Hydrogen generation assembly

Abstract

Hydrogen generation assemblies and methods are disclosed. In one embodiment, the method includes receiving a feed stream in a fuel processing assembly, and heating a hydrogen generation zone of the fuel processing assembly to at least a minimum hydrogen production temperature via one or more combustors. The method additionally includes generating an output stream from the received feed stream in the heated hydrogen generation zone of the fuel processing assembly, and generating a product hydrogen stream and a byproduct stream from the output stream in a purification zone of the fuel processing assembly. The method also includes separating at least a portion of carbon dioxide gas from the byproduct stream to generate a fuel stream having a lower concentration of carbon dioxide than the byproduct stream, and feeding the fuel stream to the one or more combustors.

Description

Background Technology

[0001] A hydrogen generation assembly is an assembly that converts one or more feedstocks into a product stream containing hydrogen as the primary component. Feedstocks may include carbonaceous feedstocks, and in some embodiments, may also include water. The feedstock is delivered from a feedstock delivery system to the hydrogen generation zone of the hydrogen generation assembly, typically under pressure and at elevated temperatures. The hydrogen generation zone is typically associated with temperature control components, such as heating or cooling components, which consume one or more fuel streams to maintain the hydrogen generation zone within a suitable temperature range for efficient hydrogen production. The hydrogen generation assembly can generate hydrogen via any suitable mechanism(s), such as steam reforming, autothermal reforming, pyrolysis, and / or catalytic partial oxidation.

[0002] However, the generated or produced hydrogen may contain impurities. This gas can be referred to as a mixed gas stream containing hydrogen and other gases. Before using the mixed gas stream, it must be purified, such as by removing at least a portion of the other gases. Therefore, the hydrogen generation assembly may include a hydrogen purification device for improving the hydrogen purity of the mixed gas stream. The hydrogen purification device may include at least one hydrogen-selective membrane to separate the mixed gas stream into a product stream and a byproduct stream. The product stream contains a higher concentration of hydrogen from the mixed gas stream and / or a reduced concentration of one or more other gases. Hydrogen purification using one or more hydrogen-selective membranes is a pressure-driven separation process in which one or more hydrogen-selective membranes are contained within a pressure vessel. The mixed gas stream contacts the mixed gas surface of the membrane(s), while the product stream is formed by at least a portion of the mixed gas stream permeating through the membrane(s). The pressure vessel is typically sealed to prevent gas from entering or leaving the pressure vessel except through defined inlets and outlets or conduits.

[0003] The product stream can be used in a variety of applications. One such application is energy generation, such as in electrochemical fuel cells. An electrochemical fuel cell is a device that converts fuel and oxidant into electricity, reaction products, and heat. For example, a fuel cell can convert hydrogen and oxygen into water and electricity. In these fuel cells, hydrogen is the fuel, oxygen is the oxidant, and water is the reaction product. A fuel cell stack comprises multiple fuel cells and can be used in conjunction with a hydrogen generation component to provide an energy generation component.

[0004] In US patent numbers 5,861,137, 6,319,306, 6,494,937, 6,562,111, 7,063,047, 7,306,868, 7,470,293, 7,601,302, 7,632,322, 8,961,627, 9,187,324, 9,914,641, 10,717,040; and US Examples of hydrogen generation components, hydrogen processing components, and / or parts thereof are described in US Patent Application Publications 2006 / 0090397, 2006 / 0272212, 2007 / 0266631, 2007 / 0274904, 2008 / 0085434, 2008 / 0138678, 2008 / 0230039, and 2010 / 0064887. The full disclosure of the aforementioned patent and patent application publications is incorporated herein by reference for all purposes. Summary of the Invention

[0005] Some embodiments include a method for generating hydrogen. In one embodiment, the method includes receiving a feed stream in a fuel processing assembly. The feed stream contains a carbonaceous feedstock. The method further includes heating a hydrogen generation zone of the fuel processing assembly to at least a minimum hydrogen generation temperature via one or more burners. The method also includes generating an output stream from the received feed stream in the heated hydrogen generation zone of the fuel processing assembly. The output stream contains hydrogen and carbon dioxide gas.

[0006] The method further includes generating a product hydrogen stream and a byproduct stream from the output stream in a purification zone of the fuel processing assembly. The product hydrogen stream has a higher hydrogen concentration and a lower carbon dioxide concentration than the output stream, and the byproduct stream has a lower hydrogen concentration and a higher carbon dioxide concentration than the output stream; the method further includes separating at least a portion of the carbon dioxide gas from the byproduct stream to generate a fuel stream with a carbon dioxide concentration lower than that of the byproduct stream. The method further includes feeding the fuel stream to one or more combustors.

[0007] Some embodiments include a hydrogen generation assembly. In one embodiment, the assembly includes an enclosure and a hydrogen generation zone contained within the enclosure. The hydrogen generation zone is configured to generate an output stream from at least one feed stream. The output stream contains hydrogen and carbon dioxide gas, and the at least one feed stream contains a carbonaceous feedstock. The assembly also includes a heating assembly configured to receive at least one air stream and at least one fuel stream, and to combust the at least one fuel stream within a combustion zone contained within the enclosure, thereby generating a heated exhaust stream for heating the hydrogen generation zone to at least a minimum hydrogen generation temperature.

[0008] The component also includes a purification zone contained within a housing. The purification zone is configured to generate a product hydrogen stream and a byproduct stream, the product hydrogen stream having a higher hydrogen concentration and a lower carbon dioxide concentration than the output stream, and the byproduct stream having a lower hydrogen concentration and a higher carbon dioxide concentration than the output stream. The component further includes a gas removal component configured to separate at least a portion of the carbon dioxide gas from the byproduct stream, thereby generating at least a portion of at least one fuel stream. Attached Figure Description

[0009] Figure 1 This is a schematic diagram of an example of a hydrogen generation component.

[0010] Figure 2 yes Figure 1 A schematic diagram of an example of a hydrogen generation component.

[0011] Figure 3 yes Figure 2 A schematic diagram of an example of a gas removal component for a hydrogen generation component.

[0012] Figure 4 yes Figure 3 A schematic diagram of an example gas removal component.

[0013] Figure 5 yes Figure 3 A schematic diagram of another example of a gas removal component.

[0014] Figure 6 yes Figure 3 A schematic diagram of an additional example of a gas removal component.

[0015] Figure 7 yes Figure 3 A schematic diagram of another example of a gas removal component.

[0016] Figure 8 yes Figure 3 A schematic diagram of another example of a gas removal component.

[0017] Figure 9 yes Figure 8 A schematic diagram of an example membrane contactor for a gas removal component.

[0018] Figure 10 yes Figure 9 A schematic diagram of an example membrane of a membrane contactor.

[0019] Figure 11 yes Figure 9 A schematic diagram of another example of a membrane contactor.

[0020] Figure 12 yes Figure 3 A schematic diagram of an additional example of a gas removal component.

[0021] Figure 13 This is a flowchart illustrating an example of a method for generating hydrogen. Detailed Implementation

[0022] Figure 1 An example of hydrogen generation assembly 20 is shown. Unless specifically excluded, hydrogen generation assembly 20 may include one or more components of other hydrogen generation assemblies described in this disclosure. The hydrogen generation assembly may include any suitable structure configured to generate product hydrogen stream 21. For example, the hydrogen generation assembly may include feedstock delivery system 22 and fuel processing assembly 24. The feedstock delivery system may include any suitable structure configured to selectively deliver at least one feed stream 26 to the fuel processing assembly.

[0023] In some embodiments, the feed delivery system 22 may additionally include any suitable structure configured to selectively deliver at least one fuel stream 28 to a burner or other heating component of the fuel processing assembly 24. In some embodiments, the feed stream 26 and the fuel stream 28 may be the same stream delivered to different portions of the fuel processing assembly. The feed delivery system may include any suitable delivery mechanism, such as a positive displacement pump or other suitable pump or mechanism for propelling fluid streams. In some embodiments, the feed delivery system may be configured to deliver one or more feed streams 26 and / or one or more fuel streams 28 without requiring the use of a pump and / or other electrically driven fluid delivery mechanism. Examples of suitable feed delivery systems that may be used with the hydrogen generation assembly 20 include those described in U.S. Patent Nos. 7,470,293 and 7,601,302 and U.S. Patent Application Publication No. 2006 / 0090397. The entire disclosure of the foregoing patents and patent applications is incorporated herein by reference for all purposes.

[0024] Feed stream 26 may include at least one hydrogen-generating fluid 30, which may include one or more fluids that can be used as reactants to produce product hydrogen stream 21. For example, the hydrogen-generating fluid may include a carbonaceous feedstock, such as at least one hydrocarbon and / or alcohol. Examples of suitable hydrocarbons include methane, propane, natural gas, diesel, kerosene, gasoline, etc. Examples of suitable alcohols include methanol, ethanol, polyols (such as ethylene glycol and propylene glycol), etc. In addition, hydrogen-generating fluid 30 may include water, as is the case when the fuel processing assembly generates product hydrogen stream via steam reforming and / or autothermal reforming. When the fuel processing assembly 24 generates product hydrogen stream via pyrolysis or catalytic partial oxidation, feed stream 26 does not contain water.

[0025] In some embodiments, feedstock delivery system 22 may be configured to deliver a hydrogen-generating fluid 30 comprising a mixture of water and a water-miscible carbonaceous feedstock (such as methanol and / or another water-soluble alcohol). The water-to-carbonaceous feedstock ratio in this fluid stream may vary depending on one or more factors, such as the specific carbonaceous feedstock used, user preferences, the design of the fuel processing assembly, and one or more mechanisms of the hydrogen generation stream used by the fuel processing assembly. For example, the water-to-carbon molar ratio may be approximately 1:1 to 3:1. Furthermore, mixtures of water and methanol may be delivered at or near a 1:1 molar ratio (37% water by weight, 63% methanol by weight), while mixtures of hydrocarbons or other alcohols may be delivered at a water-to-carbon molar ratio greater than 1:1.

[0026] When the fuel processing assembly 24 generates product hydrogen via reforming product hydrogen stream 21, the feed stream 26 may include, for example, about 25-75 vol% methanol or ethanol (or another suitable water-miscible carbonaceous feedstock) and about 25-75 vol% water. For feed streams that consist at least substantially of methanol and water, those streams may include about 50-75 vol% methanol and about 25-50 vol% water. Streams containing ethanol or other water-miscible alcohols may contain about 25-60 vol% alcohol and about 40-75 vol% water. An example of a feed stream for a hydrogen generation assembly 20 utilizing steam reforming or autothermal reforming contains 69 vol% methanol and 31 vol% water.

[0027] Although the illustrated feed delivery system 22 is configured to deliver a single feed stream 26, the feed delivery system may be configured to deliver two or more feed streams 26. These streams may contain the same or different feeds and may have different compositions, at least one common component, no common component, or the same composition. For example, a first feed stream may include a first component, such as a carbon-containing feedstock, and a second feed stream may include a second component, such as water. Furthermore, although in some embodiments the feed delivery system 22 may be configured to deliver a single fuel stream 28, the feed delivery system may also be configured to deliver two or more fuel streams. The fuel streams may have different compositions, at least one common component, no common component, or the same composition. Furthermore, the feed streams and fuel streams may exit the feed delivery system at different stages. For example, one of the streams may be a liquid stream and the other a gaseous stream. In some embodiments, both streams may be liquid streams, while in other embodiments, both streams may be gaseous streams. Additionally, although the hydrogen generation assembly 20 is shown as including a single feed delivery system 22, the hydrogen generation assembly may include two or more feed delivery systems 22.

[0028] The fuel processing assembly 24 may include a hydrogen production zone 32, which is configured to produce an output stream 34 containing hydrogen via any suitable hydrogen production mechanism(s). The output stream may include hydrogen as at least a majority component and may include one or more additional gaseous components(s). The output stream 34 may therefore be referred to as a “mixed gas stream” containing hydrogen as at least a majority component, but also including other gases.

[0029] The hydrogen production zone 32 may include any suitable catalyst bed or region. When the hydrogen production mechanism is steam reforming, the hydrogen production zone may include a suitable steam reforming catalyst 36 to facilitate the production of one or more output streams 34 from one or more feed streams 26 containing carbonaceous feedstock and water. In such an embodiment, the fuel processing assembly 24 may be referred to as a “steam reformer,” the hydrogen production zone 32 as a “reformation zone,” and the output stream 34 as a “reformed stream.” Other gases that may be present in the reformed stream may include carbon monoxide, carbon dioxide, methane, steam, and / or unreacted carbonaceous feedstock.

[0030] When the hydrogen production mechanism is autothermal reforming, the hydrogen production zone 32 may include a suitable autothermal reforming catalyst to facilitate the generation of one or more output streams 34 from one or more feed streams 26 containing water and carbonaceous feedstock in the presence of air. Furthermore, the fuel processing assembly 24 may include an air delivery assembly 38 configured to deliver one or more air streams to the hydrogen production zone.

[0031] In some embodiments, the fuel processing assembly 24 may include a purification (or separation) zone 40, which may include any suitable structure configured to generate at least one hydrogen-rich stream 42 from the output (or mixed gas) stream 34. The hydrogen-rich stream 42 may include a higher hydrogen concentration than the output stream 34 and / or one or more other gases (or impurities) present in the output stream at reduced concentrations. The product hydrogen stream 21 includes at least a portion of the hydrogen-rich stream 42. Thus, the product hydrogen stream 21 and the hydrogen-rich stream 42 may be the same stream and have the same composition and flow rate. Alternatively, some of the purified hydrogen in the hydrogen-rich stream 42 may be stored for later use, such as in a suitable hydrogen storage assembly and / or consumed by the fuel processing assembly. The purification zone 40 may also be referred to as a "hydrogen purification device" or a "hydrogen processing assembly".

[0032] In some embodiments, purification zone 40 may generate at least one byproduct stream 44, which may contain no hydrogen or contain some hydrogen. The byproduct stream may be discharged, sent to a burner assembly and / or other combustion source, used as a heated fluid stream, stored for later use, and / or otherwise utilized, stored, and / or disposed of. Additionally, purification zone 40 may continuously discharge the byproduct stream in response to the delivered output stream 34, or may discharge the byproduct stream intermittently, such as during batch processing or when a portion of the byproduct from the output stream is at least temporarily retained in the purification zone.

[0033] The fuel processing assembly 24 may include one or more purification zones configured to generate one or more byproduct streams, the byproduct streams containing sufficient hydrogen to be suitable as a fuel stream (or feed stream) for use as a heating element of the fuel processing assembly. In some embodiments, the byproduct streams may have sufficient fuel value or hydrogen content to enable the heating element to maintain the hydrogen generation zone at a desired operating temperature or a selected temperature range. For example, the byproduct streams may include hydrogen, such as 10-30 vol% hydrogen, 15-25 vol% hydrogen, 20-30 vol% hydrogen, at least 10 or 15 vol% hydrogen, at least 20 vol% hydrogen, etc.

[0034] Purification zone 40 may include any suitable structure configured to enrich (and / or increase) the concentration of at least one component of output stream 21. In most applications, hydrogen-rich stream 42 will have a higher hydrogen concentration than output stream (or mixed gas stream) 34. Hydrogen-rich stream may also contain one or more non-hydrogen components present in reduced concentrations in output stream 34, wherein the hydrogen concentration of hydrogen-rich stream is higher than, equal to, or lower than that of output stream. For example, in conventional fuel cell systems, carbon monoxide, even in its presence at parts per million, can damage the fuel cell stack, while other non-hydrogen components that may be present in output stream 34, such as water, will not damage the stack, even in much higher concentrations. Therefore, in such applications, purification zone may not increase the overall hydrogen concentration but will reduce the concentration of one or more non-hydrogen components that are detrimental or potentially harmful to the desired application of the product hydrogen stream.

[0035] Examples of suitable devices for purification zone 40 include one or more hydrogen-selective membranes 46, chemical carbon monoxide removal components 48, and / or pressure swing adsorption (PSA) systems 50. Purification zone 40 may include more than one type of purification device, and these devices may have the same or different structures and / or operate through the same or different mechanisms(s). Downstream of purification zones(s), fuel processing component 24 may include at least one throttling orifice and / or other flow restrictor, such as one or more product hydrogen streams, one or more hydrogen-rich streams, and / or one or more byproduct streams.

[0036] The hydrogen-selective membrane 46 is permeable to hydrogen, but at least substantially (if not completely) impermeable to other components of the output stream 34. Membrane 46 can be formed from any hydrogen-permeable material suitable for use under the operating conditions and parameters to which the purification zone 40 is operated. Examples of suitable materials for membrane 46 include palladium and palladium alloys, particularly thin films of such metals and metal alloys. Palladium alloys have proven particularly effective, especially alloys of palladium with 35% to 45% copper. Although other relative concentrations and compositions can be used, palladium-copper alloys containing approximately 40% copper have proven particularly effective. Three other particularly effective alloys are: palladium alloys with 2% to 20% gold, especially palladium alloys with 5% gold; palladium alloys with 3% to 10% indium and 0% to 10% ruthenium, especially palladium alloys with 6% indium and 0.5% ruthenium; and palladium alloys with 20% to 30% silver. When using palladium and palladium alloys, the hydrogen-selective membrane 46 may sometimes be referred to as a "foil". The typical thickness of the hydrogen-permeable metal foil is less than 25 micrometers, preferably less than or equal to 15 micrometers, and most preferably between 5 and 12 micrometers. The foil can be any suitable size, such as 110 mm × 270 mm.

[0037] The chemical carbon monoxide removal assembly 48 is a device that chemically reacts carbon monoxide and / or other undesirable components in the output stream 34 to form other non-hazardous components. Examples of chemical carbon monoxide removal assemblies include: a water-gas shift reactor configured to produce hydrogen and carbon dioxide from water and carbon monoxide; a partial oxidation reactor configured to convert carbon monoxide and oxygen (typically from air) into carbon dioxide; and a methanation reactor configured to convert carbon monoxide and hydrogen into methane and water. The fuel treatment assembly 24 may include more than one type and / or number of chemical removal devices 48.

[0038] Pressure swing adsorption (PSA) is a chemical process that removes gaseous impurities from the output stream 34 based on the principle that certain gases, under appropriate temperature and pressure conditions, adsorb more strongly onto the adsorbent material than others. Typically, non-hydrogen impurities are adsorbed and removed from the output stream 34. Adsorption of the impurity gas occurs under increased pressure. When the pressure decreases, the impurities desorb from the adsorbent material, thereby regenerating the adsorbent material. PSA is typically a cyclic process requiring at least two beds for continuous (as opposed to batch) operation. Examples of suitable adsorbent materials for adsorption beds are activated carbon and zeolite. The PSA system 50 also provides examples of apparatus for the purification zone 40, in which byproducts or removed components are not directly discharged as a gas stream from the purification output stream. Instead, these byproduct components are removed during adsorbent material regeneration or otherwise removed from the purification zone.

[0039] exist Figure 1 In the diagram, purification zone 40 is shown within fuel processing assembly 24. Alternatively, the purification zone may be located separately downstream of the fuel processing assembly, such as... Figure 1 The dotted lines in the diagram are schematic. The purification zone 40 may also include portions within and outside the fuel processing assembly.

[0040] The fuel treatment assembly 24 may also include a temperature regulating assembly in the form of a heating assembly 52. ​​The heating assembly may be configured to generate at least one heated exhaust stream (or combustion stream) 54 from at least one heated fuel stream 28, typically for combustion in the presence of air. The heated exhaust stream 54... Figure 1 The heating assembly 52 is schematically illustrated as heating the hydrogen production zone 32. The heating assembly 52 may include any suitable structure configured to generate a heated exhaust stream, such as a burner or combustion catalyst that burns fuel with air to produce a heated exhaust stream. The heating assembly may include an igniter or ignition source 58 configured to initiate fuel combustion. Examples of suitable ignition sources include one or more spark plugs, glow plugs, combustion catalysts, ignition lamps, piezoelectric igniters, spark igniters, hot surface igniters, etc.

[0041] In some embodiments, the heating assembly 52 may include a burner assembly 60 and may be referred to as a combustion-based or combustion-driven heating assembly. In a combustion-based heating assembly, the heating assembly 52 may be configured to receive at least one fuel stream 28 and, in the presence of air, combust the fuel stream to provide a hot combustion stream 54. The hot combustion stream 54 may be used to at least heat the hydrogen production zone of the fuel processing assembly. Air may be delivered to the heating assembly via various mechanisms. For example, an air stream 62 may be delivered to the heating assembly as a separate stream, such as... Figure 1As shown. Alternatively or additionally, the airflow 62 may be delivered to the heating assembly together with at least one of the fuel flows 28 used for the heating assembly 52 and / or drawn from the environment used by the heating assembly.

[0042] The combustion stream 54 may additionally or alternatively be used to heat the fuel processing assembly and / or other parts of the fuel cell system used in conjunction with the heating assembly. Alternatively, other configurations and types of heating assemblies 52 may be used. For example, the heating assembly 52 may be an electrically driven heating assembly configured to generate heat using at least one heating element, such as a resistance heating element, to at least heat the hydrogen production zone 32 of the fuel processing assembly 24. In those embodiments, the heating assembly 52 may not receive and burn the combustible fuel stream to heat the hydrogen production zone to a suitable hydrogen production temperature. Examples of heating assemblies are disclosed in U.S. Patent No. 7,632,322, the entire disclosure of which is incorporated herein by reference for all purposes.

[0043] The heating assembly 52 may be housed together with the hydrogen generation zone and / or separation zone within a common housing or enclosure (as discussed further below). The heating assembly may be positioned separately relative to the hydrogen generation zone 32, but in thermal and / or fluid communication with that zone to provide at least the desired heating of that hydrogen generation zone. The heating assembly 52 may be partially or entirely located within the common housing, and / or at least a portion (or all) of the heating assembly may be located outside the housing. When the heating assembly is located outside the housing, hot combustion gases from the burner assembly 60 may be delivered to one or more components within the housing via suitable heat transfer conduits.

[0044] The heating assembly can also be configured to heat: feed delivery system 22, feed supply stream, hydrogen generation zone 32, purification (or separation) zone 40, or any suitable combination of these systems, streams, and zones. Heating the feed supply stream may include vaporizing components of a liquid reactant stream or a hydrogen-generating fluid used to generate hydrogen in the hydrogen generation zone. In this embodiment, fuel handling assembly 24 may be described as including vaporization zone 64. The heating assembly can be additionally configured to heat other components of the hydrogen generation assembly. For example, a heated discharge stream may be configured to heat pressure vessels and / or other tanks containing heated fuel and / or hydrogen-generating fluid that form at least a portion of feed stream 26 and fuel stream 28.

[0045] Heating assembly 52 can reach and / or maintain any suitable temperature in hydrogen production zone 32. Steam reformers typically operate in a temperature range of 200°C to 900°C. However, temperatures outside this range are also within the scope of this disclosure. When the carbonaceous feedstock is methanol, steam reforming reactions are typically carried out in a temperature range of approximately 200-500°C. Example subsets of this range include 350-450°C, 375-425°C, and 375-400°C. When the carbonaceous feedstock is hydrocarbons, ethanol, or another alcohol, a temperature range of approximately 400-900°C is typically used for steam reforming reactions. Example subsets of this range include 750-850°C, 725-825°C, 650-750°C, 700-800°C, 700-900°C, 500-800°C, 400-600°C, and 600-800°C. The hydrogen production zone 32 may include two or more regions or sections, each of which may operate at the same or different temperatures. For example, when the hydrogen-producing fluid includes hydrocarbons, the hydrogen production zone 32 may include two distinct hydrogen-producing sections or regions, one of which operates at a lower temperature than the other to provide a pre-reforming zone. In those embodiments, the fuel processing assembly may also be referred to as including two or more hydrogen production zones.

[0046] Fuel stream 28 may include any one or more flammable liquids and / or one or more gases suitable for consumption by the heating assembly 52 to provide the desired heat output. Some fuel streams may be gases when delivered and combusted by the heating assembly 52, while others may be delivered to the heating assembly as liquid streams. Examples of heating fuels for fuel stream 28 include carbonaceous feedstocks such as methanol, methane, ethane, ethanol, ethylene, propane, propylene, butane, etc. Other examples include low molecular weight condensable fuels such as liquefied petroleum gas, ammonia, light amines, dimethyl ether, and lightweight hydrocarbons. Yet another example includes hydrogen and carbon monoxide. In embodiments of hydrogen generation assembly 20 that include a temperature-regulating assembly in the form of a cooling assembly rather than a heating assembly (such as when using an exothermic hydrogen production process, for example, partial oxidation, instead of an endothermic process, such as steam reforming), the feedstock delivery system may be configured to supply a fuel or coolant stream to the assembly. Any suitable fuel or coolant may be used.

[0047] Fuel processing assembly 24 may additionally include a housing or enclosure 66, which contains at least a hydrogen production zone 32, such as Figure 1As shown. In some embodiments, the vaporization zone 64 and / or purification zone 40 may be additionally included within the housing. The housing 66 allows components of the steam reformer or other fuel treatment assembly to be moved as a unit. The housing may also protect components of the fuel treatment assembly from damage by providing a protective enclosure and / or reduce the heating requirements of the fuel treatment assembly because the components can be heated as a unit. The housing 66 may include an insulating material 68, such as a solid insulating material, a blanket insulating material, and / or an air-filled cavity. The insulating material may be inside the housing, outside the housing, or both. When the insulating material is outside the housing, the fuel treatment assembly 24 may also include an outer cover or sheath 70 outside the insulating material, such as... Figure 1 As illustrated schematically. The fuel processing assembly may include different housings that contain additional components of the fuel processing assembly, such as the feed delivery system 22 and / or other components.

[0048] One or more components of the fuel processing assembly 24 may extend beyond the housing or be located outside the housing. For example, the purification zone 40 may be located outside the housing 66, such as being spaced apart from the housing but fluidly connected via suitable fluid transfer conduits. As another example, a portion of the hydrogen production zone 32 (such as portions of one or more reforming catalyst beds) may extend beyond the housing, such as... Figure 1 The dashed lines in the diagram indicate alternative housing configurations. Examples of suitable hydrogen generation components and their parts are disclosed in U.S. Patent Nos. 5,861,137, 5,997,594, and 6,221,117, the full disclosure of which is incorporated herein by reference for all purposes.

[0049] Another example of hydrogen generation component 20 is as follows: Figure 2 As shown, and generally indicated by 72. Unless specifically excluded, hydrogen generation assembly 72 may include one or more components of hydrogen generation assembly 20. Hydrogen generation assembly 72 may include feed delivery system 74, vaporization zone 76, hydrogen production zone 78, heating assembly 80, and purification zone 82, as shown. Figure 2 As shown.

[0050] The feed delivery system may include any suitable structure configured to deliver one or more feed streams and / or fuel streams to one or more other components of the hydrogen generation assembly. For example, the feed delivery system may include a feed tank (or container) 84 and a pump 86. The feed tank may contain any suitable hydrogen-generating fluid 88, such as water and / or a carbonaceous feedstock (such as a methanol / water mixture). The pump 86 may have any suitable structure configured to deliver a hydrogen-generating fluid to a vaporization zone 76 and / or a hydrogen generation zone 78, which may be in the form of at least one liquid-containing feed stream 90 containing water and a carbonaceous feedstock. In some embodiments, the feed delivery system may be configured to deliver one or more feed streams 90 without the need for a pump and / or other electrically powered fluid delivery mechanism.

[0051] The vaporization zone 76 may include any suitable structure configured to receive and vaporize at least a portion of a liquid-containing feed stream, such as a liquid-containing feed stream 90. For example, the vaporization zone 76 may include a vaporizer 92 configured to at least partially convert the liquid-containing feed stream 90 into one or more vapor feed streams. In some embodiments, the vapor feed stream may include a liquid. Examples of suitable vaporizers are coiled tube vaporizers, such as coiled stainless steel tubes.

[0052] The hydrogen generation zone 78 may include any suitable structure configured to receive one or more feed streams to generate one or more output streams 96 comprising hydrogen as the majority component and other gases such as carbon dioxide, such as steam feed streams from one or more vaporization zones. The hydrogen generation zone may generate the output streams via any suitable mechanism. For example, the hydrogen generation zone 78 may generate one or more output streams 96 via a steam reforming reaction, an autothermal reforming reaction, or a partial oxidation reaction. When generating one or more output streams 96 via a steam reforming reaction, the hydrogen generation zone 78 may include a steam reforming zone 97 having a reforming catalyst 98 configured to facilitate and / or promote the steam reforming reaction. When the hydrogen generation zone 78 generates one or more output streams 96 via a steam reforming reaction, the hydrogen generation assembly 72 may be referred to as a "steam reforming hydrogen generation assembly," and the output stream 96 may be referred to as a "reformed stream."

[0053] The heating assembly 80 may include any suitable structure configured to generate at least one heated exhaust stream 99 for heating one or more other components of the hydrogen generation assembly 72. For example, the heating assembly may heat the vaporization zone to any suitable temperature(s), such as at least a minimum vaporization temperature or a temperature at which at least a portion of the liquid-containing feed stream vaporizes to form a vapor feed stream. Additionally or alternatively, the heating assembly 80 may heat the hydrogen generation zone to any suitable temperature(s), such as at least a minimum hydrogen generation temperature or a temperature at which at least a portion of the vapor feed stream reacts to produce hydrogen, thereby forming an output stream. The heating assembly may be in thermal communication with one or more components of the hydrogen generation assembly, such as the vaporization zone and / or the hydrogen generation zone.

[0054] like Figure 2 As shown, the heating assembly may include a burner assembly 100 and at least one blower 102. The burner assembly may include any suitable structure configured to receive at least one air stream 106 and at least one fuel stream 107 and to burn at least one fuel stream within a combustion zone 110 to produce a heated exhaust stream 99. The fuel stream may be provided by a feed delivery system 74 and / or a purification zone 82, as discussed further below. The combustion zone may be contained within an enclosure of the hydrogen generation assembly. The blower 102 may include any suitable structure configured to generate one or more air streams 106. In some embodiments, the heating assembly may include an igniter assembly (not shown) configured to ignite one or more fuel streams 107.

[0055] Purification zone 82 may include any suitable structure configured to generate at least one hydrogen-rich stream or product hydrogen stream 112, which may include a higher hydrogen concentration than output stream 96 and / or one or more other gases or impurities, such as carbon dioxide, present in a reduced concentration in the output stream. Purification zone may generate at least one byproduct stream 108, which contains a lower hydrogen concentration than output stream 96 and / or one or more other gases or impurities present in a reduced concentration. Purification zone 82 may include membrane module 114. In some embodiments, purification zone 82 may also include a methanation reactor assembly, such as downstream of the membrane module, for converting carbon monoxide and hydrogen into methane and water.

[0056] Membrane module 114 may include any suitable structure configured to receive one or more output streams or mixed gas streams 96 comprising hydrogen and other gases, and configured to generate one or more permeate streams or hydrogen-rich streams 112 comprising hydrogen at a higher concentration than the mixed gas stream and / or other gases at a lower concentration than the mixed gas stream. Membrane module 114 may incorporate planar or tubular hydrogen-permeable (or hydrogen-selective) membranes, and more than one hydrogen-permeable membrane may be incorporated into membrane module 114. One or more permeate streams may be used for any suitable application, such as for one or more fuel cells. In some embodiments, membrane module may generate at least one byproduct stream 108 comprising at least a substantial portion of other gases such as carbon dioxide. Although purification zone 82 is shown as including membrane module 114, purification zone may alternatively or additionally include one or more other components configured to purify output stream 96 and / or generate one or more product hydrogen streams and / or one or more byproduct streams.

[0057] In some embodiments, the hydrogen generation assembly 72 may include a housing or casing 120, which may at least partially contain one or more other components of the hydrogen generation assembly 72. For example, the housing 120 may at least partially contain a vaporization zone 76, a hydrogen generation zone 78, a heating assembly 80, and / or a purification zone 82, such as... Figure 2 As shown. The housing 120 may include one or more discharge ports 122 configured to discharge at least one combustion exhaust stream 124 generated by the heating assembly 80.

[0058] In some embodiments, the hydrogen generation assembly 72 may include a gas removal assembly 126 configured to separate at least a portion of carbon dioxide gas from the byproduct stream 108 to produce a fuel stream 128 with a carbon dioxide concentration lower than that of the byproduct stream and an exhaust stream 129 with a carbon dioxide concentration higher than that of the byproduct stream. The exhaust stream may be compressed and / or liquefied, stored as compressed gas, discharged into a pipeline, chemically converted into other compounds, etc. The fuel stream 128 may form all or part of a fuel stream 107 used or burned by the burner assembly 100. A flow restriction orifice 130 may restrict the flow of the fuel stream 128 to the burner assembly 100. The gas removal assembly 126 may include any suitable components discussed further below.

[0059] In some embodiments, the hydrogen generation assembly 72 may include a heat exchange assembly 136, which may include one or more heat exchangers 138 configured to transfer heat from one part of the hydrogen generation assembly to another. For example, the heat exchange assembly 136 may transfer heat from the byproduct stream 108 to the feed stream 90 to raise the temperature of the feed stream before it enters the vaporization zone 76, and to cool the byproduct stream 108.

[0060] An example of gas removal component 126 is shown in Figure 3 As shown in the diagram, and generally indicated by 184. Unless specifically excluded, gas removal assembly 184 may include one or more components of other gas removal assemblies described in this disclosure. Gas removal assembly 184 may include at least one gas separation assembly 186.

[0061] The gas separation assembly 186 may include any suitable structure configured to separate carbon dioxide gas from the byproduct stream 108 to produce a fuel stream 128 having a lower carbon dioxide gas concentration and / or an increased concentration of other gases compared to the byproduct stream 108. For example, the gas separation assembly 186 may include at least one absorber 194 configured to receive at least one chemical reagent or absorbent 196 adapted to absorb at least a portion of the carbon dioxide gas from the byproduct stream 108 via reversible chemical binding and / or physical dissolution.

[0062] The absorber is configured to receive absorbent 196 and direct byproduct stream 108 through the absorbent to absorb carbon dioxide gas from the byproduct stream. As used herein, “absorption” means that carbon dioxide gas is bound to or fixed by the absorbent through reversible or irreversible processes, including weak chemical bonding and / or physical solvation, and the bound carbon dioxide gas may involve surface interactions with the absorbent, extensive interactions with the absorbent, or both. Absorbent 196 may be in liquid, solid, or combination form. Suitable examples of absorbents for carbon dioxide include any chemical or mixture of chemicals that bind carbon dioxide, such as metal hydroxides (e.g., sodium hydroxide, potassium hydroxide, calcium hydroxide, magnesium hydroxide, etc.); metal oxides (e.g., sodium oxide, potassium oxide, calcium oxide, magnesium oxide, iron oxide, etc.); organic amines, especially alkanolamines (e.g., monoethanolamine and diethanolamine, which are liquids under normal temperature and pressure conditions); The solvent formulated for removing acidic gases (manufactured and marketed by Dow Chemical Company); an aqueous solution of metal hydroxide; (Thomas Scientific); CarboLime TM (Allied Health Products); soda lime (Airgas); immobilized organic amines (such as organic amines bound to a polymer matrix, especially polymer beads); dimethyl polyethylene glycol, propylene carbonate, polyethylene glycol dialkyl ethers (e.g., sold by Clariant). 1753); organic ionic liquids; mixtures of the above-mentioned chemicals and / or chemical reagents; and other reagents or mixtures of reagents that reversibly absorb carbon dioxide through weak chemical interactions and / or physical dissolution.

[0063] Compared to the byproduct stream 108, the fuel stream 128 exiting the absorber 194 may include carbon dioxide gas at a reduced concentration and / or other gases at a increased concentration. Preferably, the fuel stream includes less than 25% carbon dioxide, and more preferably less than 10% carbon dioxide. The absorber 194 can operate at pressures greater than 50 psig (pounds per square inch), and preferably at pressures between 100 psig and 500 psig.

[0064] When the absorbent 196 is in solid form, the absorber 194 may include two or more absorbent beds 197 and may be configured to direct the byproduct stream 108 to flow to the first of those absorbent beds. When the bed is nearly saturated with carbon dioxide, the absorber may be configured to direct the flow to another absorbent bed to allow for refilling and / or regeneration of the absorbent from the previous absorbent bed. When the absorbent 196 is in liquid form, the absorbent may be configured to absorb or bind carbon dioxide gas at a relatively low temperature, and then release or desorb (one or more) the gas at an elevated temperature. This process is called temperature-swing absorption or TSA (temperature-swing absorption). Alternatively, a carbon dioxide absorbent that binds carbon dioxide at high pressure and releases carbon dioxide at low pressure (also known as pressure-swing absorption) may be selected.

[0065] The gas separation assembly 186 may alternatively or additionally include a membrane contactor assembly 198, which may include one or more permeate membranes 200 (such as one or more carbon dioxide selective membranes). The membrane contactor assembly 198 may be configured to separate carbon dioxide gas from the byproduct stream 108. For example, the permeate membrane 200 may have relatively high permeability to carbon dioxide gas relative to other gases, thereby allowing carbon dioxide gas from the byproduct stream 108 to pass from the feed side of the permeate membrane to the permeate side.

[0066] The membrane contactor assembly 198 may be additionally configured to receive at least one liquid chemical agent or liquid absorbent 202, adapted to absorb at least a portion of the carbon dioxide gas separated from the byproduct stream 108 (such as carbon dioxide gas passing from the feed side of the permeate membrane to the permeate side). For example, the membrane contactor assembly may receive the absorbent on the permeate side of the permeate membrane 200. The liquid absorbent 202 may be configured to absorb or bind carbon dioxide gas at a relatively low temperature and then release or desorb one or more of the gas at an elevated temperature. Examples of suitable liquid absorbents include alkanolamines, such as monoethanolamine or diethanolamine, or aqueous solutions thereof. However, other organic amines, organic amine solutions, or solutions of inorganic hydroxide salts and / or organic hydroxide salts may be used.

[0067] When the gas separation assembly 186 includes one or more absorbers 194 and / or one or more permeation membranes 200 for receiving liquid absorbent, the gas separation assembly can generate at least one liquid absorbent stream 204 with absorbed carbon dioxide gas (which may also be referred to as a "depleted liquid absorbent stream" or a "gas-loaded liquid absorbent stream"). When a depleted liquid absorbent stream 204 is generated and the absorption of one or more gases in the stream is reversible, the gas removal assembly 184 may additionally include at least one gas extraction assembly 206.

[0068] The gas extraction assembly 206 may include any suitable structure configured to extract (or desorb) the absorbed gas from one or more liquid absorbent streams 204. For example, the gas extraction assembly 206 may include one or more strippers 208. In some embodiments, when the liquid absorbent comprises absorbed carbon dioxide gas, the gas extraction assembly may be configured to extract or desorb at least a substantial portion of the absorbed carbon dioxide gas to form a liquid absorbent stream (or stripped liquid absorbent stream) 210 that is at least substantially regenerated with at least a substantial portion of the carbon dioxide gas extracted, and an exhaust stream 212 having the extracted carbon dioxide gas.

[0069] The stripped liquid absorbent stream 210 may be pumped or otherwise delivered to the gas separation assembly 186 to additionally absorb carbon dioxide gas from the byproduct stream 108. Alternatively or additionally, the stripped liquid absorbent stream 210 may be stored for later use. The waste gas stream 212 may be pumped or otherwise delivered to one or more other components of the refining assembly, such as to supplement one or more heating fuel streams. Alternatively, the waste gas stream 212 may be stored, vented into the air, or otherwise disposed of.

[0070] The gas extraction assembly 206 can use any suitable mechanism to regenerate the liquid absorbent stream 204 containing the absorbed gas. When the liquid absorbent used in the gas separation assembly 186 is configured to absorb or bind carbon dioxide gas at a relatively low temperature and then release or desorb (one or more) of the gas(s) at an elevated temperature, the gas removal assembly 184 may also include at least one heating assembly 214. The heating assembly may be configured to generate at least one heated exhaust stream (or combustion stream) 216 from at least one heated fuel stream 218, typically for combustion in the presence of air. The heated exhaust stream 216... Figure 3 The diagram schematically shows a heated gas extraction assembly 206. The heated exhaust stream may alternatively or additionally heat the heat-depleted liquid absorbent stream 204 before the gas extraction assembly 206, as shown below. Figure 3 As shown in the image.

[0071] Heating assembly 214 may include any suitable structure configured to generate one or more heated exhaust streams, such as a burner or combustion catalyst for burning fuel with air to produce one or more heated exhaust streams. Heating assembly 214 may include an igniter or ignition source 220 configured to initiate fuel combustion. Heating assembly 214 may achieve and / or maintain any suitable temperature in and / or upstream of gas extraction assembly 206. For example, heating assembly 214 may heat gas extraction assembly to at least the target operating temperature and / or at least the minimum extraction or desorption temperature of the specific liquid absorbent used.

[0072] In some embodiments, the heating assembly 214 may include a burner assembly 222 and may be configured to receive at least one fuel stream 218 and burn the fuel stream in the presence of air to provide a combustion stream 216 that can be used to heat the gas removal reactor. Air may be delivered to the heating assembly via various mechanisms. For example, air stream 224 may be delivered to the heating assembly as a separate stream, such as... Figure 3 As shown. Alternatively or additionally, the airflow 224 may be delivered to the heating assembly together with at least one of the fuel flows 218 used for the heating assembly 214 and / or drawn from the environment used by the heating assembly.

[0073] Fuel stream 218 may include any one or more combustible liquids and / or one or more gases suitable for consumption by heating assembly 214 to provide a desired heat output. Some fuel streams may be gases when delivered and combusted by heating assembly 214, while others may be delivered to the heating assembly as liquid streams. Examples of suitable heating fuels for fuel stream 218 include carbonaceous feedstocks, low molecular weight condensable fuels, and low molecular weight hydrocarbons. Other examples include carbon dioxide gas from one or more byproduct streams 226. For example, one or more byproduct streams 226 from other parts and / or components of the fuel handling system may be used as suitable heating fuels for fuel stream 218. In some examples, at least a portion of fuel stream 128 is used for one or more byproduct streams 226.

[0074] Combustion stream 216 may be additionally or alternatively used to heat other parts of the fuel processing system and / or other systems used in conjunction with the heating assembly. Additionally, other configurations and types of heating assembly 214 may be used. For example, heating assembly 214 may be an electrically powered heating assembly configured to generate heat to heat gas extraction assembly 206 and / or upstream piping by using at least one heating element (such as a resistance heating element), one or more waste heat streams, solar heating, electric heating, etc. In these embodiments, heating assembly 214 may not receive and combust the combustible fuel stream to heat the vaporizer to a suitable vaporization temperature and / or heat the methanogenic reactor to a suitable methanogenic temperature.

[0075] The heating assembly can also be configured to heat other components and / or parts, such as feed delivery systems, feed supply streams, methane generation components and / or other components of purification components, or any suitable combination of these systems, streams and areas. The heating assembly can also be configured to heat other parts of the refining component. For example, a heated discharge stream can be configured to heat pressure vessels and / or other tanks containing heated fuel and / or hydrogen-generating fluids that form at least a portion of the feed and / or fuel stream of a fuel handling system.

[0076] Heating assembly 214 may be housed together with gas separation assembly and gas extraction assembly within an assembly housing or enclosure 227. The heating assembly may be positioned separately relative to one or both of these components, but is in thermal and / or fluid communication with one or both to provide desired heating. Heating assembly 214 may be partially or completely located within a common enclosure, and / or at least a portion (or all) of the heating assembly may be located outside the enclosure. When the heating assembly is located outside the enclosure, hot combustion gases from burner assembly 222 may be delivered to one or more components within the enclosure via suitable heat transfer conduits.

[0077] Despite the gas removal component 184 ( Figure 3(middle) and hydrogen production zone 78 and / or vaporization zone 76 ( Figure 2 The gas removal assembly 184, vaporization zone 76, and hydrogen generation zone are shown to all include heating components, but the gas removal assembly 184, vaporization zone 76, and hydrogen generation zone may share a common heating component, which may be located within housing 120, within the housing of one or more gas removal assemblies, or outside these housings. When a common heating component is present, the heating component may include suitable heat transfer conduits to transfer heat to components of the gas removal assembly, vaporization zone, and / or hydrogen generation zone. Additionally, when the gas extraction assembly 206 includes two or more strippers 208, the gas extraction assembly may include a common heating component 214 for the two or more strippers (and in some embodiments, for all strippers). Furthermore, although the gas removal assembly 184 is shown as including a single gas separation assembly 186, a single gas extraction assembly 206, and a single heating component 214, a gas removal assembly may include two or more gas separation assemblies, two or more gas extraction assemblies, and / or two or more heating components, such as... Figure 3 As shown by the dashed line in the image.

[0078] An example of gas removal component 184 is shown in Figure 4 As shown in the diagram and generally indicated by 350. Unless explicitly excluded, the gas removal assembly 350 may include one or more components of other gas removal assemblies and / or other assemblies described in this disclosure. The gas removal assembly 350 may include at least one absorber 352, at least one stripper 354, at least one heating assembly 356, at least one pump 358, and at least one heat exchanger 360.

[0079] The absorber 352 may include any suitable structure configured to receive a liquid absorbent stream 362 adapted to absorb at least a portion of carbon dioxide gas from the byproduct stream 108 and / or guide the byproduct stream 108 through the liquid absorbent stream. For example, the absorber 352 may include at least one nozzle 364 configured to atomize the liquid absorbent stream at least partially into one or more sprayed liquid absorbent streams 366. The absorber may be configured to guide the byproduct stream 108 through one or more sprayed liquid absorbent streams 366 in any suitable flow configuration such as countercurrent flow, crossflow, or parallel flow. As the byproduct stream 108 flows through one or more sprayed liquid absorbent streams, carbon dioxide gas may be at least partially absorbed by the sprayed streams to form a fuel stream 128 without absorbed carbon dioxide gas and a depleted liquid absorbent stream 368 with absorbed carbon dioxide gas. The absorber 352 can operate at pressures greater than 50 psig, and preferably at pressures between 100 psig and 500 psig.

[0080] Another suitable configuration is to return the liquid absorbent stream 362 to the absorber without using a nozzle. For example, the liquid absorbent stream 362 can be connected to the top, middle, or bottom portion of the absorber 352 via a suitable pipe or conduit, and the liquid absorbent can be allowed to accumulate to fill the volume at the bottom of the absorber. The byproduct stream 108 can be directed to bubble through the volume of liquid absorbent to remove at least a portion of the carbon dioxide gas, thereby forming the fuel stream 128.

[0081] Stripper 354 may include any suitable configuration configured to receive one or more depleted liquid absorbent streams 368, strip absorbed carbon dioxide gas from those streams(one or more), and / or deliver one or more stripped liquid absorbent streams 370 to absorber(one or more) absorbers 352. For example, stripper 354 may include at least one nozzle 372 configured to at least partially atomize the depleted liquid absorbent stream into one or more sprayed depleted liquid absorbent streams 374. Stripper 354 may strip the absorbed carbon dioxide gas via any suitable mechanism(one or more). For example, when the liquid absorbent(one or more) used for liquid absorbent stream 362 absorbs or binds carbon dioxide gas in a first temperature range and releases or desorbs carbon dioxide gas in a second temperature range above the first temperature range, stripper 354 may be configured to receive one or more heated exhaust streams 376 from heating assembly 356 and direct those streams through the sprayed depleted liquid absorbent streams(one or more).

[0082] For example, the depleted liquid stream(s) sprayed can be heated to between 60°C and 200°C, preferably between 80°C and 150°C, by one or more heated discharge streams to remove absorbed carbon dioxide gas, thereby producing or generating at least substantially regenerated liquid absorbent stream 370. The released or desorbed gas may form at least one exhaust gas stream 377. Stripper 354 can operate in the range of 0 psig to 50 psig, and preferably between 0 psig and 10 psig.

[0083] The heating assembly 356 may include any suitable structure configured to generate at least one heated discharge stream 376 for heating one or more sprayed depleted liquid absorbent streams 374. For example, the heating assembly may heat the stripper to any suitable temperature, such as at least the minimum release or desorption temperature of carbon dioxide gas in one or more sprayed depleted liquid absorbent streams.

[0084] The heating assembly 356 may include at least one heater 394 powered by at least one power supply assembly (not shown). The heater 394 may include at least one heating element 398 (such as a resistance heating element). The heating element may heat the depleted liquid absorbent stream 368 before the stripper 354 (and / or nozzle 372) and / or in the stripper. The power supply assembly may include one or more wires (to allow a user to plug the heater into a power outlet), a solar panel, a wind turbine, a fuel cell, etc.

[0085] Alternatively, other configurations and types of heating components 356 can be used. For example, such as... Figure 5 As shown, the heating assembly 356 may include a burner assembly 378, at least one blower 380, and an igniter assembly 382. The burner assembly may include any suitable structure configured to receive at least one air stream 384 and at least one fuel stream 386 and burn at least one fuel stream to produce one or more heated exhaust streams 376. The fuel streams may be provided by a feed delivery system 74, an absorber 352, and / or one or more other gas removal assemblies. Additionally, at least a portion of the exhaust gas stream 377 may be used as the byproduct fuel stream. One or more fuel streams 386 may be delivered to the burner assembly 378 via a pump and / or another suitable device. The blower 380 may include any suitable structure configured to generate one or more air streams 384. The igniter assembly 382 may include any suitable structure configured to ignite one or more fuel streams 386.

[0086] Pump 358 may be configured to deliver or convey the depleted liquid absorbent stream 368 to stripper 354 to desorb at least a portion of the absorbed carbon dioxide gas from the liquid absorbent stream, such as Figure 4 As shown. Alternatively, pump 358 may be configured to deliver or convey one or more stripped liquid absorbent streams 370 to absorb at least a portion of the carbon dioxide gas from byproduct stream 108, such as Figure 5 As shown. In some embodiments, the depleted and / or stripped liquid absorbent stream flows between the absorber and the stripper without the need for a pump and / or other electro-fluid delivery mechanism. The heat exchanger 360 may include any suitable structure configured to transfer heat from one or more stripped liquid absorbent streams to one or more depleted liquid absorbent streams.

[0087] In some embodiments, the gas removal assembly 350 may include a housing or enclosure 392, which may at least partially contain one or more other components of the assembly. For example, the housing 392 may at least partially contain an absorber 352, a stripper 354, a heating assembly 356, a pump 358, and / or a heat exchanger 360, such as... Figure 5As shown. The housing or enclosure may include insulation and / or a sheath. Alternatively, the gas removal assembly may be contained within a common housing or enclosure of other components of the fuel treatment assembly.

[0088] Another example of gas removal component 184 is in Figure 6 As shown in the diagram, and generally indicated by 400. Unless specifically excluded, gas removal assembly 400 may include one or more components of other gas removal assemblies described in this disclosure. For example, gas removal assembly 400 may include one or more absorbers 402.

[0089] Absorber 402 may include at least one solid absorbent 406 (such as in a solid absorbent bed) adapted to absorb at least a portion of carbon dioxide gas from byproduct stream 108 and / or guide byproduct stream 108 through the solid absorbent. As byproduct stream 108 flows through the solid absorbent, carbon dioxide gas may be at least partially absorbed, resulting in a fuel stream 128 without absorbed carbon dioxide gas. Gas removal assembly 400 may include any suitable number of absorbers 402. For example, gas removal assembly may include a first absorber 408 and a second absorber 410, such as... Figure 6 As shown. Although the second gas removal assembly 400 is shown as including two absorbers 402, the assembly may include any suitable number of absorbers, such as one absorber or three or more absorbers.

[0090] When the gas removal assembly 400 includes two or more absorbers 402, the gas removal assembly may include two or more control valves (not shown) and / or other structures to isolate one or more absorbers 402 and / or direct flow to one or more other absorbers 402. For example, byproduct stream 108 may be directed to flow through a first absorber 408 until the solid absorbent in that absorber is saturated or substantially saturated with carbon dioxide gas. At this time, the control valve may isolate the first absorber 408 and direct byproduct stream 108 to flow through a second absorber 410 until the solid absorbent in the second absorber is saturated or substantially saturated. While byproduct stream 108 is flowing through the second absorber, the solid absorbent in the isolated first absorber may be refilled or regenerated, or vice versa. In some embodiments, the gas removal assembly 400 may include a housing or enclosure 413, which may at least partially contain one or more other components of the assembly. For example, the housing 413 may at least partially contain the absorbers 402, such as Figure 6 As shown. The housing or enclosure may include insulation and / or a sheath. Alternatively, the gas removal assembly may be contained within a common housing or enclosure of other components of the fuel treatment assembly.

[0091] Another example of gas removal component 184 is in Figure 7As shown in the diagram and generally indicated by 414. Unless explicitly excluded, gas removal assembly 414 may include one or more components of other gas removal assemblies and / or other components as described in this disclosure. Gas removal assembly 414 may include membrane assembly 418.

[0092] Membrane module 418 may include any suitable structure configured to separate at least a portion of carbon dioxide gas from byproduct stream 108 to form fuel stream 128. The separated carbon dioxide gas may form exhaust gas stream 333. For example, membrane module 418 may include one or more carbon dioxide selective membranes 428 configured to separate at least a portion of carbon dioxide gas from byproduct stream 108. Membrane module 418 may include any suitable number of membranes 428, such as... Figure 7 As shown by the dashed lines. When membrane assembly 418 includes two or more membranes 428, these membranes may be arranged in parallel or in series. In some embodiments, gas removal assembly 414 may include a housing or enclosure 429, which may at least partially contain one or more other components of the assembly. For example, housing 429 may at least partially contain membrane assembly 418, such as... Figure 7 As shown. The housing or enclosure may include insulation and / or a sheath. Alternatively, the gas removal assembly may be contained within a common housing or enclosure of other components of the fuel treatment assembly.

[0093] Another example of gas removal component 184 is in Figure 8 As shown in the diagram and generally indicated by 430. Unless explicitly excluded, the gas removal assembly 430 may include one or more components of other gas removal assemblies and / or other components as described in this disclosure. The gas removal assembly 430 may include a membrane contactor assembly 434, at least one stripper 436, at least one heating assembly 438, at least one heat exchanger 440, and at least one pump 442.

[0094] The membrane contactor assembly 434 may include any suitable structure configured to separate carbon dioxide gas from the byproduct stream 108 to form the fuel stream 128. For example, the membrane contactor assembly 434 may include one or more membrane contactors 452. The membrane contactors may include a plurality of carbon dioxide selective membranes 454 configured to separate at least a portion of the carbon dioxide gas from the byproduct stream 108.

[0095] Membrane 454 can be a hollow fiber or small-diameter tubular membrane, which can be sealed (or packaged) into housing 456, such as Figure 9As shown. The housing 456 may include inlet and outlet ports 457 and any suitable number of membranes 454, such as hundreds to thousands of these membranes. The membranes 454 may have any suitable length, such as from about one centimeter to about two to three meters, and / or any suitable diameter, such as from 0.1 millimeters to 5 millimeters. The membranes may be configured to be microporous and / or highly permeable to carbon dioxide gas.

[0096] Membrane 454 may be composed of one or more materials that are chemically inert to the components of byproduct stream 108, whether these components are in the gas phase and / or liquid phase. Alternatively, when membrane 454 is microporous, the membrane may be composed of one or more materials that are not wetted by the liquid phase of the components of byproduct stream 108 and / or liquid absorbent stream 470. In other words, the liquid phase of these components will not be drawn into the microporous structure by capillary forces. Otherwise, if the microporous structure of the membrane is filled with liquid, the relatively slow diffusion of carbon dioxide gas from the liquid-filled pores may adversely affect the overall performance of the membrane. An example of a suitable microporous polypropylene membrane is... Manufactured by LLC (Charlotte, NC).

[0097] One or more membrane contactors 452 can guide the byproduct flow 108 through the orifices or lumens 458 of the membrane 454, such as Figure 10 As shown. At least a portion of the carbon dioxide gas can pass through one or more walls 460 into the membrane contactor housing, as... Figure 10 As shown in 462. When the byproduct stream 108 is directed to flow into and / or through the lumen 458 of the membrane 454, the interior of the lumen may be referred to as the "feed side 466", and the interior of the housing (and / or the exterior of the membrane) may be referred to as the "permeate side 468".

[0098] Alternatively, one or more membrane contactors may direct the byproduct stream 108 through the membrane contactor housing and / or over the membrane, as... Figure 11 As shown. At least a portion of the carbon dioxide gas can pass through one or more walls 460 into the lumen 458 of the membrane 454, as... Figure 11 As shown in section 464. When the byproduct stream 108 is directed to flow into and / or through the membrane contactor housing and / or over the membrane, the interior of the membrane contactor housing or the exterior of the membrane may be referred to as the "feed side 466," and the interior of the lumen may be referred to as the "permeate side 468." Preferably, when the lumen diameter is small and the membrane length is long, the byproduct stream 108 is directed to flow through the membrane lumen to prevent high pressure drops that would be encountered if the liquid absorbent stream 470 were directed to flow through the lumen.

[0099] Additionally, one or more membrane contactors 452 may receive at least one liquid absorbent flow 470 at the permeate side of the membrane. The liquid absorbent flow may be adapted to absorb at least a portion of the carbon dioxide gas passing from the feed side of the membrane 454 to the permeate side, forming one or more liquid absorbent flows 472 with the absorbed carbon dioxide gas (which may also be referred to as "one or more depleted liquid absorbent flows 472"). For example, when one or more membrane contactors 452 are configured to receive a byproduct flow 108 through the lumen 458 of the membrane 454, the membrane contactor may receive the liquid absorbent flow 470 within the membrane contactor housing 456. Alternatively, when one or more membrane contactors 452 are configured to receive a byproduct flow 108 through the membrane contactor housing 456, the membrane contactor may receive a liquid absorbent flow through the lumen 458 of the membrane 454. The liquid absorbent(s) in the liquid absorbent stream 470 may be configured to absorb (or bind) at least a portion of the carbon dioxide gas at a relatively low temperature, and then release (or desorb) those gases at an elevated temperature. Alternatively, the liquid absorbent(s) in the liquid absorbent stream 470 may be driven by a pressure cycle, in which case the absorption of carbon dioxide in the membrane contactor assembly 434 may be at a relatively high pressure of 50 to 100 psig, or particularly at a relatively high pressure of 100 to 500 psig, and the desorption in the stripper 436 may occur at a lower pressure.

[0100] Membrane contactor assembly 434 may include any suitable number of membrane contactors 452, such as Figure 8 As shown by the dashed lines. When the membrane contactor assembly 434 includes two or more membrane contactors 452, these membrane contactors can be arranged in parallel or in series.

[0101] Stripper 436 may include any suitable configuration configured to receive one or more depleted liquid absorbent streams 472, strip absorbed carbon dioxide gas from those streams(one or more), and / or deliver one or more stripped liquid absorbent streams 474 to one or more membrane contactors 452. For example, stripper 436 may include at least one nozzle 476 configured to at least partially atomize the depleted liquid absorbent stream into one or more sprayed depleted liquid absorbent streams 478. Stripper 436 may strip the absorbed carbon dioxide gas via any suitable mechanism(s). For example, when the liquid absorbent(s) used for liquid absorbent stream 470 absorbs or binds carbon dioxide gas in a first temperature range and releases or desorbs carbon dioxide gas in a second temperature range above the first temperature range, stripper 436 may be configured to receive one or more heated exhaust streams 480 from heating assembly 438 and direct those streams through the sprayed depleted liquid absorbent streams(s).

[0102] The depleted liquid stream from one or more sprays can be heated to between 60°C and 200°C, preferably between 80°C and 150°C, by one or more heated discharge streams to remove absorbed carbon dioxide gas and produce at least substantially regenerated liquid absorbent stream 474. The released or desorbed gas may form at least one exhaust gas stream 333. Stripper 436 can operate in the range of 0 psig to 50 psig, and most preferably in the range of 0 psig to 10 psig.

[0103] The heating assembly 438 may include any suitable structure configured to generate at least one heated exhaust stream 480 for heating one or more sprayed depleted liquid absorbent streams 478. For example, the heating assembly may heat the stripper to any suitable temperature, such as at least the minimum release or desorption temperature of carbon dioxide gas in one or more sprayed depleted liquid absorbent streams.

[0104] like Figure 8As shown, the heating assembly may include a burner assembly 484, at least one blower 486, and an igniter assembly 488. The burner assembly may include any suitable structure configured to receive at least one air stream 490 and at least one fuel stream 492 and burn at least one fuel stream to produce one or more heated exhaust streams 480. The fuel streams 492 may be provided by a feed delivery system 232, a membrane contactor assembly (such as from at least a portion of the fuel stream 128), and / or one or more gas removal assemblies. In some embodiments, at least a portion of the exhaust gas stream 333 may supplement the fuel streams 492. The fuel streams 492 may be delivered to the burner assembly 378 via one or more pumps and / or other suitable means. The blower 486 may include any suitable structure configured to generate one or more air streams 492. The igniter assembly 488 may include any suitable structure configured to ignite one or more fuel streams 492.

[0105] Alternatively, other configurations and types of heating components 438 may be used. For example, heating component 438 may include at least one heater 498 powered by at least one power supply component 500, such as... Figure 12 As shown. The heater 498 may include at least one heating element 502 (such as a resistance heating element). The heating element may heat the depleted liquid absorbent stream 472 before the stripper 436 (and / or nozzle 476) and / or in the stripper. The power supply assembly 500 may include one or more wires (to allow a user to plug the heater into a power outlet), a solar panel, a wind turbine, a fuel cell, etc.

[0106] The heat exchanger 440 may include any suitable structure configured to transfer heat from one or more stripped liquid absorbent streams to one or more depleted liquid absorbent streams. The pump 442 may include a suitable structure configured to deliver or convey one or more stripped liquid absorbent streams 474 to one or more membrane contactors 452 to additionally absorb carbon dioxide gas from the byproduct stream 108. In some embodiments, the depleted and / or stripped liquid absorbent streams flow between the absorber and stripper without the need for a pump and / or other electrofluid delivery mechanism.

[0107] In some embodiments, the gas removal assembly 430 may include a housing or enclosure 508, which may at least partially contain one or more other components of the assembly. For example, the housing 508 may at least partially contain a membrane contactor assembly 434, a stripper 436, a heating assembly 438, a heat exchanger 440, and / or a pump 442, such as... Figure 8 and 12As shown. In some embodiments, housing 508 may include insulation and / or a sheath. Alternatively, the gas removal assembly may be contained within a common housing or enclosure of other components of the fuel treatment assembly.

[0108] Gas removal assembly 184 may additionally or alternatively include one or more structures and / or components, such as those described in U.S. Patent No. 9,605,224, which is hereby incorporated by reference for all purposes. Although the gas removal assemblies of this disclosure are discussed as separating and / or removing carbon dioxide, those gas removal assemblies may also separate and / or remove carbon monoxide and / or other gases. Although the hydrogen generation assembly and gas removal assembly of this disclosure include streams delivered via pumps, one or more of these streams may be delivered without a pump, or vice versa.

[0109] An example of a method 600 for generating hydrogen is as follows: Figure 13 As shown. Although Figure 13 Specific steps are shown, but other examples of method 600 may omit, replace, modify, repeat, and / or add one or more steps. Furthermore, these steps may be performed in any suitable order.

[0110] At 602, one or more feed streams containing carbonaceous feedstock and / or water may be received in the fuel processing assembly. At 604, the hydrogen generation zone of the fuel processing assembly may be heated to at least the minimum hydrogen generation temperature, for example, via one or more burners.

[0111] At 606, one or more output streams can be generated from one or more feed streams in a heated hydrogen generation zone. The output streams may contain hydrogen, carbon dioxide, and one or more other gases. At 608, one or more product hydrogen streams and one or more byproduct streams can be generated from the one or more output streams in a purification zone of the fuel treatment assembly. The one or more product hydrogen streams may have a hydrogen concentration greater than that of the output streams and a carbon dioxide concentration less than that of the output streams. Additionally, the one or more byproduct streams may have a hydrogen concentration less than that of the output streams and a carbon dioxide concentration greater than that of the output streams. In some examples, the purification zone may include one or more hydrogen-selective membranes in which the product hydrogen streams are generated from the portions of the output streams that pass through the one or more hydrogen-selective membranes, and the byproduct streams are generated from the portions of the output streams that do not pass through the one or more hydrogen-selective membranes.

[0112] At point 610, at least a portion of the carbon dioxide gas can be separated or removed from one or more byproduct streams to generate one or more fuel streams. The carbon dioxide concentration of the fuel streams may be less than the carbon dioxide concentration of the byproduct streams. For example, at least a portion of the carbon dioxide can be absorbed from the byproduct streams by means of or via at least one absorbent, such as at least one solid absorbent or at least one liquid absorbent stream. In some examples, one or more depleted liquid absorbent streams or liquid absorbent streams containing absorbed carbon dioxide gas can be heated to strip at least a substantial portion of the absorbed carbon dioxide gas, thereby forming a stripped liquid absorbent stream and an exhaust stream containing the stripped carbon dioxide gas.

[0113] In other examples, one or more byproduct streams flow through one or more carbon dioxide selective membranes to remove carbon dioxide gas. At least a portion of the carbon dioxide gas passes from the feed side of the membrane to the permeate side to form one or more fuel streams, while the portion of the byproduct stream that does not pass through the membrane (i.e., does not pass from the feed side to the permeate side) forms an exhaust gas stream. In some examples, one or more liquid absorbent streams flow through the permeate side of one or more carbon dioxide selective membranes to produce a depleted liquid absorbent stream or one or more liquid absorbent streams containing absorbed carbon dioxide gas. In some examples, one or more depleted liquid absorbent streams or one or more liquid absorbent streams containing absorbed carbon dioxide gas may be heated to strip at least a substantial portion of the absorbed carbon dioxide gas to form a stripped liquid absorbent stream and an exhaust gas stream containing the stripped carbon dioxide gas. At 612, one or more fuel streams may be fed to one or more burners for combustion.

[0114] Some examples of method 600 may additionally or alternatively include one or more other steps. For example, at 614, the vaporization zone of the fuel processing assembly may be heated to at least a minimum vaporization temperature, such as via one or more burners. The burners used to heat the vaporization zone may be the same as or different from the one or more burners used to heat the hydrogen generation zone. Additionally, at 616, at least a portion of the feed stream(s) may be vaporized in the vaporization zone of the fuel processing assembly to form one or more at least substantially vaporized streams. When at least a portion of the feed stream(s) has been vaporized, the output stream generated at 606 may be generated at least partially from the at least substantially vaporized stream(s).

[0115] The hydrogen generation components and methods disclosed herein provide an efficient way to reduce carbon dioxide emissions generated when hydrogen is generated from carbonaceous feedstocks, such as from methanol. Alternatively, carbon dioxide can be removed from the combustion exhaust stream. However, the combustion exhaust stream has a relatively low carbon dioxide concentration, such as due to the dilution of the combustion gases in the case of excess air supplied for combustion, and at very low pressures.

[0116] In one example, a methanol / water mixture (62.5 wt% methanol / equilibrium water) at a flow rate of 1,575 L / min produced 1,396 std. L / min of product hydrogen with a lower heating value (LHV) energy efficiency of 83%. The byproduct stream from the purification zone was approximately 1.5 MPa to approximately 2.0 MPa and approximately 1.0 Nm. 3 The byproduct stream consists of approximately 25.7% hydrogen, 15.8% water, 1.8% methanol, 47.8% carbon dioxide, and 10% carbon monoxide. The byproduct stream reaches approximately 400°C and exits the heat exchanger at approximately 30°C. The feed stream enters the same heat exchanger at approximately 25°C and exits at approximately 195°C. The heat load of the heat exchanger is approximately 578 kJ / min. In comparison, with a carbon dioxide concentration of 19% to 22%, the combustion exhaust stream has a pressure of approximately 110 kPa and a thermal efficiency of approximately 3.2 Nm³. 3 / min. Industrial applicability

[0117] This disclosure includes hydrogen generation apparatus and components thereof, applicable to the fuel processing industry and other industries that purify, produce and / or utilize hydrogen.

[0118] The foregoing disclosure includes a number of different inventions with independent practical applicability. While each of these inventions is disclosed in its preferred form, the specific embodiments disclosed and described herein should not be considered limiting, as many variations are possible. The subject matter of this invention includes all novel and non-obvious combinations and sub-combinations of the various elements, features, functions, and / or characteristics disclosed herein. Similarly, where any claim refers to an element “a” or “first” or its equivalent, such a claim should be understood to include one or more such elements, neither requiring nor excluding two or more such elements.

[0119] Inventions embodied in various combinations and sub-combinations of features, functions, elements, and / or characteristics may be claimed by filing new claims in related applications. Such new claims, whether for different or the same invention, and whether they differ in scope, are broader, narrower, or the same as the original claims, are also considered to be included within the subject matter of this disclosure.

Claims

1. A method for generating hydrogen, comprising: A feed stream containing a carbon-containing feedstock is received in a fuel processing assembly. The hydrogen generation zone of the fuel processing assembly is heated at least to the minimum steam reforming temperature of the feed stream via one or more burners; An output stream comprising hydrogen and carbon dioxide gas is generated from the received feed stream via steam reforming in the heated hydrogen generation zone of the fuel processing assembly. In the purification zone of the fuel processing assembly, a product hydrogen stream and a byproduct stream are generated from the output stream, the product hydrogen stream having a higher hydrogen concentration and a lower carbon dioxide concentration than the output stream, and the byproduct stream having a lower hydrogen concentration and a higher carbon dioxide concentration than the output stream. At least a portion of the carbon dioxide gas is separated from the byproduct stream to generate a fuel stream with a carbon dioxide concentration lower than that of the byproduct stream; and The fuel stream is fed to the one or more burners.

2. The method of claim 1, wherein separating at least a portion of the carbon dioxide gas from the byproduct stream comprises absorbing the at least a portion of the carbon dioxide gas from the byproduct stream via at least one absorbent.

3. The method of claim 2, wherein absorbing the at least portion of the carbon dioxide gas comprises absorbing the at least portion of the carbon dioxide gas from the byproduct stream via at least one solid absorbent.

4. The method of claim 2, wherein absorbing the at least portion of the carbon dioxide gas from the byproduct stream comprises absorbing the at least portion of the carbon dioxide gas from the byproduct stream via a liquid absorbent stream.

5. The method of claim 4, wherein separating at least a portion of the carbon dioxide gas from the byproduct stream further comprises heating the liquid absorbent stream containing the absorbed carbon dioxide gas to strip at least a substantial portion of the absorbed carbon dioxide gas to form a stripped liquid absorbent stream and a waste gas stream containing the stripped carbon dioxide gas.

6. The method of claim 1, wherein separating at least a portion of the carbon dioxide gas from the byproduct stream comprises allowing the at least a portion of the carbon dioxide gas to pass from the feed side of at least one carbon dioxide selective membrane to the permeate side.

7. The method of claim 6, wherein separating at least a portion of the carbon dioxide gas from the byproduct stream further comprises flowing a liquid absorbent stream through the permeate side of the at least one carbon dioxide selective membrane to thereby generate a liquid absorbent stream having absorbed carbon dioxide gas.

8. The method of claim 7, wherein separating at least a portion of the carbon dioxide gas from the byproduct stream further comprises heating the liquid absorbent stream containing the absorbed carbon dioxide gas to strip at least a substantial portion of the absorbed carbon dioxide gas to form a stripped liquid absorbent stream and a waste gas stream containing the stripped carbon dioxide gas.

9. The method of claim 1, further comprising vaporizing at least a portion of the feed stream in the vaporization zone of the fuel processing assembly to form at least substantially vaporized stream, and wherein generating the output stream in the heated hydrogen generation zone comprises generating the output stream from the at least substantially vaporized stream in the heated hydrogen generation zone.

10. The method of claim 9, further comprising heating the vaporization zone of the fuel processing assembly to at least a minimum vaporization temperature via the one or more burners.

11. The method of claim 1, wherein the purification zone comprises at least one hydrogen-selective membrane, wherein generating a product hydrogen stream and a byproduct stream in the purification zone comprises generating the product hydrogen stream and the byproduct stream via the at least one hydrogen-selective membrane, and wherein the product hydrogen stream is generated from a portion of the output stream that passes through the at least one hydrogen-selective membrane, and the byproduct stream is generated from a portion of the output stream that does not pass through the at least one hydrogen-selective membrane.

12. A hydrogen generation assembly, comprising: Encapsulation shell; A hydrogen generation region contained within the encapsulation housing is configured to generate an output stream from at least one feed stream, the output stream comprising hydrogen and carbon dioxide gas as the majority components, the at least one feed stream comprising a carbon-containing raw material; A heating assembly configured to receive at least one air stream and at least one fuel stream, and to combust the at least one fuel stream within a combustion zone contained in the encapsulation housing, thereby generating a heated exhaust stream for heating the hydrogen production zone to at least the minimum hydrogen production temperature of the received at least one fuel stream; A purification zone contained within the encapsulation shell, the purification zone being configured to generate a product hydrogen stream and a byproduct stream, the product hydrogen stream having a higher hydrogen concentration and a lower carbon dioxide concentration than the output stream, and the byproduct stream having a lower hydrogen concentration and a higher carbon dioxide concentration than the output stream; and A gas removal assembly configured to separate at least a portion of carbon dioxide gas from the byproduct stream and thereby generate at least a portion of the at least one fuel stream.

13. The component of claim 12, wherein the gas removal component comprises at least one absorber configured to receive at least one solid absorbent adapted to absorb the at least a portion of the carbon dioxide gas from the byproduct stream, thereby generating the at least a portion of the at least one fuel stream.

14. The component of claim 12, wherein the gas removal component comprises at least one absorber configured to (a) receive a liquid absorbent stream adapted to absorb at least a portion of the carbon dioxide gas, and (b) guide the byproduct stream through the liquid absorbent stream.

15. The component of claim 14, wherein the gas removal component further comprises at least one stripper configured to (a) receive the liquid absorbent stream having absorbed carbon dioxide gas, (b) strip the carbon dioxide gas from the liquid absorbent stream to thereby form an exhaust gas stream, and (c) deliver the stripped liquid absorbent stream to the at least one absorber.

16. The assembly of claim 12, wherein the gas removal assembly comprises at least one carbon dioxide selective membrane having a feed side and a permeate side, the feed side being configured to receive the byproduct stream, the at least a portion of the carbon dioxide gas in the byproduct stream being configured to pass from the feed side to the permeate side, and the remaining portion of the byproduct stream retained on the feed side forming the at least a portion of the at least one fuel stream.

17. The component of claim 16, wherein the gas removal component comprises at least one absorber configured to (a) receive a liquid absorbent stream adapted to absorb at least a portion of the carbon dioxide gas passing from the feed side to the permeate side, and (b) guide the byproduct stream through the liquid absorbent stream.

18. The component of claim 17, wherein the gas removal component further comprises at least one stripper configured to (a) receive the liquid absorbent stream having absorbed carbon dioxide gas, (b) strip the carbon dioxide gas from the liquid absorbent stream to thereby form an exhaust gas stream, and (c) deliver the stripped liquid absorbent stream to the at least one absorber.

19. The component of claim 12, further comprising a vaporization zone contained within the package and configured to receive the at least one feed stream to form at least substantially vaporized stream, wherein the hydrogen generation zone is configured to generate the product hydrogen stream from the at least substantially vaporized stream.

20. The component of claim 19, wherein the heated exhaust stream is used to heat the vaporization zone to at least a minimum vaporization temperature and to heat the hydrogen production zone to the at least minimum hydrogen production temperature.

21. The component of claim 12, wherein the hydrogen generation region comprises a catalyst.

22. The component of claim 21, wherein the catalyst is a reforming catalyst.

23. The assembly of claim 12, wherein the purification zone comprises at least one hydrogen-selective membrane, and wherein the product hydrogen stream is generated by a portion of the output stream passing through the at least one hydrogen-selective membrane, and the byproduct stream is generated by a portion of the output stream not passing through the at least one hydrogen-selective membrane.

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