken formation in North Dakota and Montana, to capitalize on the occurrence of natural gas liquids in shale gas development (Speight, 2013f; Sandrea, 2014; Speight, 2015a).
Methane hydrates (also often referred to as methane clathrates) is a resource in which a large amount of methane is trapped within a crystal structure of water, forming a solid similar to ice (Collett, 2009; Speight, 2014, 2019b). Methane hydrates exist as methane (the chief constituent of natural gas) trapped in a cage-like lattice of ice which, if either warmed or depressurized (with suitable caution), revert back to water and natural gas. When brought to the surface of the Earth, one cubic meter of gas hydrate releases 164 cubic meters of natural gas.
Gas hydrates occur in two discrete geological situations: (i) marine shelf sediments and (ii) on-shore Polar Regions beneath permafrost (Kvenvolden 1993; Kvenvolden and Lorenson, 2000). These two Hydrates occur in these two types of settings because these are the settings where the pressure-temperature conditions are within the hydrate stability field (Lerche and Bagirov, 1998). Gas hydrates can be detected seismically as well as by well logs (Goldberg and Saito, 1998; Hornbach et al., 2003).
When drilling in crude oil-bearing and gas-bearing formations submerged in deep water, the reservoir gas may flow into the well bore and form gas hydrates owing to the low temperatures and high pressures found during deep water drilling. The gas hydrates may then flow upward with drilling mud or other discharged fluids. When the hydrates rise, the pressure in the annulus decreases and the hydrates dissociate into gas and water. The rapid gas expansion ejects fluid from the well, reducing the pressure further, which leads to more hydrate dissociation and further fluid ejection.
1.2.2 The Crude Oil Family
Crude oil and the equivalent term petroleum, cover a wide assortment of materials consisting of mixtures of hydrocarbon derivatives and other compounds containing variable amounts of sulfur, nitrogen, and oxygen, which may vary widely in volatility, specific gravity, and viscosity. Metal-containing constituents, notably those compounds that contain vanadium and nickel, usually occur in the more viscous crude oils in amounts up to several thousand parts per million and can have serious consequences during processing of these feedstocks. Because crude oil is a mixture of widely varying constituents and proportions, its physical properties also vary widely and the color from colorless to black. The crude oil family consists of various types of crude oil: (i) conventional crude oil, (ii) crude oil from tight formations, (iii) opportunity crude oils, (iv) high acid crude oil, (v) foamy oil, and (vi) heavy crude oil.
The total amount of crude oil is indeed is finite, and, therefore, production will one day reach a peak and then begin to decline. This is common sense, as explained in the resource depletion theory which, in this case, assumes that reserves of crude oil will not be replenished (i.e. that abiogenic replenishment is negligible) and future world oil production must inevitably reach a peak and then decline as these reserves are exhausted (Hubbert, 1956, 1962). There is no doubt that crude oil and natural gas are being consumed at a steady rate but whether or not the Hubbert peak oil theory will affect the consumption of crude oil is another issue. It is a theory that is based on reserve estimates and reserve consumption. No one will disagree that hydrocarbon resources (in the form of crude oil and natural gas) are finite resources and will run out at some future point in time but the proponents of an energy precipice must recognize that this will not be the case, at least not for now (Speight and Islam, 2016). The issue is the timing of this event – whether it is tomorrow, next week, next month, next year, or in 50 or more years remains to be seen. Current evidence (Speight, 2011a, 2011c; BP, 2019) favors a 50+ years lifetime for the current reserves of crude oil and natural gas, perhaps longer if hydraulic fracturing continues to play a dominant role in crude oil and natural gas production (Speight, 2015a). Thus, controversy surrounds the theory – not so much from the theory itself which is quite realistic but from the way in which the theory is used by varying collections of alarmists – since as predictions for the time of the global peak is dependent on the past production and discovery data used in the calculation.
To date, crude oil production on a worldwide basis has come almost exclusively from what are considered to be conventional crude oil reservoirs from which crude oil can be produced using tried-and-true recovery technologies compared with non-conventional sources that require more complex or more expensive technologies to extract – example of such resources are tar sand bitumen, liquids from coal, liquids from biomass, and liquids from oil shale (Lee, 1990; Scouten, 1990; Lee, 1991; Speight, 2008, 2011b, 2012, 2013a, 2014b, 2016).
Generally, crude oil from tight formations (sometime referred to as unconventional tight oil resources) are found at considerable depths in sedimentary rock formations that are characterized by very low permeability. While some of the tight oil plays produce oil directly from shales, tight oil resources are also produced from low-permeability siltstone formations, sandstone formations, and carbonate formations that occur in close association with a shale source rock.
Oil from tight shale formation is characterized by a low content of high-boiling (resid) constituents, low-sulfur content, and a significant molecular weight distribution of the paraffinic wax content (Speight, 2014a, 2015b). Finally, the properties of crude oils from tight formations are highly variable. Density and other properties can show wide variation, even within the same field. The Bakken crude is light and sweet with an API of 42° and a sulfur content of 0.19% w/w. Similarly, Eagle Ford is a light sweet feed, with a sulfur content of approximately 0.1% w/w and with published API gravity between 40° API and 62° API.
There is also the need for a refinery to be configured to accommodate opportunity crude oils and/or high acid crude oils which, for many purposes are often included with heavy feedstocks (Speight, 2014a, 2014b; Yeung, 2014). Opportunity crude oils are either new crude oils with unknown or poorly understood properties relating to processing issues or are existing crude oils with well-known properties and processing concerns (Ohmes, 2014). Opportunity crude oils are often, but not always, heavy crude oils but in either case are more difficult to process due to high levels of solids (and other contaminants) produced with the oil, high levels of acidity, and high viscosity. These crude oils may also be incompatible with other oils in the refinery feedstock blend and cause excessive equipment fouling when processed either in a blend or separately (Speight, 2015b). There is also the need for a refinery to be configured to accommodate opportunity crude oils and/or high acid crude oils which, for many purposes are often included with heavy feedstocks.
Opportunity crude oils, while offering initial pricing advantages, may have composition problems which can cause severe problems at the refinery, harming infrastructure, yield, and profitability. Before refining, there is the need for comprehensive evaluations of opportunity crudes, giving the potential buyer and seller the needed data to make informed decisions regarding fair pricing and the suitability of a particular opportunity crude oil for a refinery. This will assist the refiner to manage the ever-changing crude oil quality input to a refinery – including quality and quantity requirements and situations, crude oil variations, contractual specifications, and risks associated with such opportunity crudes.
High acid crude oils are crude oils that contain considerable proportions of naphthenic acids which, as commonly used in the crude oil industry, refers collectively to all of the organic acids present in the crude oil (Shalaby, 2005; Speight, 2014b). In many instances, the high-acid crude oils are actually the heavier crude oils (Speight, 2014a, 2014b). The total acid matrix is therefore complex and it is unlikely that a simple titration, such as the traditional methods for measurement of the total acid number, can give meaningful results to use in predictions of problems. An alternative way of defining the relative organic acid fraction of crude oils is therefore a real need in the oil industry, both upstream and downstream.
High acid crude oils cause corrosion in the refinery – corrosion is predominant at temperatures in excess of 180°C (355°F) (Kane and Cayard, 2002; Ghoshal and Sainik, 2013; Speight, 2014c) – and occurs particularly in the atmospheric distillation unit (the first point of entry of the high-acid crude oil) and also in the vacuum distillation units. In addition, overhead corrosion is caused by the mineral salts, magnesium, calcium and sodium chloride which are hydrolyzed to produce volatile hydrochloric acid, causing a highly corrosive condition in the overhead exchangers. Therefore, these salts present a significant contamination in opportunity crude oils. Other contaminants in opportunity crude oils which are shown to accelerate the hydrolysis reactions are inorganic clay minerals and organic acids.
Foamy oil is oil-continuous foam that contains dispersed gas bubbles produced at the well head from heavy crude oil reservoirs under solution gas drive (Maini, 1999; Sheng et al., 1999; Maini, 2001). The nature of the gas dispersions in oil distinguishes foamy oil behavior from conventional heavy crude oil. The gas that comes out of solution in the reservoir does not coalesce into large gas bubbles nor into a continuous flowing gas phase. Instead it remains as small bubbles entrained in the crude oil, keeping the effective oil viscosity low while providing expansive energy that helps drive the oil toward the producing. Foamy oil accounts for unusually high production in heavy crude oil reservoirs under solution-gas drive.
During primary production of heavy crude oil from solution gas drive reservoirs, the oil is pushed into the production wells by energy supplied by the dissolved gas. As fluid is withdrawn from the production wells, the pressure in the reservoir declines and the gas that was dissolved in the oil at high pressure starts to come out of solution (foamy oil). As pressure declines further with continued removal of fluids from the production wells, more gas is released from solution and the gas already released expands in volume. The expanding gas, which at this point is in the form of isolated bubbles, pushes the oil out of the pores and provides energy for the flow of oil into the production well. This process is very efficient until the isolated gas bubbles link up and the gas itself starts flowing into the production well. Once the gas flow starts, the oil has to compete with the gas for available flow energy. Thus, in some heavy crude oil reservoirs, due to the properties of the oil and the sand and also due to the production methods, the released gas forms foam with the oil and remains subdivided in the form of dispersed bubbles much longer.
Heavy crude oil is a type of crude oil that is different from conventional crude oil insofar as they are much more difficult to recover from the subsurface reservoir. Heavy crude oil, particularly heavy crude oil formed by biodegradation of organic deposits, are found in shallow reservoirs, formed by unconsolidated sands. This characteristic, which causes difficulties during well drilling and completion operations, may become a production advantage due to higher permeability. In simple terms, heavy crude oil is a type of crude oil which is very viscous and does not flow easily. The common characteristic properties (relative to conventional crude oil) are high specific gravity, low hydrogen to carbon ratios, high carbon residues, and high contents of asphaltenes, heavy metal, sulfur and nitrogen. Specialized refining processes are required to produce more useful fractions, such as: naphtha, kerosene, and gas oil.
1.2.3 Extra Heavy Crude Oil and Tar Sand Bitumen
In addition to conventional crude oil and heavy crude oil, there remains two other, even more viscous materials, that offers some relief to the potential shortfalls in supply (Meyer and De Witt, 1990; Meyer and Attanasi, 2003; Speight, 2014a; BP, 2019). This is the bitumen known as extra heavy crude oil and the bitumen found in tar sand (oil sand) deposits (Speight, 2014a). However, many of these reserves are only available with some difficulty and optional refinery scenarios will be necessary for conversion of these materials to liquid products because of the differences in character between conventional crude oil and tar sand bitumen (Speight, 2000; Speight, 2014a).
Extra heavy crude oil is a non-descript term (related to viscosity) of little scientific meaning that is usually applied to tar sand bitumen, which is generally capable of free flow under reservoir conditions (Speight, 2014a, 2017). Thus, general difference is that extra heavy crude oil, which may have properties similar to tar sand bitumen in the laboratory but, unlike tar sand bitumen in the deposit, has some degree of mobility in the reservoir or deposit (Delbianco and Montanari, 2009; Speight, 2014a, 2017). Extra heavy crude oils can flow at reservoir temperature and can be produced economically, without additional viscosity-reduction techniques, through variants of conventional processes such as long horizontal wells, or multilaterals. This is the case, for instance, in the Orinoco basin (Venezuela) or in offshore reservoirs of the coast of Brazil but, once outside of the influence of the high reservoir temperature, these oils are too viscous at surface to be transported through conventional pipelines and require heated pipelines for transportation. Alternatively, the oil must be partially upgraded or fully upgraded or diluted with a light hydrocarbon (such as aromatic naphtha) to create a mix that is suitable for transportation (Parkash, 2003; Gary et al., 2007; Speight, 2014a; Hsu and Robinson, 2017; Speight, 2017).
Tar sand (referred to as oil sand in Canada) deposits are found in various countries throughout the world, but in vast quantities in Alberta and Venezuela. There have been many attempts to define tar sand deposits and the bitumen contained therein. In order to define conventional crude oil, heavy crude oil, and bitumen, the use of a single physical parameter such as viscosity is not sufficient. Other properties such as API gravity, elemental analysis, composition, and, most of all, the properties of the bulk deposit must also be included in any definition of these materials. Only then will it be possible to classify crude oil and its derivatives.
In fact, the most appropriate and workable definition of tar sand is found in the writings of the United States government (United States Congress, 1976), which is not subject to any variation in chemical or physical properties that can vary depending upon the method of property determination and the accuracy of that method (Speight, 2014, 2016), viz.:
Tar sands are the several rock types that contain an extremely viscous hydrocarbon which is not recoverable in its natural state by conventional oil well production methods including currently used enhanced recovery techniques. The hydrocarbon-bearing rocks are variously known as bitumen-rocks oil, impregnated rocks, oil sands, and rock asphalt.
This definition speaks to the character of the bitumen through the method of recovery (Speight, 2014, 2016). Thus, the bitumen found in tar sand deposits is an extremely viscous material that is immobile under reservoir conditions and cannot be recovered through a well by the application of secondary or enhanced recovery techniques.
By inference and by omission, conventional crude oil and heavy crude oil are also indicated in this definition – crude oil is the material that can be recovered by conventional oil well production methods whereas heavy crude oil is the material that can be recovered by enhanced recovery methods. Extra heavy oil can also be accommodated under this definition because the properties of extra heavy crude oil approximates the properties and behavior of tar sand bitumen at ambient conditions but is mobile because the reservoir temperature is higher than the pour point of the oil (Speight, 2014a). In the early days of resource development, the sole method of the recovery of the bitumen from tar sand formations was by use of a mining process followed by separation of the bitumen by the hot water process. Current methods also include the use of advanced in situ processes that are not covered by the above definition. After recovery, the bitumen is then used to produce hydrocarbon derivatives by a conversion process.
1.3 Other Energy Sources
All fossil fuels are non-renewable, and as such they will get eventually depleted to the point where extraction of the remaining fossil fuels from the Earth is impossible or prohibitively expensive. Further, energy generation from fossil fuels require combustion, thus damaging the environment with pollutants and greenhouse gas emission (Speight and Lee, 2000). Also, since the fossil fuels are based on finite resources and their distributions are heavily localized in certain areas of the world, they will become expensive. In order to sustain the future of the world with clean environment and non-depletive energy, renewable energy is a right choice. Renewable energy sources include hydrgoen, biomass, solar energy, wind energy, and geothermal energy. Most renewable energy except geothermal energy comes directly or indirectly from sun. Benefits of renewable energy are variable and include: (i) environmental cleanness without pollutant emission, (ii) non-depletive nature, (iii) availability throughout the world, (iv) no cause for global warming, (v) waste reduction, (vi) stabilization of energy cost, and (vii) creation of jobs.
Alternate fuels produced from sources other than fossil fuels (particularly those from crude oil) are making some headway into the fuel demand. For example, diesel from plant sources (biodiesel) is similar in performance to diesel from crude oil and has the added advantage of a higher cetane rating than crude oil-derived diesel. However, the production of liquid fuels from sources other than crude oil has a checkered history. The on-again-off-again efforts that are the result of the inability of the political decision-makers to formulate meaningful policies has caused the production of non-conventional fuels to move slowly, if at all (Yergin, 1991; Bower, 2009; Wihbey, 2009; Speight, 2011a, 2011b, Yergin, 2011; Speight, 2014a).
Non-fossil fuels are alternative sources of energy that do not rely on continued consumption of the limited supplies of crude oil, coal, and natural gas. Examples of the non-fossil fuel energy sources include: (i) biomass, wind, solar, geothermal, tidal, nuclear, and hydrogen sources (Nersesian, 2007; Speight, 2008, 2011c). Such resources are considered to be extremely important to the future of energy generation because they are renewable energy sources that could be exploited continuously and not suffer depletion. In addition, energy production using non-fossil-based sources is claimed to generate much less pollution than the fossil fuel energy sources. This is considered crucial by many governments who are looking for ways to reduce the amount of pollution produced by their countries. The advantages of fossil fuel resources are often considered to include the know-how and ease of production, many opponents of fossil fuel use cite the adverse effects on the environment (Speight, 2008, 2013a, 2013b, 2014a) and consider non-fossil fuels as a much better way to generate energy.
While there are now methods of burning gas and similar products very efficiently, as clean fossil fuels, a certain amount of pollution is still generated. Accordingly, various initiatives now exist, especially in Western countries, to encourage corporations and energy companies to invest in methods of producing energy from renewable (non-fossil fuel).
1.3.1 Coal
Coal is a combustible organic sedimentary rock that is formed from the accumulation and preservation of plant materials, usually in a swamp environment (Speight, 2013a, 2013b). Along with crude oil and natural gas, coal is one of the three most important fossil fuels, such as for the generation of electricity and provides approximately 40% of electricity production on a worldwide basis. In many countries these data are much higher; for example Poland relies on coal for approximately 94% of the electricity production; South Africa relies on coal for approximately 92% of the electricity production; China relies on coal for approximately 77% of the electricity production; and Australia relies on coal for approximately 76% of the electricity production.
Total recoverable reserves of coal around the world are estimated at 891,531 million tons – the United States has sufficient coal reserves to last (at current rates of consumption) in excess of 250 years (BP, 2019). Even though coal deposits are distributed widely throughout the world, deposits in three countries account for approximately 57% of the world recoverable coal reserves, viz., United States (27%), Russian Federation (18%), and China (13%) and another six countries account for 30% of the total reserves and they are Australia (9%), India (7%), Ukraine (4%), Kazakhstan (4%), South Africa (3%), and Japan (3%). Coal is also very unequally and unevenly distributed in the world, just as other fossil fuels such as crude oil and natural gas.
Coal has been studied extensively for conversion into gaseous and liquid fuels as well as hydrocarbon feedstocks. Largely thanks to its relative abundance and stable fuel price on the market, coal has been a focal target for synthetic conversion into other forms of fuels, i.e., synfuels. Research and development work on coal conversion has seen peaks (highs) and valleys (lows) due to external factors including the comparative fossil fuel market as well as the international energy outlook of the era. Coal can be gasified, liquefied, pyrolyzed, and co-processed with other fuels including oil, biomass, scrap tires, and municipal solid wastes (Speight, 2008, 2011b, 2011c, 2013a, 2014b). Secondary conversion of coal derived gas and liquids can generate a wide array of petrochemical products as well as alternative fuels.
For the past two centuries, coal played this important role – providing coal gas for lighting and heating and then electricity generation with the accompanying importance of coal as an essential fuel for steel and cement production, as well as a variety of other industrial activities. On a worldwide basis, in excess of 4 billion tons (4.0 x 109 tons) of coal is consumed by a variety of sectors – including power generation (steam coal and/or lignite), iron and steel production (coking coal), cement manufacturing, and as a solid fuel or a source of liquid fuels (Speight, 2013a, 2103b). In fact, coal remains an important source of energy in many countries, and is used to provide approximately 40% of electricity worldwide but this does not give the true picture of the use of coal for electricity production. During the time the coal industry has been pressured into consideration of the environmental aspects of coal use and has responded with a variety of on-stream coal-cleaning and gas-cleaning technologies (Speight, 2013a).
Coal is the largest single source of fuel for the generation of electricity world-wide, as well as the largest source of carbon dioxide emissions, which have been implicated as the primary cause of global climate change, although the debate still rages as to the actual cause (or causes) of climate change. Coal is found as successive layers, or seams, sandwiched between strata of sandstone and shale and extracted from the ground by coal mining – either underground coal seams (underground mining) or by open-pit mining (surface mining).
Coal occurs in different forms or types (Speight, 2013a). Variations in the nature of the source material and local or regional the variations in the coalification processes cause the vegetal matter to evolve differently. Various classification systems thus exist to define the different types of coal. Using the ASTM system of classification (ASTM D388), the coal precursors are transformed over time (as geological processes increase their effect over time).
Chemically, coal is a hydrogen-deficient hydrocarbon with an atomic hydrogen-to-carbon ratio near 0.8, as compared to crude oil hydrocarbon derivatives, which have an atomic hydrogen-to-carbon ratio approximately equal to 2, and methane (CH4) that has an atomic carbon-to-hydrogen ratio equal to 4. For this reason, any process used to convert coal to alternative fuels must add hydrogen or redistribute the hydrogen in the original coal to generate hydrogen-rich products and coke (Speight, 2013a).
The chemical composition of the coal is defined in terms of its proximate and ultimate (elemental) analyses (Speight, 2013a). The parameters of proximate analysis are moisture, volatile matter, ash, and fixed carbon. Elemental analysis (ultimate analysis) encompasses the quantitative determination of carbon, hydrogen, nitrogen, sulfur, and oxygen within the coal. Additionally, specific physical and mechanical properties of coal and particular carbonization properties are also determined.
Carbon monoxide and hydrogen are produced by the gasification of coal in which a mixture of gases is produced. In addition to carbon monoxide and hydrogen, methane and other hydrocarbon derivatives are also produced depending on conditions. Producing diesel and other fuels from coal can be performed through the conversion of coal to synthesis gas, a combination of carbon monoxide, hydrogen, carbon dioxide, and methane. Synthesis gas is subsequently reacted through Fischer-Tropsch Synthesis processes to produce hydrocarbon derivatives that can be refined into liquid fuels (Speight, 2019a). Thus, gasification thus offers one of the cleanest and versatile ways to convert the energy contained in coal into electricity, hydrogen, and other sources of power. Turning coal into synthesis gas isn’t a new concept, in fact the basic technology dates back to pre-World War II. In fact, a gasification unit can process virtually all the residua and wastes that are produced in refineries leading to enhanced yields of high-value products (and hence their competitiveness in the market) by deeper upgrading of their crude oil.
1.3.2 Oil Shale
Just like the term oil sand (tar sand in the United States), the term oil shale is a misnomer since the mineral does not contain oil nor is it always shale. The organic material is chiefly kerogen and the shale is usually a relatively hard rock, called marl. Oil shale is a complex and intimate mixture of organic and inorganic materials that vary widely in composition and properties. In general terms, oil shale is a fine-grained sedimentary rock that is rich inorganic matter and yields oil when heated. Some oil shale is genuine shale but others have been mis-classified and are actually siltstones, impure limestone, or even impure coal. Oil shale does not contain oil and only produces oil when it is heated to approximately 500°C (approximately 930°F), when some of the organic material is transformed into a distillate similar to crude oil (Lee, 1990; Scouten, 1990; Lee, 1991; Speight, 2008, 2012).
Thus, when properly processed, kerogen can be converted into a substance somewhat similar to crude oil which is often better than the lowest grade of oil produced from conventional oil reservoirs but of lower quality than conventional light oil. Shale oil (retort oil) is the liquid oil condensed from the effluent in oil shale retorting and typically contains appreciable amounts of water and solids, as well as having an irrepressible tendency to form sediments. Oil shale is an inorganic, non-porous sedimentary marlstone rock containing various amounts of solid organic material (known as kerogen) that yields hydrocarbon derivatives, along with non-hydrocarbon derivatives, and a variety of solid products, when subjected to pyrolysis (a treatment that consists of heating the rock at high temperature) (Lee, 1990; Scouten, 1990; Lee, 1991; Speight, 2008, 2012).
Oil production potential from oil shale is measured by a laboratory pyrolysis method called Fischer Assay (Speight, 1994, 2008, 2012) and is reported in barrels per ton (42 US gallons per barrel, approximately 35 Imperial gallons per barrel). Rich oil shale zones can yield more than 40 US gallons per ton, while most shale zones produce 10 to 25 US gallons per ton. Yields of shale oil in excess of 25 US gallons per ton are generally viewed as the most economically attractive, and hence, the most favorable for initial development. Thus, oil shale has, though, a definite potential for meeting energy demand in an environmentally acceptable manner (Lee, 1990; Scouten, 1990; Lee, 1991; Bartis et al., 2005; Andrews, 2006; Speight, 2008; 2012).
The oil shale deposits in the western United States contain approximately 15% w/w organic material (kerogen) (Lee, 1990; Scouten, 1990; Lee, 1991; Speight, 2012). By heating oil shale to high temperatures (>500°C, >930°F), the kerogen is decomposed and converted to a volatile liquid product. However, shale oil is sufficiently different from crude oil and refining processing shale oil presents some unusual problems but, nevertheless, shale oil can be refined into a variety of liquid fuels, gases, and high value products for the petrochemical industry.
The United States has vast known oil shale resources that could translate into as much as 2.2 trillion barrels of known oil-in-place
