Simultaneous production of hydrogen, carbon, and electricity with carbon dioxide recovery

Abstract

The hydrocarbon feed stream is exposed to heat in the absence of oxygen (pyrolyzed), and the hydrocarbon feed stream is converted into a solid stream and a gas stream. The solid stream contains carbon. The gas stream contains hydrogen. The gas stream is separated into an exhaust gas stream and a first hydrogen stream. The first hydrogen stream contains at least a portion of the hydrogen from the gas stream. Carbon is separated from the solid stream to produce a carbon stream. Electrolysis is performed on the water stream to produce an oxygen stream and a second hydrogen stream. At least a portion of the oxygen in the oxygen stream is combined with at least a portion of the carbon in the carbon stream to generate electric power and a carbon dioxide stream. At least a portion of the generated electric power is used to perform electrolysis of the water stream.

Description

Technical Field

[0001] Claim of Priority This application claims the priority of U.S. Patent Application No. 17 / 730,942, filed on April 27, 2022, the entire content of which is incorporated herein by reference.

[0002] This disclosure relates to the simultaneous production of hydrogen, carbon, and electricity.

Background Art

[0003] Carbon is an element that is abundantly present in the Earth's crust. Carbon functions as an element common to all known life due to its abundance, diversity in the formation of organic compounds, and ability to form polymers at temperatures commonly experienced on Earth. Carbon atoms bond in many ways to form various allotropes of carbon. Examples of carbon allotropes include graphite, diamond, amorphous carbon, carbon nanotubes, carbon fibers, and fullerenes. The physical properties of carbon vary greatly depending on the allotrope. Therefore, carbon is widely used across various markets on a commercial or near-commercial scale.

[0004] Hydrogen is the lightest element. Under standard conditions, hydrogen is a diatomic gas that is colorless, odorless, tasteless, non-toxic, and flammable. Hydrogen is the most abundant chemical substance in the universe. Most of the hydrogen on Earth exists in molecular form in water and organic compounds (such as hydrocarbons). Examples of hydrogen use include the treatment of fossil fuels (e.g., hydrocracking) and the production of ammonia.

[0005] As a global effort to reduce carbon dioxide emissions, there is an increasing interest in energy conversion from fossil fuels to renewable or sustainable energy. Examples of decarbonization pathways in energy conversion to renewable energy include improving energy efficiency, manufacturing and / or using low-carbon fuels, and carbon capture and storage (CCS).

SUMMARY OF THE INVENTION

[0006] The present disclosure describes a technique related to the simultaneous production of hydrogen, carbon, and electricity with isolated and prepared carbon dioxide. Specific aspects of the described subject matter can be implemented as a method. A hydrocarbon feed stream is subjected to heat (pyrolysis) in the absence of oxygen, and the hydrocarbon feed stream is converted into a solid stream and a gas stream. The hydrocarbon feed stream contains hydrocarbons. The solid stream contains carbon. The gas stream contains hydrogen. The gas stream is separated into an exhaust gas stream and a first hydrogen stream. The first hydrogen stream contains at least a portion of the hydrogen from the gas stream. Carbon is separated from the solid stream to produce a carbon stream. Electrolysis is performed on a water stream to produce an oxygen stream and a second hydrogen stream. The water stream contains water. The oxygen stream contains oxygen. The second hydrogen stream contains hydrogen. At least a portion of the oxygen in the oxygen stream and at least a portion of the carbon in the carbon stream are combined to generate electric power and a carbon dioxide stream. The carbon dioxide stream contains carbon dioxide. At least a portion of the generated electric power is used to perform electrolysis of the water stream.

[0007] This aspect and other aspects can include one or more of the following features. The hydrocarbon feed stream can include a plurality of hydrocarbons selected from C1-C22 alkanes. The hydrocarbon feed stream can include hydrogen. Oxygen and carbon can be combined by a direct carbon fuel cell (DCFC) including a solid oxide. Oxygen and carbon can be combined by a direct carbon fuel cell at an operating temperature in the range of about 800 °C to about 1000 °C. Heat can be transferred from the gas stream to a buffer fluid by a first waste heat recovery heat exchanger. Before exposing the hydrocarbon feed stream to heat in the absence of oxygen, heat can be transferred from the buffer fluid to the hydrocarbon feed stream by a second waste heat recovery heat exchanger. Electric power can be generated by a Rankine cycle using heat transferred from the gas stream to the buffer stream. Power generation by the Rankine cycle can include transferring heat from the buffer fluid to a working fluid in a boiler to vaporize the working fluid into a vaporized working fluid. Power generation by the Rankine cycle can include flowing the vaporized working fluid through a turbine to expand and generate power. Power generation by the Rankine cycle can include condensing the vaporized working fluid into a condensed working fluid. Power generation by the Rankine cycle can include circulating the condensed working fluid back to the boiler. Heat can be transferred from the carbon dioxide stream to the buffer fluid by a first waste heat recovery heat exchanger. Before exposing the hydrocarbon feed stream to heat in the absence of oxygen, heat can be transferred from the buffer fluid to the hydrocarbon feed stream by a second waste heat recovery heat exchanger. The carbon dioxide stream generated by the direct carbon fuel cell can be isolated within an underground formation and the carbon dioxide stream is not released into the atmosphere.

[0008] Certain aspects of the subject matter described can be implemented as a system. The system includes a hydrocarbon feed stream, a pyrolysis chamber, a gas separation unit, a carbon separation unit, a water stream, an electrolysis unit, and a power generation unit. The hydrocarbon feed stream includes hydrocarbons. The water stream includes water. The pyrolysis chamber is configured to receive the hydrocarbon feed stream and expose the hydrocarbon feed stream to heat in the absence of oxygen to convert the hydrocarbon feed stream into a solid stream and a gas stream. The solid stream includes carbon. The gas stream includes hydrogen. The gas separation unit is configured to receive the gas stream from the pyrolysis chamber and separate hydrogen from the gas stream to produce an exhaust gas stream and a first hydrogen stream. The first hydrogen stream includes at least a portion of the hydrogen from the gas stream. The carbon separation unit is configured to receive the solid stream from the pyrolysis chamber and separate carbon from the solid stream to produce a carbon stream. The carbon stream includes at least a portion of the carbon from the solid stream. The electrolysis unit is configured to receive the water stream and power. The electrolysis unit is configured to perform electrolysis of the water stream using the power to produce an oxygen stream and a second hydrogen stream. The oxygen stream includes oxygen. The second hydrogen stream includes hydrogen. The power generation unit is configured to receive at least a portion of the oxygen stream from the electrolysis unit and at least a portion of the carbon stream from the carbon separation unit. The power generation unit includes a direct carbon fuel cell configured to combine oxygen from a portion of the oxygen stream and carbon from a portion of the carbon stream to generate power and a carbon dioxide stream. The carbon dioxide stream includes carbon dioxide. At least a portion of the power generated by the power generation unit is supplied to the electrolysis unit to perform electrolysis of the water stream.

[0009] This aspect and other aspects can include one or more of the following features. The hydrocarbon feed stream can include a plurality of hydrocarbons selected from C1-C22 alkanes. The hydrocarbon feed stream can include hydrogen. The direct carbon type fuel cell can include a solid oxide electrolyte configured to operate at a temperature in the range of about 800°C to about 1000°C. The system can include a first waste heat recovery heat exchanger. The first waste heat recovery heat exchanger can be in fluid communication with a gas stream exiting the pyrolysis chamber. The first waste heat recovery heat exchanger can be in fluid communication with a buffer fluid. The first waste heat recovery heat exchanger can be configured to transfer heat from the gas stream to the buffer fluid. The system can include a second waste heat recovery heat exchanger. The second waste heat recovery heat exchanger can be in fluid communication with the hydrocarbon feed stream entering the pyrolysis chamber. The second waste heat recovery heat exchanger can be in fluid communication with a buffer fluid. The second waste heat recovery heat exchanger can be configured to transfer heat from the buffer fluid to the hydrocarbon feed stream before the hydrocarbon feed stream enters the pyrolysis chamber. The system can include a Rankine cycle configured to generate power using heat transferred from the gas stream to the buffer fluid. The Rankine cycle can include a boiler configured to receive a working fluid and the buffer fluid. The boiler can be configured to transfer heat from the buffer fluid to the working fluid to vaporize the working fluid into a vaporized working fluid. The Rankine cycle can include a turbine configured to receive the vaporized working fluid and generate power as the vaporized working fluid flows through and expands through the turbine. The Rankine cycle can include a condenser configured to receive and condense the vaporized working fluid into a condensed working fluid. The Rankine cycle can include a pump configured to circulate the condensed working fluid to the boiler. The system can include a first waste heat recovery heat exchanger. The first waste heat recovery heat exchanger can be in fluid communication with a carbon dioxide stream exiting the power generation unit. The first waste heat recovery heat exchanger can be in fluid communication with a buffer fluid. The first waste heat recovery heat exchanger can be configured to transfer heat from the carbon dioxide stream to the buffer fluid.The system can include a second waste heat recovery heat exchanger. The second waste heat recovery heat exchanger can be in fluid communication with a hydrocarbon feed stream entering the pyrolysis chamber. The second waste heat recovery heat exchanger can be in fluid communication with a buffer fluid. The second waste heat recovery heat exchanger can be configured to transfer heat from the buffer fluid to the hydrocarbon feed stream before the hydrocarbon feed stream enters the pyrolysis chamber. The pyrolysis chamber can include a catalyst. The catalyst can include at least one of activated carbon, carbon black, cobalt, iron, copper, nickel.

[0010] Details of one or more implementations of the subject matter of this disclosure are set forth in the accompanying drawings and the description herein. Other features, aspects, and advantages of the subject matter will become apparent from the description, the drawings, and the claims.

Brief Description of the Drawings

[0011]

Figure 1A

[0012]

Figure 1B

[0013]

Figure 1C

[0014]

Figure 1D

[0015]

Figure 1E

[0016]

Figure 1F

[0017]

Figure 1G

[0018]

Figure 1H

[0019]

Figure 2

[0020]

Figure 3

DETAILED DESCRIPTION OF THE INVENTION

[0021] The present disclosure describes a system for the simultaneous production of hydrogen, oxygen, carbon, carbon dioxide, and electricity. The two main sources to the system include a hydrocarbon stream and a water stream. Depending on the implementation, renewable power and / or power from the power grid is used as needed. The hydrocarbon stream is pyrolyzed to produce carbon and hydrogen. The water stream is split by electrolysis to produce oxygen and hydrogen. Electricity can be generated by (i) combusting carbon in the presence of oxygen (obtained from the electrolysis of the water stream) to generate heat and using that heat to produce steam for a steam turbine, (ii) combining carbon (obtained from the pyrolysis of the hydrocarbon stream) with oxygen (obtained from the electrolysis of the water stream) using a direct carbon fuel cell (DCFC), or both (i) and (ii). Depending on the implementation, waste heat recovery is carried out for process integration and efficiency optimization. The carbon dioxide produced by the system is in a state where it can be transported (e.g., by pipeline) for sequestration in the Earth's subsurface regions, in contrast to being released into the atmosphere and contributing to carbon dioxide emissions, and is thus sequestration-ready.

[0022] The subject matter described in this disclosure can be implemented in certain implementations, whereby one or more of the following advantages are realized. Carbon dioxide that can be produced as a byproduct can be sequestered and / or used in another industrial process rather than being released into the atmosphere. The system is flexible in that it can accept a variety of feedstocks such as conventional hydrocarbons (e.g., natural gas, crude oil, and / or their derivatives), biogas, bio-liquid fuels, or oil waste. The systems described herein can be implemented to utilize excess solid carbon products resulting from pyrolysis while addressing the intermittency of renewable energy sources and are typically difficult to introduce into the carbon market. For example, some of the carbon produced by the system can be used as an energy storage medium, and another portion of the carbon produced by the system can be sold on the market as a feedstock for another industrial process. For example, carbon produced by the system can be used to form carbon black, synthetic graphite, carbon filaments / fibers, and / or carbon nanostructures (such as carbon nanotubes and carbon nanofibers).

[0023] FIG. 1A is a schematic diagram of an example of a system 100 for the simultaneous production of hydrogen, carbon, and electricity. System 100 includes a hydrocarbon feed stream 101. Hydrocarbon feed stream 101 includes hydrocarbons (e.g., alkanes, alkenes, alkynes, cyclic hydrocarbons, aromatic hydrocarbons, and / or non-aromatic hydrocarbons). In some implementations, hydrocarbon feed stream 101 includes a plurality of hydrocarbons selected from C1-C22 alkanes (i.e., alkanes having a number of carbon atoms in the range of 1 to 22). In some implementations, hydrocarbon feed stream 101 also includes components other than hydrocarbons such as hydrogen. However, hydrocarbon feed stream 101 does not include oxygen-containing components. System 100 includes a water stream 103 that includes water (i.e., H2O).

[0024] System 100 includes a pyrolysis chamber 110, a gas separation unit 120, a carbon separation unit 130, an electrolysis unit 140, and a power generation unit 150. The pyrolysis chamber 110 is configured to receive a hydrocarbon feed stream 101. The pyrolysis chamber 110 is configured to expose the hydrocarbon feed stream 101 to heat in the absence of oxygen to convert the hydrocarbon feed stream 101 into a solid stream 105 and a gas stream 107. Depending on the implementation, depending on the composition of the hydrocarbon feed stream 101, the pyrolysis chamber 110 may produce a liquid (e.g., bio-oil) that exits the pyrolysis chamber 110 along with the solid stream 105. The solid stream 105 contains carbon. The gas stream 107 contains hydrogen. Depending on the implementation, the gas stream 107 may contain carbon (e.g., small particles entrained in the gas stream 107), unconverted hydrocarbons from the hydrocarbon feed stream 101, or both.

[0025] The gas separation unit 120 is configured to receive the gas stream 107 from the pyrolysis chamber 110. The gas separation unit 120 is configured to separate hydrogen from the gas stream 107 to produce an exhaust gas stream 109 and a first hydrogen stream 111. The first hydrogen stream 111 includes at least a portion of the hydrogen from the gas stream 107. In some implementations, the first hydrogen stream 111 includes substantially all of the hydrogen from the gas stream 107. In some implementations, the exhaust gas stream 109 is the remainder of the gas stream 107 excluding the first hydrogen stream 111. For example, the exhaust gas stream 109 may contain a relatively small amount of hydrogen from the gas stream 107 compared to the first hydrogen stream 111. In some implementations, because the exhaust gas stream 109 may contain unconverted hydrocarbons from the hydrocarbon feed stream 101, at least a portion of the exhaust gas stream 109 is recycled to the pyrolysis chamber 110. In some implementations, at least a portion of the first hydrogen stream 111 is stored and / or transported for use in another industrial process such as ammonia production, power generation, feedstock for hydrogen fuel cells, hydrocarbon sweetening processes, petroleum refining, metal processing (e.g., steel manufacturing), fertilizer manufacturing, and food processing.

[0026] The carbon separation unit 130 is configured to receive the solid stream 105 from the pyrolysis chamber 110. The carbon separation unit 130 is configured to separate carbon from the solid stream 105 to produce a carbon stream 113. For example, if the solid stream 105 contains a liquid, the carbon separation unit 130 separates carbon from the liquid to produce the carbon stream 113. The carbon stream 113 can include carbon black, carbides, synthetic graphite, carbon filaments / fibers, carbon nanostructures (such as carbon nanotubes and carbon nanofibers), or any combination thereof. Depending on the implementation, at least a portion of the carbon stream 113 is stored and / or transported for use in another industrial process such as power generation, carbon black production, carbide production, synthetic graphite production, carbon filament / fiber production, and carbon nanostructure (e.g., carbon nanotubes and carbon nanofibers) production. Depending on the implementation, at least a portion of the carbon stream 113 is sold in the external market.

[0027] The electrolysis unit 140 is configured to receive a water stream 103 and power. The electrolysis unit 140 is configured to perform electrolysis of the received water stream 103 using the received power to produce an oxygen stream 115 and a second hydrogen stream 117. The oxygen stream 115 contains oxygen. At least a part (e.g., all) of the oxygen stream 115 is flowed to the power generation unit 150 to produce power. In some implementations, at least a part of the oxygen stream 115 is stored and / or transported for use in another industrial process such as fuel combustion or power generation. The second hydrogen stream 117 contains hydrogen. In some implementations, at least a part of the second hydrogen stream 117 is stored and / or transported for use in other industrial processes such as ammonia production, power generation, raw material for hydrogen fuel cells, hydrocarbon sweetening processes, petroleum refining, metal processing (e.g., steel manufacturing), fertilizer manufacturing, and food processing. In some implementations, at least a part of the first hydrogen stream 111 and at least a part of the second hydrogen stream 117 are combined, stored, and / or transported for use in another industrial process such as ammonia production, power generation, raw material for hydrogen fuel cells, hydrocarbon sweetening processes, petroleum refining, metal processing (e.g., steel manufacturing), fertilizer manufacturing, and food processing. The electrolysis unit 140 can be configured to receive power from various power sources. For example, the electrolysis unit 140 can be configured to receive power from a renewable energy source. For example, the electrolysis unit 140 can be configured to receive power from the power grid. For example, the electrolysis unit 140 can be configured to receive power from the power generation unit 150. For example, the electrolysis unit 140 can be configured to receive power from a Rankine cycle (an example is shown in FIG. 2 and will be described in detail later). The electrolysis unit 140 can be configured to switch the power source based on the available power and power demand from various power sources.

[0028] The power generation unit 150 is configured to receive at least a part (e.g., most or all) of the oxygen stream 115 from the electrolysis unit 140 and at least a part of the carbon stream 113 from the carbon separation unit 130. The power generation unit 150 includes a direct carbon fuel cell 151. The direct carbon fuel cell 151 is configured to combine oxygen from a part (or all) of the oxygen stream 115 and carbon from a part (or all) of the carbon stream 113 to generate power and a carbon dioxide stream 119. The carbon dioxide stream 119 contains carbon dioxide. The carbon dioxide stream 119 generated by the direct carbon fuel cell 151 is a high-purity carbon dioxide stream. For example, the carbon dioxide stream 119 contains at least 99 volume percent (Vol.%) or at least 99.9 Vol.% of carbon dioxide. For example, the carbon dioxide stream 119 is pure carbon dioxide. At least a part of the power generated by the power generation unit 150 is supplied to the electrolysis unit 140 for electrolysis of the water stream 103. In some implementations, at least a part (e.g., most or all) of the carbon dioxide stream 119 is transported (e.g., via a pipeline) and isolated, for example, in the subsurface region of the earth. The subsurface region may be a geological formation within the earth that defines a reservoir, but in other cases, the subsurface region may be a plurality of formations or a part of a formation. The subsurface region may include, for example, one formation, a part of a formation, or a plurality of formations within a reservoir. In some implementations, the subsurface region includes a subsurface layer of naturally fractured or porous rock. In some implementations, the subsurface region may intersect other types of formations including non-naturally fractured reservoirs. In some implementations, at least a part of the carbon dioxide stream 119 is stored and / or transported for use in another industrial process such as cement production. In some implementations, at least a part of the carbon dioxide stream 119 is injected into a subsurface layer, for example, to facilitate hydrocarbon recovery from the subsurface layer. Since the carbon dioxide stream 119 is not released into the atmosphere, it does not contribute to greenhouse gas emissions.

[0029] In addition to the direct carbon fuel cell 151 for generating electric power, the power generation unit 150 can include additional components and / or alternative components. In some implementations, the power generation unit 150 includes a combustion chamber (not shown), in which carbon (fuel) from a part (or all) of the carbon stream 113 burns in the presence of oxygen (oxidant) from a part (or all) of the oxygen stream 115. In such an implementation, heat is supplied to the combustion chamber to burn the carbon. The heat generated by combustion can be used to generate electric power in a Rankine cycle (including, for example, a turbine) (an example is shown in FIG. 2 and will be described in more detail later).

[0030] In some implementations, at least a part of the electric power generated by the power generation unit 150 is used by another component of the system 100. For example, at least a part of the electric power generated by the power generation unit 150 can be supplied to the electrolysis unit 140 to perform electrolysis of the water stream 103. For example, at least a part of the electric power generated by the power generation unit 150 can be used to supply heat to the pyrolysis chamber 110 to perform pyrolysis of the hydrocarbon feed stream 101. In some implementations, at least a part of the electric power generated by the power generation unit 150 is supplied to another user. For example, at least a part of the electric power generated by the power generation unit 150 can be used in another industrial process. For example, at least a part of the electric power generated by the power generation unit 150 is sent to the power grid, where it can be stored and / or distributed to various users.

[0031] Depending on the implementation, system 100 includes a power distribution unit 160. The power distribution unit 160 can receive power from various power sources. For example, the power distribution unit 160 can be connected to the power grid and receive power therefrom. For example, the power distribution unit 160 can be connected to a renewable energy source (such as wind energy or solar energy) and receive power therefrom. For example, the power distribution unit 160 can be connected to the power generation unit 150 and receive power therefrom. For example, the power distribution unit 160 can be connected to a Rankine cycle and receive power therefrom (e.g., from a turbine within the Rankine cycle). The power distribution unit 160 can distribute power to various users. For example, the power distribution unit 160 can be connected to the electrolysis unit 140 and supply power to the electrolysis unit 140. For example, the power distribution unit 160 can be connected to the pyrolysis chamber 110 and supply power to the pyrolysis chamber 110. For example, the power distribution unit 160 can be connected to the power grid and supply power to the power grid. For example, the power distribution unit 160 can be connected to a Rankine cycle and supply power to the Rankine cycle (e.g., to a pump within the Rankine cycle).

[0032] FIG. 1B is a schematic diagram of an example of the pyrolysis chamber 110. Depending on the implementation, as shown in FIG. 1B, the pyrolysis chamber 110 includes a catalyst 110a. The catalyst 110a can include at least one of activated carbon, carbon black, cobalt, iron, copper, and nickel. The operating pressure inside the pyrolysis chamber 110 can be substantially atmospheric pressure (about 1 atmosphere). The pyrolysis chamber 110 includes a heater 110b. When the pyrolysis chamber 110 is a plasma pyrolysis reactor, the heater 110b includes electrodes, and an inert gas is supplied to the pyrolysis chamber 110 together with the hydrocarbon feed stream 101. Power can be supplied to the electrodes of the heater 110b, and the inert gas functions as an operating gas for producing plasma to pyrolyze the hydrocarbon feed stream 101. When the pyrolysis chamber 110 is a catalytic reactor or a non-catalytic reactor, the heater 110b supplies heat indirectly by a mechanism that generates radiant heat. For example, the heater 110b may be a gas burner or an electric heater including an electrical resistor. When the heater 110b includes electrodes (plasma reactor) or an electrical resistor (electric heater), power is supplied to the heater 110b to generate heat inside the pyrolysis chamber 110.

[0033] FIG. 1C is a schematic diagram of an example of components that can be included in the gas separation unit 120. The gas separation unit 120 can include a gravity settling chamber, a cyclone, a baghouse filter, a microfilter, a pressure swing adsorption bed, a temperature swing adsorption bed, a high density membrane, or any combination thereof. As described above, the gas separation unit 120 separates the gas stream 107 into an exhaust gas stream 109 and a first hydrogen stream 111. The first hydrogen stream 111 includes at least a majority of the hydrogen from the gas stream 107, and the exhaust gas stream 109 includes the remainder of the gas stream 107. Thus, the gas separation unit 120 is mainly used to extract hydrogen from the gas stream 107. Hydrogen can be extracted from the gas stream 107 using a pressure swing adsorption bed, a temperature swing adsorption bed, a high density membrane, or any combination thereof. In some cases, the gas stream 107 may contain some solid particles (e.g., particles of solid carbon entrained in the gas stream 107). In such cases, a gravity settling chamber, a cyclone, a baghouse filter, a microfilter, or any combination thereof can be used to remove solids from the gas stream 107. The components included in the gas separation unit 120 are configured to operate in a range that adds a design margin (e.g., ±5%, ±10%, ±15%, ±20%, ±25%, or ±30%) to the expected operating range (operating pressure and temperature range) of the gas stream 107. In some implementations, the gas stream 107 is cooled before entering the gas separation unit 120.

[0034] FIG. 1C shows examples of a gravity settling chamber, a cyclone, a baghouse filter, a pair of pressure swing adsorption beds, and a high density membrane. In the gravity settling chamber and / or cyclone, the outlet velocity of the gas stream 107 may be less than 300 centimeters per second (cm / s). For example, the outlet velocity of the gas stream 107 exiting the gravity settling chamber may be about 275 cm / s, about 250 cm / s, about 225 cm / s, about 200 cm / s, about 175 cm / s, about 150 cm / s, about 125 cm / s, about 100 cm / s, about 90 cm / s, about 80 cm / s, about 70 cm / s, about 60 cm / s, about 50 cm / s, about 40 cm / s, about 30 cm / s, about 20 cm / s, about 10 cm / s, or about 5 cm / s. In some implementations, it is preferred that the outlet velocity of the gas stream 107 exiting the gravity settling chamber is less than 30 cm / s. In some implementations, the gravity settling chamber and / or cyclone is configured to remove solid particles having an average or maximum particle size in the range of about 10 microns to about 50 microns from the gas stream 107. The density of the solid particles may also be a factor in separating the solid particles from the gas stream 107. In the pressure swing adsorption bed, the extraction of hydrogen from the gas stream 107 depends on various factors such as the pressure difference between the bed and the absorbent material. As shown in FIG. 1C, in the case of the pressure swing adsorption bed, there are at least two containers that swing over a range of pressures. During the adsorption process, a fluid (e.g., gas stream 107) passes through the bed in a first direction and hydrogen is adsorbed onto the bed to produce an exhaust gas stream 109. During the desorption process, the fluid passes through the bed in a second direction and hydrogen is desorbed from the bed to produce a first hydrogen stream 111.

[0035] FIG. 1D is a schematic diagram of an example of components that can be included in the carbon separation unit 130. The carbon separation unit 130 can include a gravity settling chamber, a cyclone, a baghouse filter, a microfilter, a centrifuge, a wet collector, electrostatic separation, acid flux treatment, or any combination thereof. As described above, the carbon separation unit 130 separates carbon from the solid stream 105 to produce the carbon stream 113. Therefore, the carbon separation unit 130 is mainly used to extract carbon from the solid stream 105. The components included in the carbon separation unit 130 are configured to operate within a range that adds a design margin (e.g., ±5%, ±10%, ±15%, ±20%, ±25%, or ±30%) to the expected operating range (operating pressure and temperature range) of the solid stream 105.

[0036] FIG. 1D shows examples of a gravity settling chamber, a cyclone, a baghouse filter, and a centrifuge. In the gravity settling chamber and / or the cyclone, the exit velocity of the solid stream 105 may be less than 300 centimeters per second (cm / s). For example, the exit velocity of the solid stream 105 exiting the gravity settling chamber may be about 275 cm / s, about 250 cm / s, about 225 cm / s, about 200 cm / s, about 175 cm / s, about 150 cm / s, about 125 cm / s, about 100 cm / s, about 90 cm / s, about 80 cm / s, about 70 cm / s, about 60 cm / s, about 50 cm / s, about 40 cm / s, about 30 cm / s, about 20 cm / s, about 10 cm / s, or about 5 cm / s. In some embodiments, it is preferable that the exit velocity of the solid stream 105 exiting the gravity settling chamber is less than 30 cm / s. In some embodiments, the gravity settling chamber and / or the cyclone are configured to remove solid particles having an average or maximum particle size in the range of about 10 microns to about 50 microns from the solid stream 105. Carbon particles with smaller particle sizes may be more commercially valuable than carbon particles with larger particle sizes, so smaller particle sizes may be desired for sale in the external market. In such cases, the larger-sized carbon particles may be used, for example, for power generation. The density of the solid particles may also be a factor when separating the solid particles from the solid stream 105. In a centrifuge, the rotational speed depends on the desired size of the carbon particles removed from the solid stream 105. For example, the rotational speed of the centrifuge can range from about 1,500 revolutions per minute (rpm) to about 50,000 rpm. In some cases, the rotational speed of the centrifuge may exceed 50,000 rpm.

[0037] Figure 1E is a schematic diagram of an example of the electrolysis unit 140. The example of the electrolysis unit 140 shown in Figure 1E is a polymer electrolyte membrane (PEM) electrolysis unit, but different types of electrolysis units such as an alkaline water electrolysis unit, a solid oxide electrolysis unit, or an anion exchange membrane (AEM) electrolysis unit may be alternatively or additionally used. The PEM electrolysis unit 140 includes an anode 140a, a cathode 140b, and a proton exchange membrane 140c. The proton exchange membrane 140c is a solid polymer electrolyte membrane that conducts protons from the anode 140a to the cathode 140b while electrically insulating the electrodes (140a, 140b). The half-reaction occurring on the anode 140a side is also called an oxygen evolution reaction (Equation 1). 2H2O→O2+4H + +4e - (1) The half-reaction occurring on the cathode 140b side is also called a hydrogen evolution reaction (Equation 2). 4H + +4e - →2H2(2)

[0038] The water stream 103 enters the PEM electrolysis unit 140. The PEM electrolysis unit 140 decomposes water into hydrogen and oxygen. The generated hydrogen and oxygen are separated. For example, the membrane is permeable to hydrogen, and hydrogen can pass through the membrane and be separated from oxygen, and oxygen remains on the opposite side of the membrane. The oxygen stream 115 exits the PEM electrolysis unit 140 from the anode 140a side, and the second hydrogen stream 117 exits the PEM electrolysis unit 140 from the cathode 140b side.

[0039] The open-circuit voltage of the operating electrolysis unit 140 can range from about 1.2 volts (V) to about 2.5 V. Depending on the implementation, the operating temperature of the PEM electrolysis unit 140 ranges from about 50°C to about 80°C. Depending on the implementation, the operating pressure of the PEM electrolysis unit 140 is less than about 70 bar. Depending on the implementation, the current density of the power supplied to the PEM electrolysis unit 140 ranges from about 1 ampere per square centimeter (A / cm 2 ) to about 6 A / cm2 is in the range of.

[0040] When the electrolysis unit 140 is an alkaline water electrolysis unit, the open circuit voltage of the operating electrolysis unit 140 can be in the range of about 1.2V to about 3V. Depending on the implementation, the operating temperature of the alkaline water electrolysis unit 140 is in the range of about 70°C to about 90°C. Depending on the implementation, the operating pressure of the alkaline water electrolysis unit 140 is less than about 70 bar. Depending on the implementation, the current density of the power supplied to the alkaline water electrolysis unit 140 is about 0.2A / cm 2 to about 6A / cm 2 is in the range of.

[0041] When the electrolysis unit 140 is a solid oxide electrolysis unit, the open circuit voltage of the operating electrolysis unit 140 can be in the range of about 1V to about 1.5V. Depending on the implementation, the operating temperature of the solid oxide electrolysis unit 140 is in the range of about 700°C to about 850°C. Depending on the implementation, the operating pressure of the solid oxide electrolysis unit 140 is less than about 30 bar. Depending on the implementation, the current density of the power supplied to the solid oxide electrolysis unit 140 is about 0.3A / cm 2 to about 6A / cm 2 is in the range of.

[0042] When the electrolysis unit 140 is an AEM electrolysis unit, the open circuit voltage of the operating electrolysis unit 140 can be in the range of about 1.2V to about 2V. Depending on the implementation, the operating temperature of the AEM electrolysis unit 140 is in the range of about 40°C to about 80°C. Depending on the implementation, the operating pressure of the AEM electrolysis unit 140 is less than about 70 bar. Depending on the implementation, the current density of the power supplied to the AEM electrolysis unit 140 is about 0.2A / cm 2 to about 6A / cm 2 is in the range of.

[0043] Figure 1F is a schematic diagram of an example of a direct carbon fuel cell 151. The example of the direct carbon fuel cell 151 shown in Figure 1F includes a solid oxide electrolyte 152, but different types of electrolytes such as molten salts (e.g., hydroxide salts), molten carbonates, and molten tin anodes may be used alternatively or additionally. Oxygen from the oxygen stream 115 flows into the direct carbon fuel cell 151, and carbon from the carbon stream 113 flows into the direct carbon fuel cell 151. The direct carbon fuel cell 151 combines oxygen and carbon to generate carbon dioxide and electricity. The carbon dioxide stream 119 flows out of the direct carbon fuel cell 151. In some embodiments, the solid oxide electrolyte 152 is zirconium oxide (ZrO2). In some embodiments, oxides such as yttrium oxide (Y2O3) or scandium(III) oxide (Sc2O3) are added to the solid oxide electrolyte 152. The solid oxide electrolyte 152 can be configured to combine carbon and oxygen at an operating temperature in the range of about 550°C to about 1000°C, about 600°C to about 1000°C, about 650°C to about 1000°C, about 700°C to about 1000°C, about 750°C to about 1000°C, about 800°C to about 1000°C, about 850°C to about 1000°C, about 900°C to about 1000°C, or about 950°C to about 1000°C to generate electricity and carbon dioxide.

[0044] When the direct carbon fuel cell 151 includes a molten salt electrolyte (e.g., potassium hydroxide or sodium hydroxide), the direct carbon fuel cell 151 can be configured to combine carbon and oxygen at an operating temperature in the range of about 500°C to about 600°C to generate electricity and carbon dioxide. When the direct carbon fuel cell 151 includes a molten carbonate electrolyte (e.g., including lithium, sodium, or potassium), the direct carbon fuel cell 151 can be configured to combine carbon and oxygen at an operating temperature in the range of about 750°C to about 800°C to generate electricity and carbon dioxide. When the direct carbon fuel cell 151 includes a molten tin anode, the direct carbon fuel cell 151 can be configured to combine carbon and oxygen at an operating temperature of about 900°C to generate electricity and carbon dioxide.

[0045] Figure 1G is a schematic diagram of an example of a simultaneous production system 100G for hydrogen, carbon, and electricity that realizes waste heat recovery. System 100G is substantially similar to system 100 shown in Figure 1A and can include substantially the same components. System 100G includes a first waste heat recovery heat exchanger 190G and a second waste heat recovery heat exchanger 190G'. The first waste heat recovery heat exchanger 190G is in fluid communication with at least a portion of the gas stream 107 exiting the pyrolysis chamber 110 on the first side. The first waste heat recovery heat exchanger 190G is in fluid communication with a buffer fluid on the second side. The first waste heat recovery heat exchanger 190G is configured to transfer heat from a portion (or all) of the gas stream 107 to the buffer fluid. Accordingly, the gas stream 107 is cooled by the first waste heat recovery heat exchanger 190G before being processed by the gas separation unit 120. The second waste heat recovery heat exchanger 190G' can be in fluid communication with at least a portion of the hydrocarbon supply stream 101 entering the pyrolysis chamber 110 on the first side. The second waste heat recovery heat exchanger 190G' can be in fluid communication with a buffer fluid on the second side. The second waste heat recovery heat exchanger 190G' can be configured to transfer heat from the buffer fluid to a portion (or all) of the hydrocarbon supply stream 101 before the hydrocarbon supply stream 101 enters the pyrolysis chamber 110. Accordingly, the first and second waste heat recovery heat exchangers 190G, 190G' cooperate to recover heat from the gas stream 107 and use the recovered heat to preheat a portion (or all) of the hydrocarbon supply stream 101 before the hydrocarbon supply stream 101 is pyrolyzed in the pyrolysis chamber 110. The buffer fluid is an intermediate fluid that transfers heat from the gas stream 107 to the hydrocarbon supply stream 101. The buffer fluid can be any suitable fluid that can transfer heat from the gas stream 107 to the hydrocarbon supply stream 101. For example, the buffer fluid can be an aqueous fluid or an oily fluid (such as a hydrocarbon fluid). For example, the buffer fluid can include supercritical carbon dioxide.

[0046] Figure 1H is a schematic diagram of an example of a simultaneous hydrogen, carbon, and electricity production system 100H that realizes waste heat recovery. System 100H is substantially similar to system 100 shown in Figure 1A and can include substantially the same components. System 100H includes a first waste heat recovery heat exchanger 190H and a second waste heat recovery heat exchanger 190H'. The first waste heat recovery heat exchanger 190H is in fluid communication, on a first side, with at least a portion of a carbon dioxide stream 119 exiting the power generation unit 150. The first waste heat recovery heat exchanger 190H is in fluid communication with a buffer fluid on a second side. The first waste heat recovery heat exchanger 190H is configured to transfer heat from a portion (or all) of the carbon dioxide stream 119 to the buffer fluid. The second waste heat recovery heat exchanger 190H' can be in fluid communication, on a first side, with at least a portion of a hydrocarbon feed stream 101 entering the pyrolysis chamber 110. The second waste heat recovery heat exchanger 190H’ can be in fluid communication with the buffer fluid on a second side. The second waste heat recovery heat exchanger 190H’ can be configured to transfer heat from the buffer fluid to a portion (or all) of the hydrocarbon feed stream 101 before the hydrocarbon feed stream 101 enters the pyrolysis chamber 110. Thus, the first and second waste heat recovery heat exchangers 190H, 190H’ cooperate to recover heat from the gas stream 107 and use the recovered heat to preheat a portion (or all) of the hydrocarbon feed stream 101 before the hydrocarbon feed stream 101 is pyrolyzed in the pyrolysis chamber 110. The buffer fluid is an intermediate fluid that transfers heat from the gas stream 107 to the hydrocarbon feed stream 101. The buffer fluid can be any suitable fluid that can transfer heat from the gas stream 107 to the hydrocarbon feed stream 101. For example, the buffer fluid can be an aqueous fluid or an oily fluid (such as a hydrocarbon fluid). Figures 1G and 1H show specific examples of where waste heat can be recovered from specific regions within each system, but waste heat recovery can be implemented anywhere where waste heat is generated.

[0047] FIG. 2 is a schematic diagram of an example of a Rankine cycle 200 that generates power using heat. Cycle 200 includes a boiler 210, a turbine 220, a condenser 230, and a pump 240. The pump 240 circulates a working fluid 202 through the cycle 200. The working fluid 202 changes in temperature and pressure as it flows through the cycle 200. As the working fluid 202 flows through the cycle 200, a phase change of the working fluid 202 occurs due to the changes in temperature and pressure. For clarity, the various states of the working fluid 202 (having various phase compositions) are shown in a form where a letter follows 202 (e.g., 202a and 202b). As the working fluid 202 flows through the cycle 200, the overall composition of the working fluid 202 does not change. However, the individual phases (e.g., the gas phase and the liquid phase) can have various compositions based on the operating conditions, heat, and work (thermodynamics).

[0048] The liquid working fluid 202 (202a) enters the boiler 210. The boiler 210 is configured to receive the liquid working fluid 202. The boiler 210 is configured to transfer heat to the working fluid 202 to produce a vaporized working fluid 202b. The vaporized working fluid 202b flows from the boiler 210 to the turbine 220. The turbine 220 is configured to receive the vaporized working fluid 202b. The turbine 220 is configured to generate power as the vaporized working fluid 202b expands as it flows through the turbine 220. The vaporized working fluid 202b exiting the turbine 220 has a reduced operating pressure compared to the vaporized working fluid 202b entering the turbine 220. The vaporized working fluid 202b flows from the turbine 220 to the condenser 230. The condenser 230 is configured to receive and condense the vaporized working fluid 202b into a condensed working fluid 202a. The condensed working fluid 202a flows from the condenser 230 to the pump 240. The pump 240 is configured to circulate the condensed working fluid 202a to the boiler 210 to restart the cycle 200.

[0049] The heat used by the boiler 210 to vaporize the working fluid 202 can be supplied from various heat sources. In some embodiments, the boiler 210 receives heat from a buffer fluid (e.g., from the first waste heat recovery heat exchanger 190G or 190H). For example, the boiler 210 can be configured to be in fluid communication with the buffer fluid from the first waste heat recovery heat exchanger 190G on a first side and in fluid communication with the working fluid 202 on a second side. For example, the boiler 210 can be configured to be in fluid communication with the buffer fluid from the first waste heat recovery heat exchanger 190H on a first side and in fluid communication with the working fluid 202 on a second side. In some embodiments, the boiler 210 receives heat from the combustion of fuel (e.g., from the combustion of at least a portion of the carbon stream 113 in the presence of oxygen from at least a portion of the oxygen stream 115 in the power generation unit 150).

[0050] In some embodiments, at least a portion of the power generated by the turbine 220 is used by components of the system 100, 100G, or 100H. For example, at least a portion of the power generated by the turbine 220 can be supplied to the electrolysis unit 140 to perform electrolysis of the water stream 103. For example, using at least a portion of the power generated by the turbine 220, heat can be supplied to the pyrolysis chamber 110 to perform pyrolysis of the hydrocarbon feed stream 101. In some embodiments, at least a portion of the power generated by the turbine 220 is supplied to another user. For example, at least a portion of the power generated by the turbine 220 can be used in another industrial process. For example, at least a portion of the power generated by the turbine 220 can be sent to the power grid, where it can be stored and / or distributed to various users. For example, at least a portion of the power generated by the turbine 220 can be supplied to another process within the same facility as one of the systems 100, 100G, or 100H.

[0051] Figure 3 is a flowchart showing an example of a method 300 for the simultaneous production of hydrogen, carbon, electricity, and isolated carbon dioxide. Method 300 can be implemented using any of systems 100, 100G, or 100H. A hydrocarbon feed stream (such as hydrocarbon feed stream 101) flows into a pyrolysis chamber (such as pyrolysis chamber 110). In block 302, the hydrocarbon feed stream 101 is exposed to heat in the absence of oxygen (e.g., within pyrolysis chamber 110), converting the hydrocarbon feed stream 101 into a solid stream (such as solid stream 105) and a gas stream (such as gas stream 107). As described above, the solid stream 105 contains carbon and the gas stream 107 contains hydrogen. The gas stream 107 flows from the pyrolysis chamber 110 to a gas separation unit (such as gas separation unit 120). In block 304, the gas stream 107 is separated (e.g., within gas separation unit 120) into an exhaust gas stream (such as exhaust gas stream 109) and a first hydrogen stream (such as first hydrogen stream 111) containing at least a portion of the hydrogen from the gas stream 107. The solid stream 105 flows from the pyrolysis chamber 110 to a carbon separation unit (such as carbon separation unit 130). In block 306, carbon is separated from the solid stream 105 (e.g., within carbon separation unit 130) to produce a carbon stream (such as carbon stream 113). A water stream (such as water stream 103) flows into an electrolysis unit (such as electrolysis unit 140). The electrolysis unit 140 is supplied with power. In block 308, electrolysis is performed on the water stream 103 (e.g., by electrolysis unit 140 in response to receiving power) to produce an oxygen stream (such as oxygen stream 115) and a second hydrogen stream (such as second hydrogen stream 117). At least a portion of the oxygen stream 115 flows from the electrolysis unit 140 to a power generation unit (such as power generation unit 150). At least a portion of the carbon stream 113 flows from the carbon separation unit 130 to the power generation unit 150. As described above, the power generation unit 150 includes a direct carbon fuel cell 151.In block 310, oxygen from a part (or all) of the oxygen stream 115 and carbon from a part (or all) of the carbon stream 113 combine (e.g., by the direct carbon type fuel cell 151) to generate electric power and a carbon dioxide stream (such as the carbon dioxide stream 119). At least a part of the electric power generated in block 310 is used to perform the electrolysis of the water stream 103 (block 308). Therefore, at least a part of the electric power used to perform the electrolysis in block 308 (e.g., by the electrolysis unit 140) is supplied from at least a part of the electric power generated in block 310. In some implementations, at least a part of the electric power generated in block 310 is used to perform the pyrolysis of the hydrocarbon supply stream 101 (block 302).

[0052] Although many specific implementation details are described in this specification, these should not be construed as limitations of the claims, but rather as descriptions of features specific to particular implementations. The specific features described in this specification in the context of individual implementations can be implemented singly or in combination. Conversely, the various features described in the context of a single implementation can be implemented individually or in any partial combination in multiple implementations. Furthermore, the foregoing features have been described and even initially claimed to function in a particular combination, but one or more features from the claimed combination may, in some cases, be deleted from the combination, and the claimed combination may be directed to a partial combination or a variation of a partial combination.

[0053] As used in this disclosure, the terms "a", "an", or "the" are used to include one or more, unless the context clearly indicates otherwise. The term "or" is used to refer to non-exclusive "or", unless otherwise specified. The description "at least one of A and B" has the same meaning as "A, B, or A and B". Further, it should be understood that expressions or terms used in this disclosure and not otherwise defined are for illustrative purposes only and not for limitation. The use of section headings is for the purpose of document readability and not for limitation. Information related to a section heading may appear within or outside that particular section.

[0054] As used in this disclosure, the terms "about" or "approximately" allow for a degree of variation in a value or range. For example, within 10%, 5%, or 1% of the stated value or the limits of the stated range.

[0055] As used in this disclosure, the term "substantially" refers to a majority or a large part, such as at least about 50%, 60%, 70%, 80%, 90%, 95%, 96%, 97%, 98%, 99%, 99.5%, 99.9%, 99.99%, or at least about 99.999% or more.

[0056] Values expressed in a range format should be interpreted flexibly to include not only the numerical values specified as the limits of the range, but also all individual numerical values or sub-ranges included within that range as if each numerical value and sub-range were specified. For example, a range of "0.1% to about 5%" or "0.1% to 5%" should be interpreted to include not only about 0.1% to about 5%, but also the individual values within the indicated range (e.g., 1%, 2%, 3%, and 4%) and sub-ranges (e.g., 0.1% to 0.5%, 1.1% to 2.2%, 3.3% to 4.4%). The description "from X to Y" has the same meaning as "from about X to about Y" unless otherwise specified. Similarly, the description "X, Y, or Z" has the same meaning as "about X, about Y, or about Z" unless otherwise specified.

[0057] Specific implementations of the subject matter have been described. Other implementations, variations, and substitutions of the described implementations are within the scope of the following claims, as will be apparent to those skilled in the art. Although operations are presented in a particular order in the drawings or claims, this should not be understood as requiring that such operations be performed in the particular order or sequential order shown, or that all of the illustrated operations be performed (some operations may be considered optional in some cases). In certain situations, multitasking or parallel processing (or a combination of multitasking and parallel processing) may be advantageous and may be performed if determined appropriate.

[0058] Furthermore, the separation or integration of the various system modules and components in the foregoing implementations should not be understood as requiring such separation or integration in all implementations. It should be understood that the components and systems described can generally be integrated together or packaged into multiple products.

[0059] Accordingly, the examples of the foregoing implementations do not define or limit the present disclosure. Other changes, substitutions, and modifications are possible without departing from the spirit and scope of the present disclosure.

Claims

1. A step of converting a hydrocarbon supply stream containing hydrocarbons and hydrogen into a solid stream and a gaseous stream by exposing the hydrocarbon supply stream containing hydrocarbons and hydrogen to heat in the absence of oxygen within a pyrolysis chamber, wherein the solid stream contains carbon and the gaseous stream contains hydrogen; The steps include separating the gas stream into an exhaust gas stream and a first hydrogen stream containing at least a portion of the hydrogen from the gas stream; The steps include: separating the carbon from the solid stream to produce a carbon stream; A step of performing electrolysis on a water stream containing water, wherein an oxygen stream and a second hydrogen stream are produced, the oxygen stream containing oxygen and the second hydrogen stream containing hydrogen; A step of generating a carbon dioxide stream containing electricity and carbon dioxide by combining at least a portion of the oxygen in the oxygen stream and at least a portion of the carbon in the carbon stream, wherein a first portion of the generated electricity is used to electrolyze the water stream; The step of supplying a second portion of the generated power to the heater of the pyrolysis chamber to generate heat in the pyrolysis chamber; method.

2. The hydrocarbon supply stream comprises a plurality of hydrocarbons selected from C1-C22 alkanes. The method according to claim 1.

3. The oxygen and carbon are bonded by a direct carbon fuel cell containing a solid oxide, and the oxygen and carbon are bonded by the direct carbon fuel cell at an operating temperature in the range of approximately 800°C to approximately 1000°C. The method according to claim 1.

4. The process includes a step of transferring heat from the gas stream to a buffer fluid using a first waste heat recovery heat exchanger. The method according to claim 3.

5. The method includes a step of transferring heat from the buffer fluid to the hydrocarbon supply stream by a second waste heat recovery heat exchanger before exposing the hydrocarbon supply stream to heat in the absence of oxygen. The method according to claim 4.

6. The process includes a step of generating power by a Rankine cycle using heat transferred from the gas stream to the buffer stream, The steps for generating power by the aforementioned Rankine cycle are: The steps include: transferring heat from the buffer fluid to the working fluid in the boiler to vaporize the working fluid and convert it into a vaporized working fluid; The steps include: flowing the vaporized working fluid through a turbine to expand it and generate electricity; The steps include: condensing the vaporized working fluid to make it a condensed working fluid; The step of circulating the condensing working fluid to the boiler; The method according to claim 4.

7. The process includes the step of transferring heat from the carbon dioxide stream to a buffer fluid using a first waste heat recovery heat exchanger. The method according to claim 3.

8. The method includes a step of transferring heat from the buffer fluid to the hydrocarbon supply stream by a second waste heat recovery heat exchanger before exposing the hydrocarbon supply stream to heat in the absence of oxygen. The method according to claim 7.

9. The method includes the step of isolating the carbon dioxide stream generated by the direct carbon fuel cell in an underground layer to prevent the carbon dioxide stream from being released into the atmosphere. The method according to claim 3.

10. Supplying the second portion of the generated power to the heater of the pyrolysis chamber includes supplying the second portion of the generated power to the electrodes of the heater, The method includes flowing an inert gas into the pyrolysis chamber together with the hydrocarbon supply stream, By supplying the second portion of the generated power to the electrodes of the heater, plasma is generated from the inert gas to thermally decompose the hydrocarbon supply stream. The method according to claim 1.

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