Processes and systems for separating carbon dioxide in the production of alkanes

Abstract

A method for separating CO.sub.2 from C.sub.2 to C.sub.5 alkanes includes introducing a first stream including C.sub.2 to C.sub.5 alkanes and CO.sub.2 into a first separation zone, the first separation zone including a hydrocarbon solvent, and separating the first stream into a recycle stream and a second stream in the first separation zone. The recycle stream including CO.sub.2 and one or more of CO, H.sub.2, and CH.sub.4, and the second stream including C.sub.2 to C.sub.5 alkanes. The method further includes introducing the second stream into a second separation zone, and separating the second stream into a third stream and a fourth stream, wherein the third stream includes C.sub.2 alkanes and the fourth stream includes C.sub.3 to C.sub.5 alkanes.

Claims

1. A method for separating CO.sub.2 from C.sub.2 to C.sub.5 alkanes, comprising: introducing a first stream comprising C.sub.2 to C.sub.5 alkanes and CO.sub.2 into a first separation zone, the first separation zone comprising a hydrocarbon solvent; separating the first stream into a recycle stream and a second stream in the first separation zone, wherein the recycle stream comprises CO.sub.2 and one or more of CO, H.sub.2, and CH.sub.4, and the second stream comprises C.sub.2 to C.sub.5 alkanes; introducing the recycle stream into a reaction zone; introducing the second stream into a second separation zone; and separating the second stream into a third stream and a fourth stream, wherein the third stream comprises C.sub.2 alkanes and the fourth stream comprises C.sub.3 to C.sub.5 alkanes.

2. The method of claim 1, wherein the method further comprises introducing at least a portion of the fourth stream into the first separation zone as the hydrocarbon solvent.

3. The method of claim 1, wherein a portion of the recycle stream is purged before the recycle stream is introduced into the reaction zone.

4. The method of claim 1, wherein a ratio of the hydrocarbon solvent to C.sub.2 to C.sub.5 alkanes in the first separation zone is from 1:1 to 5:1.

5. The method of claim 1, wherein the first stream is a feed stream that is introduced from a reaction zone into the first separation zone.

6. The method of claim 1, wherein the third stream further comprises CO.sub.2, and the method further comprises introducing the third stream to a CO.sub.2 separator where a purge amount of CO.sub.2 separated from the third stream.

7. The method of claim 1, wherein the method further comprises removing a purge amount of CO.sub.2 from the first stream before it is introduced into the first separation zone.

8. The method of claim 6, wherein removing the purge amount of CO.sub.2 comprises introducing a stream comprising CO.sub.2 into a CO.sub.2 separator that comprises an amine solvent, and isolating the purge amount of CO.sub.2 in the amine solvent.

9. The method of claim 8, wherein the method further comprises: introducing the amine solvent and the purge amount of CO.sub.2 into a CO.sub.2 stripper that strips the purge amount CO.sub.2 from the amine solvent thereby forming a stripped amine solvent, and introducing the stripped amine solvent into the CO.sub.2 separator.

10. The method of claim 1, wherein the fourth stream comprises C.sub.3 alkanes and C.sub.4 to C.sub.5 alkanes.

11. The method of claim 1, wherein the recycle stream comprises CH.sub.4.

Description

BRIEF DESCRIPTION OF THE DRAWINGS

(1) FIG. 1 schematically depicts a conventional system for separating CO.sub.2 in the production of alkanes;

(2) FIG. 2 schematically depicts a first system for separating CO.sub.2 in the production of alkanes according to one or more embodiments disclosed and described herein; and

(3) FIG. 3 schematically depicts a second system for separating CO.sub.2 in the production of alkanes according to one or more embodiments disclosed and described herein.

DETAILED DESCRIPTION

(4) Reference will now be made in detail to embodiments of processes and systems for separating CO.sub.2 in the production of alkanes. Whenever possible, the same reference numerals will be used throughout the drawings to refer to the same or like parts. In one embodiment, A method for separating CO.sub.2 from C.sub.2 to C.sub.5 alkanes includes introducing a first stream including C.sub.2 to C.sub.5 alkanes and CO.sub.2 into a first separation zone, the first separation zone including a hydrocarbon solvent, and separating the first stream into a recycle stream and a second stream in the first separation zone. The recycle stream including CO.sub.2 and one or more of CO, H.sub.2, and CH.sub.4, and the second stream including C.sub.2 to C.sub.5 alkanes. The method further includes introducing the second stream into a second separation zone, and separating the second stream into a third stream and a fourth stream, wherein the third stream includes C.sub.2 alkanes and the fourth stream includes C.sub.3 to C.sub.5 alkanes. The third stream comprises C.sub.2 alkanes, and the fourth stream comprises C.sub.3 to C.sub.5 alkanes. In another embodiment, a system for separating CO.sub.2 from C.sub.2 to C.sub.5 alkanes includes a first separation zone comprising a hydrocarbon solvent and that is configured to separate a first stream comprising C.sub.2 to C.sub.5 alkanes and CO.sub.2 into a recycle stream and a second stream, and a second separation zone, which is fluidly connected to the first separation zone, and that is configured to separate the second stream into a third stream and a fourth stream. The recycle stream includes CO.sub.2 and one or more of CO, H.sub.2, and CH.sub.4, and the second stream includes C.sub.2 to C.sub.5 alkanes. The third stream includes C.sub.2 alkanes and the fourth stream includes C.sub.3 to C.sub.5 alkanes.

(5) As used herein, the term “light alkanes” refers to C.sub.2 to C.sub.5 alkanes, including, but not limited to, ethane, propane, n-butane, isobutane, pentane, isopentane, and neopentane.

(6) The scheme used to separate and control the recycle streams, including separation of the CO.sub.2 in the various streams, will impact reactor composition, reactor flow, CO conversion, CO.sub.2 production or conversion across the reactor, and reactor productivity. Conventional methods for removing CO.sub.2 from a gas stream include using polar solvents to trap CO.sub.2, but leave the other light gases in the gas stream. Such methods include: using methanol as a solvent (e.g., Rectisol® process); using di-methyl ethers of polyethylene glycol (e.g., Selexol™ process); using amine components, such as, for example, monoethanlamine (MEA), diethanolamine (DEA), or methyl diethanolamine (MDEA), in water (e.g., Ucarsol™ process); using potassium carbonate in water (e.g., Benfield™ process); and using caustic wash systems. However, in each of these systems CO.sub.2 is the main constituent of the product stream, and the CO.sub.2 is removed from the product stream before other components are separated. The CO.sub.2 that has been removed is generally purged from the system in conventional CO.sub.2 separation systems.

(7) With reference now to FIG. 1, a conventional CO.sub.2 separation system 100, such as a system for using one of the above-described processes, will be described. A reaction zone 110 converts a gas stream (not shown) into a feed stream 111 comprising light alkanes and CO.sub.2. In embodiments, the feed stream 111 also comprises one or more of CO, H.sub.2, and methane. The reactions that occur in the reaction zone 110 are not limited and may be any conventional reactions that form the desired light alkanes and CO.sub.2 as a byproduct. Such reactions include, for example, the conversion of syngas to light alkanes using a hybrid catalyst in a reactor. In some embodiments, the hybrid catalyst comprises a methanol synthesis component and a solid microporous acid component. In other embodiments, different conventional reactions may be used to form light alkanes and CO.sub.2 as a byproduct. It should be understood that, in embodiments, the reaction zone 110 may include any number of reactors. For instance, in some embodiments, the reaction zone 110 may comprise a first reactor for converting raw gases—such as, for example, methane or natural gas—into syngas, and the reaction zone 110 may comprise a second reactor—such as, for example, a reactor containing the above-described hybrid catalyst—for converting the syngas into light alkanes and a CO.sub.2 byproduct. Accordingly, in one or more embodiments, the reaction zone 110 includes any necessary reactors for converting raw gas streams into feed stream 111 that comprises light alkanes and CO.sub.2.

(8) The feed stream 111 is sent from the reaction zone 110 to a CO.sub.2 scrubber 120 that is fluidly connected to the reaction zone 110, a demethanizer 140, and a stripper 130. The CO.sub.2 scrubber 120 comprises a solvent that isolates CO.sub.2 from the other components of the feed stream 111—such as, for example, light alkanes and, optionally, one or more of CO, H.sub.2, and CH.sub.4. Any conventional solvent for isolating CO.sub.2 may be used. For example, the solvent may comprise one or more of methanol, di-methyl ethers of polyethylene glycol, an aqueous solution comprising amine components (such as, for example, MEA, DEA, or MDEA), or an aqueous solution comprising potassium carbonate. Once the CO.sub.2 has been isolated from the other components of the feed stream 111, the CO.sub.2 exits the scrubber 120 as CO.sub.2 solvent stream 121 that comprises CO.sub.2 and the solvent described above. The CO.sub.2 solvent stream 121 is sent to a stripper 130 that is fluidly connected to the scrubber 120. Similarly, the other components of the feed stream 111 that have been isolated from CO.sub.2 (such as, for example, light alkanes and, optionally, one or more of CO, H.sub.2, and CH.sub.4) exit the scrubber 120 as a first product stream 122. The first product stream 122 is sent from the scrubber 120 to a demethanizer 140. It should be understood that any conventional scrubber suitable for scrubbing CO.sub.2 from the feed stream 111 may be used as the scrubber 120.

(9) The demethanizer 140 is fluidly connected to the scrubber 120 and the reaction zone 110. An optional first splitter 150 may be positioned between, and fluidly connected to, the demethanizer 140 and the reaction zone 110. At the demethanizer 140, the first product stream 122 is separated into a final product stream 141 that comprises light alkanes and a recycle stream 142 that comprises one or more of H.sub.2, CO, and CH.sub.4. Any conventional type of demethanizer that is capable of separating light alkanes from other components in the first product stream 122 may be used as the demethanizer 140. The final product stream 141 exits the conventional CO.sub.2 separation system and may be used in various chemical processes. The recycle stream 142 is sent from the demethanizer 140 to the reaction zone 110 where the components of the recycle stream 142 can be used as reactants in the reaction zone 110. In embodiments, the demethanizer 140 is operated at a temperature of from −80° C. to −60° C., such as about −70° C., and at a pressure from 25 bar (2500 kPa) to 35 bar (3500 kPa), such as about 30 bar (3000 kPa).

(10) In some embodiments, the recycle stream 142 may comprise inert gases, such as, for example, nitrogen or argon, which, in some embodiments, may be present in the feed stream 111. In such embodiments, an optional first splitter 150 may be fluidly connected to the demethanizer 140 and the first reaction zone 110 such that the recycle stream 142 passes through the first splitter 150. At the first splitter 150, a portion of the recycle stream 142 is removed from the conventional CO.sub.2 separation system 100 as an inert gas containing stream 151. The remainder of the recycle stream 142 exits the first splitter 150 as a second recycle stream 152 and is sent to the reaction zone 110. In embodiments, a portion of the recycle stream 142 is withdrawn from the process to prevent inert build-up and the remaining portion of stream 142 is sent directly from the demethanizer 140 to the reaction zone 110. In one or more embodiments, the recycle stream 142, the inert gas containing stream 151, and the second recycle stream 150 have the same composition. It should be understood that any conventional device that can separate gas stream 142 into two streams and regulate the flow of gaseous stream 142 in each of the two streams may be used as the first splitter 150.

(11) As stated above, the CO.sub.2 solvent stream 121 is sent from the scrubber 120 to the stripper 130. The stripper 130 is fluidly connected to the scrubber 120 and a second splitter 160. At the stripper 130 the CO.sub.2 solvent stream 121 is stripped to form a lean solvent and gaseous CO.sub.2. This stripping of the CO.sub.2 solvent stream 121 can be conducted by any conventional method, and is not limited herein. The solvent that remains after the CO.sub.2 has been stripped therefrom exits the stripper 130 as a solvent stream 132 and is returned to the scrubber 120 where it can again be used as a solvent to separate CO.sub.2 from the feed stream 111. Similarly, the gaseous CO.sub.2 that has been stripped from the CO.sub.2 solvent stream 121 exits the stripper 130 as CO.sub.2 stream 131 and is sent to a second splitter 160 that is fluidly connected to the stripper 130. It should be understood that any conventional stripper suitable for stripping CO.sub.2 from the type of solvent used in the conventional CO.sub.2 separation system 100 may be used as the stripper 130. Conventionally CO.sub.2 separation from the solvent is achieved by adding energy to the process. This means adding heat or energy to the process stream. At higher temperatures, part of the solvent may also evaporate, but it can be recovered using condensation at low temperature. In embodiments, process heat, such as steam, and cooling, such as cooling water, are used for this process.

(12) The second splitter 160 is fluidly connected to the stripper 130 and the reaction zone 110. At the second splitter 160 the gaseous CO.sub.2 stream is split into a CO.sub.2 purge stream 161 that exits the conventional CO.sub.2 separation system 100 and a CO.sub.2 recycle stream 162 that is sent back to the reaction zone 110. It should be understood that the amount CO.sub.2 that is purged from the conventional CO.sub.2 separation system 100 as CO.sub.2 purge stream 161 and the amount of CO.sub.2 that is sent back to the reaction zone 110 is not limited and will be determined base on the need for CO.sub.2 at the reaction zone 110. It should be understood that any conventional device that can separate gaseous CO.sub.2 into two streams and regulate the flow of gaseous CO.sub.2 in each of the two streams may be used as the second splitter 160.

(13) The above method provides for recycling CO.sub.2 (such as by CO.sub.2 recycle stream 162) to be used in the reaction zone 110. However, there are inefficiencies with conventional CO.sub.2 separation systems, such as the one described above. One inefficiency is that a large amount of CO.sub.2 must be removed. For instance, in many systems the mass ratio of CO.sub.2 to alkane at the outlet of the reaction zone 110 is greater than one. When the CO.sub.2 to alkane ratio is greater than one, more than one pound of CO.sub.2 must be removed for every pound of alkanes, which requires a large amount of energy per pound of alkane produced. Another inefficiency of the conventional CO.sub.2 separation systems, such as those described above, is that the CO.sub.2 recycle stream 162 that exits the stripper 130 and is sent back to the reaction zone 110 is at a low pressure, so it needs to be compressed before it can be used in the reaction zone 110, which requires additional capital investment and energy.

(14) In view of the above inefficiencies of conventional CO.sub.2 separation systems, it is desirable to separate H.sub.2, CO, CO.sub.2, and CH.sub.4 into one stream and light alkanes into another stream. This separation scheme is not easily achieved because ethane (i.e., C.sub.2 alkane) and CO.sub.2 have an azeotrope and cannot be separated by simple distillation. However, systems and methods for separating CO.sub.2 during the preparation of alkanes according to embodiments disclosed and described below can achieve this preferred separation scheme.

(15) With reference now to FIG. 2, systems and methods for separating CO.sub.2 during alkane preparation using a two column distillation according to one or more embodiments is described. In the embodiments of CO.sub.2 separation systems 200 shown in FIG. 2, a small amount of CO.sub.2 (i.e., a purge amount of CO.sub.2) is removed from the feed stream 111 in a CO.sub.2 separator 210 before the process stream 212 comprising light alkanes is introduced into a first separation zone 230. However, unlike the conventional CO.sub.2 separation systems described in reference to FIG. 1 above, in the CO.sub.2 separation system 200 according to embodiments shown in FIG. 2, the process stream 212 that enters the first separation zone 230 comprises a significant amount of CO.sub.2. In one or more embodiments, the process stream 212 comprises from 5 mass % to 40 mass % CO.sub.2, such as from 10 mass % to 35 mass % CO.sub.2, from 15 mass % to 30 mass % CO.sub.2, or from 20 mass % to 25 mass % CO.sub.2. In the embodiments of CO.sub.2 separation systems depicted in FIG. 2, CO.sub.2 is primarily separated from the light alkanes, including ethane, in the first separation zone 230 using a hydrocarbon solvent. Details of the CO.sub.2 separation systems 200 and methods according to embodiments depicted in FIG. 2 are described below.

(16) In one or more embodiments, the CO.sub.2 separation system 200 comprises a reaction zone 110 that is the same as the reaction zone 110 described above in reference to the conventional CO.sub.2 separation systems as discussed above. A feed stream 111 that comprises light alkanes, CO.sub.2 and one or more of H.sub.2, CO, and CH.sub.4 is sent from the reaction zone 110 to a CO.sub.2 separator 210 that is fluidly connected to the reaction zone 110 and a CO.sub.2 stripper 220. According to embodiments, in the CO.sub.2 separator 210, the feed stream 111 is mixed with an amine solvent, such as, for example MEA, DEA, MDEA, or mixtures thereof, that isolates a small amount of CO.sub.2 from the remaining components of the feed stream 111, such as, for example, light alkanes, CO, H.sub.2, and CH.sub.4. The amount of amine solvent and reaction conditions in the CO.sub.2 separator 210 are selected, in various embodiments, such that only a small amount of CO.sub.2 is isolated in the CO.sub.2 separator 210.

(17) The amount of CO.sub.2 that is isolated by the amine solvent is, in one or more embodiments, an amount of CO.sub.2 that is desired to be purged from the CO.sub.2 separation system 200. The desired amount of CO.sub.2 that is desired to be purged from the CO.sub.2 separation system 200 is, in some embodiments, based on the amount of CO.sub.2 that is to be recycled back to the reaction zone 110. Although not limited to any particular theory, the amount of CO.sub.2 co-produced with light alkanes in the reaction zone 110 may depend on the combination of reactors and processes used in the reaction zone 110. It should be understood that it may also depend on the H.sub.2:CO molar ratio used in the synthesis of light alkanes in reaction zone 110. In one or more embodiments, the molar H.sub.2:CO ratio is from 1:1 to 10:1 such as from 7:1 to 9:1, or about 8:1. In some embodiments, the molar H.sub.2:CO ratio is from 3:1 to 5:1, or about 3:1. In embodiments, a CO.sub.2 solvent stream 211 comprising the purge amount of CO.sub.2 and the amine solvent exits the CO.sub.2 separator 210 and is sent to the CO.sub.2 stripper 220. At the CO.sub.2 stripper 220, the CO.sub.2 in the CO.sub.2 solvent stream 211 is extracted from the amine solvent and purged from the CO.sub.2 separation system 200 as CO.sub.2 purge 221. In various embodiments, after the CO.sub.2 has been extracted from the CO.sub.2 solvent stream 211, the amine solvent is sent from the CO.sub.2 stripper 220 to the CO.sub.2 separator 210 as solvent stream 222. It should be understood that in one or more embodiments, the CO.sub.2 stripper 220 is any conventional extractor that is capable of extracting CO.sub.2 from an amine solvent.

(18) As discussed above, according to one or more embodiments, a process stream 212 that comprises light alkanes, CO.sub.2, and one or more of CO, H.sub.2, and CH.sub.4 is sent from the CO.sub.2 separator 210 to the first separation zone 230. The first separation zone 230 is fluidly connected to the CO.sub.2 separator 210, the reaction zone 110, and a second separation zone 240. In the first separation zone 230, according to various embodiments, the light alkanes in the process stream 212 are separated from CO.sub.2 and one or more of CO, H.sub.2, and CH.sub.4 that are present in the process stream 212. In some embodiments, this separation may be conducted by any suitable process. However, in one or more embodiments, the first separation zone 230 is a combined demethanizer/extractive distillation column that separates light alkanes from CO.sub.2 and one or more of CO, H.sub.2, and CH.sub.4. In one or more embodiments, the separation zone 230 comprises a hydrocarbon solvent for separating the light alkanes from CO.sub.2 and one or more of CO, H.sub.2, and CH.sub.4. In embodiments, the hydrocarbon solvent may be C.sub.3 to C.sub.5 alkanes that are recycled from the second separator 240 as described in more detail below. A light alkane stream 231 that comprises C.sub.2 to C.sub.5 alkanes exits the first separation zone 230 and is sent to the second separation zone 240. A recycle stream 232 comprising CO.sub.2 and one or more of CO, H.sub.2, and CH.sub.4 exits the first separation zone 230 and is sent back to the reaction zone 110.

(19) In some embodiments, the recycle stream 232 may comprise inert gases, such as, for example, nitrogen or argon, which, in some embodiments, may be present in the feed stream 111. In such embodiments, an optional first splitter 260 may be fluidly connected to the first separation zone 230 and the reaction zone 110 such that the recycle stream 232 passes through the first splitter 260. At the first splitter 260, a portion of the recycle stream 232 is removed from the CO.sub.2 separation system 200 as an inert gas containing stream 261. The remainder of the recycle stream 232 exits the first splitter 260 as a second recycle stream 262 and is sent to the reaction zone 110. In embodiments, a portion of the recycle stream 232 is withdrawn from the process to prevent inert build-up and the remaining portion of stream 232 is sent directly from the first separation zone 230 to the reaction zone 110 as the second recycle stream 262. In one or more embodiments, the recycle stream 232, the inert gas containing stream 261, and the second recycle stream 262 have the same composition. It should be understood that any conventional device that can separate gas stream 232 into two streams and regulate the flow of gaseous stream 232 in each of the two streams may be used as the first splitter 260.

(20) As discussed above, in embodiments, a light alkane stream 231 exits the first separation zone 230 and is sent to the second separation zone 240. The second separation zone 240 is, in embodiments, fluidly connected to the first separation zone 230 and a second splitter 250. In the second separation zone 240, the light alkanes are separated into a first product stream 241 comprising C.sub.2 alkanes and a second product stream 242 that comprises C.sub.3 to C.sub.5 alkanes. In some embodiments, the first product stream 241 comprises from 10 mass % to 90 mass % C.sub.2 alkanes, such as from 20 mass % to 80 mass % C.sub.2 alkanes, from 30 mass % to 70 mass % C.sub.2 alkanes, or from 30 mass % to 60 mass % C.sub.2 alkanes. In one or more embodiments, the first product stream 241 consists essentially of C.sub.2 to C.sub.3 alkanes. This separation of the light alkanes into the first product stream 241 that comprises C.sub.2 alkanes and the second product stream 242 that comprises C.sub.3 to C.sub.5 alkanes may, in various embodiments, be completed by any known separation method, such as, for example distillation. In one or more embodiments, the second product stream 242 comprises from 30 mass % to 95 mass % C.sub.3 to C.sub.5 alkanes, such as from 40 mass % to 90 mass % C.sub.3 to C.sub.5 alkanes, from 50 mass % to 90 mass % C.sub.3 to C.sub.5 alkanes, or from 60 mass % to 85 mass % C.sub.3 to C.sub.5 alkanes. The first product stream 241 exits the CO.sub.2 separation system 200 and can be used as products or starting materials in other chemical processing. In some embodiments, the second product stream 242 exits the second separation zone 240 and is sent to the second splitter 250 that is fluidly connected to the second separation zone 240 and the first separation zone 230.

(21) According to one or more embodiments, the second product stream 242 is split at the second splitter 250 into a third product stream 251 and a hydrocarbon solvent stream 252. In embodiments, the second product stream 242 is physically split into the third product stream 251 and the hydrocarbon solvent stream 252 and, thus, the third product stream 251 has the same composition as the hydrocarbon solvent stream 252. In one or more embodiments, the third product stream 251 exits the CO.sub.2 separation system 200 and can be used as products or starting materials in other chemical processing. The hydrocarbon solvent stream 252, which comprises C.sub.3 to C.sub.5 alkanes, is sent back to the first separation zone 230, where, in one or more embodiments, it is used as a solvent to separate the process stream 212 into the recycle stream 232—that comprises CO.sub.2 and one or more of CO, H.sub.2, and CH.sub.4—and light alkane stream 231. It should be understood that, in embodiments, any splitter capable of separating the second product stream 242 into two streams may be used as the second splitter 250.

(22) As discussed above, in some embodiments, the hydrocarbon solvent stream 252 exits the second splitter 250 and is sent to the first separation zone 230 where it is used as a solvent to separate process stream 212 into light alkane stream 231 and recycle stream 232. In embodiments, the amount of hydrocarbon solvent 252 that is directed to the first separation zone 230 is an amount such that the weight ratio of hydrocarbon solvent in the first separation zone 230 to the light alkanes in the first separation zone 230 is from 1:1 to 5:1, such as from 1:1 to 3:1, or from 2:1 to 3:1.

(23) With reference now to FIG. 3, further embodiments of systems and methods for separating CO.sub.2 during alkane preparation using a two column distillation are described. In the embodiments of CO.sub.2 separation systems 300 shown in FIG. 3, the feed stream 111 is fed directly to the first separation zone 230 without removing any CO.sub.2 from the feed stream 111. Details of the CO.sub.2 separation systems 300 and methods according to embodiments depicted in FIG. 3 are described below.

(24) In one or more embodiments, the CO.sub.2 separation system 300 comprises a reaction zone 110 that is the same as the reaction zone 110 described above in reference to the conventional CO.sub.2 separation systems depicted in FIG. 1 and the CO.sub.2 separation systems depicted in FIG. 2. In some embodiments, a feed stream 111 that comprises light alkanes, CO.sub.2 and one or more of H.sub.2, CO, and CH.sub.4 is sent from the reaction zone 110 to a first separation zone 230. The first separation zone 230 is fluidly connected to the reaction zone 110 and a second separation zone 240. In the first separation zone 230, according to various embodiments, the light alkanes in the feed stream 111 are separated from the CO.sub.2 and one or more of CO, H.sub.2, and CH.sub.4 that are present in the feed stream 111. In embodiments, this separation may be conducted by any suitable process. However, in one or more embodiments, the first separation zone 230 is a combined demethanizer/extractive distillation column that separates light alkanes from CO.sub.2 and one or more of CO, H.sub.2, and CH.sub.4. In some embodiments, the first separation zone 230 comprises a hydrocarbon solvent for separating the light alkanes from CO.sub.2 and one or more of CO, H.sub.2, and CH.sub.4. In embodiments, the hydrocarbon solvent may be C.sub.3 to C.sub.5 alkanes that are recycled from the second separation zone 240 as described in more detail below. In various embodiments, a second process stream 233 that comprises C.sub.2 to C.sub.5 alkanes and a small amount of CO.sub.2 exits the first separation zone 230 and is sent to the second separation zone 240. A recycle stream 232 comprising CO.sub.2 and one or more of CO, H.sub.2, and CH.sub.4 exits the first separation zone 230 and is sent back to the reaction zone 110.

(25) In some embodiments, the recycle stream 232 may comprise inert gases, such as, for example, nitrogen or argon, which may be introduced by the feed stream 111. In such embodiments, an optional first splitter 260 may be fluidly connected to the first separation zone 230 and the reaction zone 110 such that the recycle stream 232 passes through the first splitter 260. At the first splitter 260, a portion of the recycle stream 232 is removed from the CO.sub.2 separation system 300 as an inert gas containing stream 261. The remainder of the recycle stream 232 exits the first splitter 260 as a second recycle stream 262 and is sent to the reaction zone 110. In embodiments, a portion of the recycle stream 232 is withdrawn from the process to prevent inert build-up and the remaining portion of the recycle stream 232 is sent directly from the first separation zone 230 to the reaction zone 110 as the second recycle stream 262. In one or more embodiments, the recycle stream 232, the inert gas containing stream 261, and the second recycle stream 262 have the same composition. It should be understood that any conventional device that can separate the recycle stream 232 into two streams and regulate the flow of the recycle stream 232 in each of the two streams may be used as the first splitter 260.

(26) As stated above, in embodiments, a second process stream 233 exits the first separation zone 230 and is sent to the second separation zone 240. The second separation zone 240 is, in embodiments, fluidly connected to the first separation zone 230 and a second splitter 250. In the second separation zone 240, the light alkanes in the second process stream 233 are separated into a third process stream 243—that comprises C.sub.2 alkanes and a small amount of CO.sub.2 (i.e., a purge amount of CO.sub.2)—and a second product stream 242 that comprises C.sub.3 to C.sub.5 alkanes. This separation of the light alkanes into the third process stream 243 and the second product stream 242 may, in various embodiments, be completed by any known separation method, such as, for example distillation. The third process stream 243 exits the second separation zone 240 and is sent to the CO.sub.2 separator 210. The second product stream 242 exits the second separation zone 240 and is sent to the second splitter 250 that is fluidly connected to the second separation zone 240 and the first separation zone 230.

(27) According to embodiments, at the second splitter 250 the second product stream 242 is split into a third product stream 251 and a hydrocarbon solvent stream 252. In one or more embodiments, the second product stream 242 comprises from 30 mass % to 95 mass % C.sub.3 to C.sub.5 alkanes, such as from 40 mass % to 90 mass % C.sub.3 to C.sub.5 alkanes, from 50 mass % to 90 mass % C.sub.3 to C.sub.5 alkanes, or from 60 mass % to 85 mass % C.sub.3 to C.sub.5 alkanes. In embodiments, the second product stream 242 is physically split into the third product stream 251 and the hydrocarbon solvent stream 252 and, thus, the third product stream 251 has the same composition as the hydrocarbon solvent stream 252. The third product stream 251 exits the CO.sub.2 separation system 300 and can be used as products or starting materials in other chemical processing. The hydrocarbon solvent stream 252, which comprises C.sub.3 to C.sub.5 alkanes, is sent back to the first separation zone 230, where, in one or more embodiments, it is used as a hydrocarbon solvent to separate the feed stream 111 into the recycle stream 232—that comprises CO.sub.2 and one or more of CO, H.sub.2, and CH.sub.4—and second process stream 233. It should be understood that, in embodiments, any splitter capable of separating the second product stream 242 into two streams may be used as the second splitter 250.

(28) As discussed above, in some embodiments, the hydrocarbon solvent stream 252 exits the second splitter 250 and is sent to the first separation zone 230 where it is used as a solvent to separate feed stream 111 into the second process stream 233 and recycle stream 232. In embodiments, the amount of hydrocarbon solvent 252 that is directed to the first separation zone 230 is an amount so that the weight ratio of hydrocarbon solvent in the first separation zone 230 to the amount of light alkanes in the first separation zone 230 is from 1:1 to 5:1, such as from 1:1 to 3:1, or from 2:1 to 3:1.

(29) As discussed above, in one or more embodiments, the third process stream 243 exits the second separation zone 240 and is sent to the CO.sub.2 separator 210 that is fluidly connected to the second separation zone 240 and a CO.sub.2 stripper 220. In one or more embodiments, the third process stream 243 comprises from 5 mass % to 40 mass % CO.sub.2, such as from 10 mass % to 35 mass % CO.sub.2, from 15 mass % to 30 mass % CO.sub.2, or from 20 mass % to 25 mass % CO.sub.2. According to embodiments, in the CO.sub.2 separator 210, the third process stream 243 is mixed with an amine solvent, such as, for example MEA, DEA, MDEA, or mixtures thereof, that isolates the small amount of CO.sub.2 (i.e., the purge amount of CO.sub.2) remaining in the third process stream 243. The amount of amine solvent and reaction conditions in the CO.sub.2 separator 210 are selected, in various embodiments, such that only the small amount of CO.sub.2 is isolated in the CO.sub.2 separator 210. As described above, the desired amount of CO.sub.2 that is to be purged from the CO.sub.2 separation system 300 is, in some embodiments, based upon the amount of CO.sub.2 that is to be recycled back to the reaction zone 110. Namely, in embodiments, the amount of CO.sub.2 that is to be recycled back to the reaction zone 110 is included in recycle stream 232. Thus, any difference between the amount of CO.sub.2 in the feed stream 111 and the desired amount that is included in the recycle stream 232 is sent to the CO.sub.2 separator 210 to be isolated by the amine solution and ultimately purged from the CO.sub.2 separation system.

(30) In embodiments, a CO.sub.2 solvent stream 211 comprising the purge amount of CO.sub.2 and the amine solvent exits the CO.sub.2 separator 210 and is sent to the CO.sub.2 stripper 220. At the CO.sub.2 stripper 220, the CO.sub.2 in the CO.sub.2 solvent stream 211 is stripped from the amine solvent and purged from the CO.sub.2 separation system 300 as CO.sub.2 purge 221. In various embodiments, after the CO.sub.2 has been stripped from the CO.sub.2 solvent stream 211, the amine solvent is sent from the CO.sub.2 stripper 220 to the CO.sub.2 separator 210 as solvent stream 222. It should be understood that in one or more embodiments, the CO.sub.2 stripper 220 is any conventional stripper that is capable of stripping CO.sub.2 from an amine solvent.

(31) According to one or more embodiments, a fourth product stream 213 that comprises C.sub.2 alkanes exits the CO.sub.2 separator 210 and the CO.sub.2 separation system 300 where it can be used as a product or starting materials for various chemical processes. In some embodiments, the fourth product stream 213 comprises from 10 mass % to 90 mass % C.sub.2 alkanes, such as from 20 mass % to 80 mass % C.sub.2 alkanes, from 30 mass % to 70 mass % C.sub.2 alkanes, or from 30 mass % to 60 mass % C.sub.2 alkanes. In one or more embodiments, the fourth product stream 213 consists essentially of C.sub.2 to C.sub.3 alkanes.

(32) The systems and method for separating CO.sub.2 in the preparation of alkanes according to embodiments disclosed and described herein reduce the energy required to separate CO.sub.2 from the alkane-containing product stream. Because only a small amount of CO.sub.2 is absorbed into the solvent to isolate the CO.sub.2 from the light alkanes, only a small fraction of the energy required in conventional CO.sub.2 separation systems. Further, the recycle stream, which comprises CO.sub.2, described in embodiments herein is pressurized, thus no, or very little, compression of the recycle stream is required before it is introduced into the reaction zone 110.

EXAMPLES

(33) Embodiments will be further clarified by the following examples, which were simulated using Aspen simulation software.

Example 1

(34) A gas feed containing H.sub.2, CH.sub.4, CO, CO.sub.2, ethane, propane, butane, and pentane was separated into three streams using two columns. A portion of CO.sub.2, which must be removed from the system, was separated before a first separation zone. For this example, the CO2 purge rate was 16,400 kg/hr. The first column was a distillation column with a solvent feed on the top tray. The overhead gas stream product for recycle back to the reactor contained H.sub.2, CO, CO.sub.2, and CH.sub.4. The remaining products were separated into two streams by distillation. The overhead product stream contained C.sub.2 and some C.sub.3. A portion of the tails stream was used as the solvent to the first column, and the remainder was the tails product containing C.sub.3, C.sub.4, and C.sub.5. The specifics of the distillation columns are provided in Table 1:

(35) TABLE-US-00001 TABLE 1 Column 1 (Extractive Distillation) Number of Trays 52 Feed Tray 35 Solvent Feed Tray 1 Column 2 Number of Trays 35 Feed Tray 10

(36) The reflux rates and heat loads on column 1 and column 2 are provided in Table 2:

(37) TABLE-US-00002 TABLE 2 Column 1 Reflux Rate 186,284 kg/hr Q.sub.condenser1 −32.6 MMBtu/hr Q.sub.reboiler1 46.7 MMBtu/hr Column 2 Reflux Rate 80,000 kg/hr Q.sub.condenser2 −28.4 MMBtu/hr Q.sub.reboiler2 27.0 MMBtu/hr

(38) Table 3 below provides mass balance for all the streams of Example 1. The streams described in Table 3 are as follows: D1 is the overhead flow from column 1; B1 is the bottoms flow from column 1 and the feed to column 2; D2 is the overhead flow from column 2; B2 is the bottoms flow from column 2; B2 product is the portion of B2 taken out as product; B2 recycle is the solvent feed to column 1. The total alkane production rate was about 36,600 kg/hr.

(39) TABLE-US-00003 TABLE 3 Mass Balance for all Streams for Example 1 Solvent Gas Feed (B2 B2 Feed recycle) D1 B1 D2 B2 product Temp, ° C. 30.9 −11.4 −39.6 98.6 31.6 109.8 109.8 P, bar.sub.g 33.5 33.5 33.5 33.5 27.6 27.6 27.6 flow, kg/hr 114,359 100,000 77,773 136,586 23,658 112,927 12,927 Total Flow 5692 1854 4807 2739 645 2094 240 kmol/hr Composition in mole fraction H.sub.2 0.4568 0.0000 0.5408 0.0000 0.0000 0.0000 0.0000 CO 0.0469 0.0000 0.0555 0.0000 0.0000 0.0000 0.0000 CO.sub.2 0.1964 0.0000 0.2312 0.0024 0.0104 0.0000 0.0000 CH.sub.4 0.1275 0.0000 0.1510 0.0000 0.0000 0.0000 0.0000 C.sub.2H.sub.6 0.0630 0.0018 0.0032 0.1265 0.5311 0.0018 0.0018 C.sub.3H.sub.8 0.0842 0.4531 0.0158 0.4539 0.4564 0.4531 0.4531 C.sub.4H.sub.10-01 0.0184 0.3866 0.0022 0.2960 0.0021 0.3866 0.3866 C.sub.5H.sub.12-01 0.0068 0.1585 0.0002 0.1212 0.0000 0.1585 0.1585

(40) The energy requirement for the separation can be calculated on a fuel gas equivalent basis. For this comparison, energy for steam and electrical generation must be put on a consistent basis. The efficiency for converting fuel gas to steam is selected to be at 85%. The cooling requirement must be converted to the electrical power needed to perform the cooling, which depends on the cooling temperature. A relationship between cooling temperature and electrical power is taken from Hall, “Rules of Thumb for Chemical Engineers”, p. 194, Chapter 11. Selected values are given in Table 4 below.

(41) TABLE-US-00004 TABLE 4 HP/Ton T, ° C. Refrigeration −17.8 1.75 −40.0 3.01 −51.1 3.79 −73.3 5.69 −95.6 8.18
In addition, the electrical power must be converted to a fuel gas equivalent. For this analysis, the efficiency for converting fuel gas to electrical energy is selected as 34%.

(42) Energy Requirement

(43) TABLE-US-00005 Cooling Power Fuel Gas Cooling Temp, Duty Requirement Equivalent, ° C. MMBtu/hr kw/(MMBtu/hr) MMBtu/yr −39.6 C. −32.6 187 61
For CO2 removal, the energy requirement basis is assumed to be 2 GJ/ton CO.sub.2, or 860 Btu/lb. This is taken from Straelen, and Geuzebroek, “The Thermodynamic minimum regeneration energy required for post-combustion CO.sub.2 capture”, ScienceDirect, 2010. The energy breakdown in terms of fuel gas equivalent in given in Table 5 below.

(44) TABLE-US-00006 TABLE 5 Fuel Gas Equivalent Energy in MMBtu/hr Refrigeration 61 CO.sub.2 Removal 31 Reboiler 1 54 Reboiler 2 32 Total Energy 178 Unit Energy, Btu/lb alkane 2240 Btu/lb alkane product

Example 2

(45) In this example, the portion of CO.sub.2 that was removed from the reaction loop was included in the feed to the first distillation column. This CO.sub.2 leaves the first column in the tails with the other C.sub.2+ alkane components, and ends up in the second column product.

(46) The reflux rates and heat loads on column 1 and column 2 are provided in Table 6:

(47) TABLE-US-00007 TABLE 6 Column 1 Reflux Rate 177,294 kg/hr Q.sub.condenser1 −29.7 MMBtu/hr Q.sub.reboiler1 27.8 MMBtu/hr Column 2 Reflux Rate 42,000 kg/hr Q.sub.condenser2 −23.0 MMBtu/hr Q.sub.reboiler2 31.8 MMBtu/hr

(48) The mass balance for all streams is given in Table 7. The streams in Table 7 have the same designations as the streams in Table 3 of Example 1.

(49) TABLE-US-00008 TABLE 7 Mass Balance for all Streams for Example 2 Gas Solvent B2 Feed Feed D1 B1 D2 B2 product Temp, ° C. 30.5 −10.5 −38.0 64.0 0.6 109.1 109.1 P, bar.sub.g 33.5 33.5 33.5 33.5 27.6 27.6 27.6 flow, kg/hr 131,236 100,000 78,534 152,703 39,604 113,082 13,082 Total Flow 6075 1860 4824 3111 1008 2103 243 kmol/hr mole fraction H.sub.2 0.4280 0.0000 0.5390 0.0000 0.0000 0.0000 0.0000 CO 0.0439 0.0000 0.0553 0.0000 0.0000 0.0000 0.0000 CO.sub.2 0.2454 0.0000 0.2318 0.1198 0.3696 0.0000 0.0000 CH.sub.4 0.1195 0.0000 0.1504 0.0002 0.0005 0.0000 0.0000 C.sub.2H.sub.6 0.0590 0.0018 0.0032 0.1113 0.3400 0.0018 0.0018 C.sub.3H.sub.8 0.0803 0.4629 0.0176 0.4063 0.2882 0.4629 0.4629 C.sub.4H.sub.10-01 0.0174 0.3791 0.0024 0.2568 0.0017 0.3791 0.3791 C.sub.5H.sub.12-01 0.0064 0.1562 0.0002 0.1056 0.0000 0.1562 0.1562

(50) Table 8 below provides the energy requirements for Example 2, which were calculated in the same manner as provided above in Example 1.

(51) TABLE-US-00009 TABLE 8 Cooling Power Fuel Gas Cooling Temp, Duty Requirement Equivalent, C. MMBtu/hr kw/(MMBtu/hr) MMBtu/yr −38 C. −29.7 180 54 0. −22.9 62 14

(52) For CO.sub.2 removal, the energy requirement basis is assumed to be 860 Btu/lb CO.sub.2. The energy breakdown in terms of fuel gas equivalent in given in Table 9 below.

(53) TABLE-US-00010 TABLE 9 Fuel Gas Equivalent Energy in MMBtu/hr Refrigeration 68 CO.sub.2 Removal 31 Reboiler 1 33 Reboiler 2 37 Total Energy 169 Unit Energy, Btu/lb alkane 2116 Btu/lb alkane product

(54) This case gives a slightly higher refrigeration cost due to the lower overhead temperature of column D2, but reduced reboiler cost for the first column. The net result is slightly lower energy cost/lb alkane product.

COMPARATIVE EXAMPLE

(55) In this Comparative Example, a conventional separation system, such as the system shown in FIG. 1 was used. For this Comparative Example, all CO.sub.2, (i.e., 65,600 kg/hr), was removed from the feed gas. A portion of the CO.sub.2, 16,400 kg/hr, was purged from the process, and the remainder was compressed and recycled back to the reactor. The remaining gas stream after the CO.sub.2 removal was cooled in steps to −100° C. The condensed liquid was fed to a demethanizer distillation column, which separated the C.sub.2+ alkanes in the tails, and the overhead contained CH.sub.4, CO, and some H.sub.2. The design specifications on the column were 0.0001 mass purity CH.sub.4 in the tails and 0.005 mass purity ethane in the overhead, which were met by controlling the reflux ratio and the distillate to feed (D/F) ratio.

(56) The uncondensed gas feed contained mostly H.sub.2 (73%), CH.sub.4 (18%), CO (7.3%), and C.sub.2H.sub.6 (1.9%). The ethane concentration was reduced further by expanding this stream through a turboexpander for cooling, and feeding the condensed product back to the column. The cold gas stream was used to cool the feed. The gas stream, containing H.sub.2, CH.sub.4, and CO was compressed back to reactor pressure for recycle, and the overall recycle composition was the same as in Example 1.

(57) Results of the energy balance are given below in Table 10 below:

(58) TABLE-US-00011 TABLE 10 Fuel Gas Equivalent Energy in MMBtu/hr Refrigeration 38 CO.sub.2 Removal 124 CO.sub.2 Compression 42 Recycle Gas Compression 40 Column Reboiler 14 Total Energy 259 Unit Energy, Btu/lb alkane 3252 Btu/lb alkane product

(59) This Comparative Example shows the increased energy usage of about 53% used in a conventional CO.sub.2 removal system compared to the CO.sub.2 removal system of Example 1 and 45% more energy used in the conventional CO.sub.2 removal system compared to the CO.sub.2 removal system of Example 2. In addition, the conventional CO.sub.2 removal system was required to be about 4 times bigger due to a 4 times higher CO.sub.2 removal rate. This conventional approach also requires compression of both the recycled CO.sub.2 and the recycled H.sub.2-rich stream, which requires additional capital.

(60) It will be apparent to those skilled in the art that various modifications and variations can be made to the embodiments described herein without departing from the spirit and scope of the claimed subject matter. Thus it is intended that the specification cover the modifications and variations of the various embodiments described herein provided such modification and variations come within the scope of the appended claims and their equivalents.