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The Chemistry and Technology of Petroleum
distillation, processing at mild conditions), (2) reactive adsorption (type of adsorbent used, process
design), and (3) oxidative desulfurization (catalyst, process design).
In addition, the most common approaches to upgrading hydrotreaters for clean-fuels production
will continue to be (1) developing higher-activity and more resilient catalysts, (2) replacing reactor
internals for increased efficiency, (3) adding reactor capacity to accommodate heavy feedstocks
and increase gasoline–diesel production, (4) increasing hydrogen partial pressure, and (5) process
design and hardware that are more specialized and focus on process schemes that effectively reduce
hydrogen consumption.
However, residuum hydrotreating requires considerably different catalysts and process flows,
depending on the specific operation so that efficient hydroconversion through uniform distribution
of liquid, hydrogen-rich gas, and catalyst across the reactor is assured. In addition to an increase in
guard bed use, the industry will see an increase in automated demetallization of fixed-bed systems
as well as more units that operate as ebullating-bed hydrocrackers.
For heavy oil upgrading, hydrotreating technology (Chapter 21) and hydrocracking technology
(Chapter 22) will be the processes of choice. For cleaner transportation fuel production, the main
task is the desulfurization of gasoline and diesel. With the advent of various techniques, such as
adsorption and biodesulfurization, the future development will be still centralized on hydrodesulfurization techniques.
Catalyst development (Chapters 19 and 22) will be key in the modification of processes and
the development of new ones to make environmentally acceptable fuels (Rostrup-Nielsen, 2004).
Conversion of crude oil is expected to remain the principal source of motor fuels for another
30–50 years, but it is likely that the production of fuel additives in large quantities along with
conversion of natural gas will become significant (Sousa-Aguiar et al., 2005). Although crude oil
conversion is expected to remain the principal source of fuels and petrochemicals in the future,
natural gas reserves are emerging, and will continue to emerge, as a major hydrocarbon resource.
This trend has already started to result in a shift toward use of natural gas (methane) as a significant
feedstock for chemicals and for fuels as well. As a result, deployment of technology for direct and
indirect conversion of methane will probably displace much of the current production of liquefied
natural gas.
The precise configuration of the refinery of the future is unknown, but it is certain that no two
refineries will to adapt in exactly the same way. However, the evolution of the refinery of the future
will not be strictly confined to petroleum processes. The major consequence will be a much more
environmentally friendly product quality. These will be solved in refinery of the future, the refinery
beyond 2020 with the development of deep conversion processing, such as residue hydrocracking
and the inclusion of processes to accommodate other feedstocks.
The typical U.S. refinery in the year 2030 will be located at an existing refinery site because economic and environmental considerations will make it difficult and uneconomical to build a new refinery at another site. Many existing refining process may still be in use but they will be more efficient
and more technologically advanced and perhaps even rebuilt (reactors having been replaced on a
scheduled or as needed basis) rather than retrofitted. However, energy efficiency will still be a primary
concern, as refiners seek to combat the inevitable increasing cost of crude oil and refinery operating
expenses.
Moreover, the future of the petroleum refining industry will be primarily on processes for the
production of improved quality products. In addition to heavy ends deep conversion, there will also
be changes in the feedstock into a refinery. Biomass, liquids from coal, and liquids from oil shale will
increase in importance. These feedstocks will be (1) sent to refineries or (2) processed at a remote
location and then blended with refinery feedstocks, which are options for future development but
the success of the blending operation is dependent upon the nature of the feedstocks. Above all, such
feedstock must be compatible with refinery feedstocks and not cause fouling in any form.
The refinery of the future will have a gasification section devoted to the conversion of coal and
biomass to Fischer–Tropsch hydrocarbons—perhaps even with rich oil shale added to the gasifier
The Chemistry and Technology of Petroleum
distillation, processing at mild conditions), (2) reactive adsorption (type of adsorbent used, process
design), and (3) oxidative desulfurization (catalyst, process design).
In addition, the most common approaches to upgrading hydrotreaters for clean-fuels production
will continue to be (1) developing higher-activity and more resilient catalysts, (2) replacing reactor
internals for increased efficiency, (3) adding reactor capacity to accommodate heavy feedstocks
and increase gasoline–diesel production, (4) increasing hydrogen partial pressure, and (5) process
design and hardware that are more specialized and focus on process schemes that effectively reduce
hydrogen consumption.
However, residuum hydrotreating requires considerably different catalysts and process flows,
depending on the specific operation so that efficient hydroconversion through uniform distribution
of liquid, hydrogen-rich gas, and catalyst across the reactor is assured. In addition to an increase in
guard bed use, the industry will see an increase in automated demetallization of fixed-bed systems
as well as more units that operate as ebullating-bed hydrocrackers.
For heavy oil upgrading, hydrotreating technology (Chapter 21) and hydrocracking technology
(Chapter 22) will be the processes of choice. For cleaner transportation fuel production, the main
task is the desulfurization of gasoline and diesel. With the advent of various techniques, such as
adsorption and biodesulfurization, the future development will be still centralized on hydrodesulfurization techniques.
Catalyst development (Chapters 19 and 22) will be key in the modification of processes and
the development of new ones to make environmentally acceptable fuels (Rostrup-Nielsen, 2004).
Conversion of crude oil is expected to remain the principal source of motor fuels for another
30–50 years, but it is likely that the production of fuel additives in large quantities along with
conversion of natural gas will become significant (Sousa-Aguiar et al., 2005). Although crude oil
conversion is expected to remain the principal source of fuels and petrochemicals in the future,
natural gas reserves are emerging, and will continue to emerge, as a major hydrocarbon resource.
This trend has already started to result in a shift toward use of natural gas (methane) as a significant
feedstock for chemicals and for fuels as well. As a result, deployment of technology for direct and
indirect conversion of methane will probably displace much of the current production of liquefied
natural gas.
The precise configuration of the refinery of the future is unknown, but it is certain that no two
refineries will to adapt in exactly the same way. However, the evolution of the refinery of the future
will not be strictly confined to petroleum processes. The major consequence will be a much more
environmentally friendly product quality. These will be solved in refinery of the future, the refinery
beyond 2020 with the development of deep conversion processing, such as residue hydrocracking
and the inclusion of processes to accommodate other feedstocks.
The typical U.S. refinery in the year 2030 will be located at an existing refinery site because economic and environmental considerations will make it difficult and uneconomical to build a new refinery at another site. Many existing refining process may still be in use but they will be more efficient
and more technologically advanced and perhaps even rebuilt (reactors having been replaced on a
scheduled or as needed basis) rather than retrofitted. However, energy efficiency will still be a primary
concern, as refiners seek to combat the inevitable increasing cost of crude oil and refinery operating
expenses.
Moreover, the future of the petroleum refining industry will be primarily on processes for the
production of improved quality products. In addition to heavy ends deep conversion, there will also
be changes in the feedstock into a refinery. Biomass, liquids from coal, and liquids from oil shale will
increase in importance. These feedstocks will be (1) sent to refineries or (2) processed at a remote
location and then blended with refinery feedstocks, which are options for future development but
the success of the blending operation is dependent upon the nature of the feedstocks. Above all, such
feedstock must be compatible with refinery feedstocks and not cause fouling in any form.
The refinery of the future will have a gasification section devoted to the conversion of coal and
biomass to Fischer–Tropsch hydrocarbons—perhaps even with rich oil shale added to the gasifier