Advanced oxidative coupling of methane

Description

BACKGROUND

The modern refining and petrochemical industry makes extensive use of fractionation technology to produce and separate various desirable compounds from crude oil. The conventional fractionation technology is energy intensive and costly to install and operate. Cryogenic distillation has been in use for over a hundred years to separate and recover hydrocarbon products in various refining and petrochemical industries. However, there is a need for non-cryogenic separation methods and systems, particularly for oxidative coupling of methane (OCM) processes.

SUMMARY

Aspects of the present disclosure provide processes for recovering olefins from a stream containing mix of hydrocarbons by utilizing techniques based the use of adsorbents. In some embodiments, systems and methods enable the separation, pre-separation, purification and/or recovery of hydrocarbons, including, but not limited to, olefins, ethylene, propylene, methane, and ethane, and CO₂, from a multicomponent hydrocarbon stream such as an effluent stream from an oxidative coupling of methane (OCM) reactor or an ethylene-to-liquids (ETL) reactor. The hydrocarbon stream can also be the feed to the OCM or ETL reactor in certain cases. In certain cases, the feed to the ETL reactor is the effluent from OCM reactor. In some cases, a separation process utilizing adsorbents can be used to purify and pre-treat existing hydrocarbon streams (such as refinery off-gases, cracker off-gas, streams from NGL plants, and others), followed by use of the resulting olefin rich stream (e.g., PSA tail gas) as the ETL feed.

The present disclosure provides various improvements in OCM and ETL processes, such as, without limitation, a separation and pre-separation process to recover desired or predetermined components from an OCM reactor effluent, CO₂recovery and capture techniques, enhanced heat recovery methods to utilize the OCM reaction heat more efficiently, and techniques and technologies to further reduce the carbon footprint of the OCM process.

An aspect of the present disclosure provides a method for generating higher hydrocarbon(s) from a stream comprising compounds with two or more carbon atoms (C₂₊), comprising introducing methane and an oxidant (e.g., O₂) into an oxidative coupling of methane (OCM) reactor that has been retrofitted into a system comprising an ethylene-to-liquids (ETL) reactor. The OCM reactor reacts the methane with the oxidant to generate a first product stream comprising the C₂₊compounds. The first product stream can then be directed to a pressure swing adsorption (PSA) unit that recovers at least a portion of the C₂₊compounds from the first product stream to yield a second product stream comprising the at least the portion of the C₂₊compounds. The second product stream can then be directed to the ETL reactor. The higher hydrocarbon(s) can then be generated from the at least the portion of the C₂₊compounds in the ETL reactor.

In some cases, the first product stream is directed to other intermediate units before the PSA, such as a post-bed cracking (PBC) unit that generates alkenes from alkanes. The alkenes can be included in the first product stream, which can then be directed to the PSA.

In an aspect, the present disclosure provides a method for generating higher hydrocarbon(s) from a stream comprising compounds with two or more carbon atoms (C₂₊), comprising: (a) introducing methane and an oxidant into an oxidative coupling of methane (OCM) reactor that has been retrofitted into a system comprising an ethylene-to-liquids (ETL) reactor, where the OCM reactor reacts the methane with the oxidant to generate a first product stream comprising the C₂₊compounds; (b) directing the first product stream to a pressure swing adsorption (PSA) unit that recovers at least a portion of the C₂₊compounds from the first product stream to yield a second product stream comprising the at least the portion of the C₂₊compounds; (c) directing the second product stream to the ETL reactor; and (d) generating the higher hydrocarbon(s) from the at least the portion of the C₂₊compounds in the ETL reactor.

In some embodiments, the method further comprises: (e) recovering a light stream comprising (i) hydrogen and (ii) carbon monoxide (CO) and/or carbon dioxide (CO₂) from the PSA unit and recycling the light stream to the OCM reactor; (f) directing at least a portion of the light stream into a methanation unit that reacts the hydrogen and the CO and/or CO₂to produce a methanation product stream comprising methane; and (g) directing the methanation product stream into the OCM reactor.

In some embodiments, the method further comprises recovering C₂and/or C₃compounds from the second product stream and directing the C₂and/or C₃compounds to the OCM reactor. In some embodiments, the OCM reactor further comprises a post-bed cracking (PBC) unit.

In some embodiments, the product stream is directed into the separations system through one or more additional units.

In some embodiments, the method further comprises separating methane from the product stream for use in the refrigeration unit. In some embodiments, the method further comprises directing CO and/or CO₂from the product stream to a methanation reactor that reacts the CO and/or CO₂to yield a methanation product stream comprising methane. In some embodiments, the method further comprises directing at least a portion of the methane in the methanation product stream to the OCM reactor. In some embodiments, the method further comprises separating the product stream into (i) an ethylene product stream comprising ethylene and (ii) a C₃₊product stream comprising compounds with three or more carbon atoms (C₃₊compounds). In some embodiments, the method further comprises directing ethane from the product stream to the OCM reactor. In some embodiments, the method further comprises prior to directing the product stream into the separations system, compressing the product stream.

In another aspect, the present disclosure provides a method for generating compounds with two or more carbon atoms (C₂₊compounds), comprising: (a) directing oxygen (O₂) and methane (CH₄) into an oxidative coupling of methane (OCM) reactor that reacts the O₂and CH₄in an OCM process to yield a product stream comprising (i) C₂₊compounds including ethylene (C₂H₄) and (ii) carbon monoxide (CO) and/or carbon dioxide (CO₂); and (b) directing the product stream from the OCM reactor into a separations system that employs a complexation unit having a complexation catalyst that forms pi complexes with the ethylene in the product stream, to enrich the C₂₊compounds in the product stream.

In some embodiments, the product stream is directed into the separations system through one or more additional units. In some embodiments, the method further comprises using the complexation unit to remove one or more impurities from the product stream, where the impurities are selected from the group consisting of CO₂, sulfur compounds, acetylenes, and hydrogen. In some embodiments, the complexation catalyst includes one or more metals selected from the group consisting of silver and copper. In some embodiments, the method further comprises directing CO and/or CO₂from the product stream to a methanation reactor that reacts the CO and/or CO₂to yield a methanation product stream comprising methane. In some embodiments, the method further comprises directing the methane in the methanation product stream to the OCM reactor. In some embodiments, the method further comprises separating the product stream into (i) an ethylene product stream comprising ethylene and (ii) a C₃+ product stream comprising compounds with three or more carbon atoms (C₃₊compounds). In some embodiments, the method further comprises directing ethane from the product stream to the OCM reactor. In some embodiments, the method further comprises prior to directing the product stream into the separations system, compressing the product stream.

In another aspect, the present disclosure provides a method for generating compounds with two or more carbon atoms (C₂₊compounds), comprising: (a) directing oxygen (O₂) and methane (CH₄) into an oxidative coupling of methane (OCM) reactor that reacts the O₂and CH₄in an OCM process to yield a product stream comprising (i) C₂₊compounds including ethylene (C₂H₄) and (ii) carbon dioxide (CO₂); and (b) directing the product stream from the OCM reactor into a separations system that employs a CO₂separation unit to separate the CO₂from the product stream, to enrich the C₂₊ compounds in the product stream, which CO₂separation unit employs (i) sorbent or solvent separation of CO₂, (ii) membrane separation of CO₂, or (iii) cryogenic or low temperature separation of CO₂having an operating temperature greater than a boiling point of methane and less than a boiling point of CO₂.

In some embodiments, the product stream is directed into the separations system through one or more additional units. In some embodiments, the sorbent or solvent separation of CO₂employs an amine based absoprtion system. In some embodiments, the sorbent or solvent separation of CO₂employs a Benfield process. In some embodiments, the sorbent or solvent separation of CO₂employs diethanolamine. In some embodiments, the sorbent or solvent separation of CO₂employs glycol dimethylether. In some embodiments, the sorbent or solvent separation of CO₂employs propylene carbonate. In some embodiments, the sorbent or solvent separation of CO₂employs Sulfinol.

In some embodiments, the sorbent or solvent separation of CO₂employs a zeolite. In some embodiments, the sorbent or solvent separation of CO₂employs active carbon. In some embodiments, the CO₂separation system comprises a membrane CO₂separation system. In some embodiments, the membrane separation of CO₂employs a polymeric membrane. In some embodiments, the membrane separation of CO₂employs a metallic membrane. In some embodiments, the membrane separation of CO₂employs a ceramic membrane. In some embodiments, the membrane separation of CO₂employs a hybrid membrane comprising a membrane supporting a solvent or sorbent. In some embodiments, the membrane separation of CO₂employs a poly ionic liquid membrane. In some embodiments, the membrane separation of CO₂employs a supported ionic liquid membrane. In some embodiments, the membrane separation of CO₂employs a polyetherimide membrane.

In some embodiments, the method further comprises directing the CO₂from the product stream to a methanation reactor that reacts the CO₂to yield a methanation product stream comprising methane. In some embodiments, the method further comprises directing the methane in the methanation product stream to the OCM reactor. In some embodiments, the method further comprises separating the product stream into (i) an ethylene product stream comprising ethylene and (ii) a C₃₊product stream comprising compounds with three or more carbon atoms (C₃₊compounds). In some embodiments, the method further comprises directing ethane from the product stream to the OCM reactor. In some embodiments, the method further comprises prior to directing the product stream into the separations unit, compressing the product stream.

In another aspect, the present disclosure provides a method for generating compounds with two or more carbon atoms (C₂₊compounds), comprising: (a) directing water into an electrolysis unit that electrolyzes the water to yield oxygen (O₂) and hydrogen (H₂); (b) directing the O₂from the electrolysis unit and methane (CH₄) into an oxidative coupling of methane (OCM) reactor that reacts the O₂and CH₄in an OCM process to yield a product stream comprising (i) C₂₊compounds, including ethylene (C₂H4) and (ii) carbon monoxide (CO) and/or carbon dioxide (CO₂); (c) directing at least a portion of the CO and/or CO₂from the product stream and the H₂from the electrolysis unit into a methanation reactor that reacts the H₂and the CO and/or CO₂to yield CH₄; and (d) directing at least a portion of the CH₄from the methanation reactor to the OCM reactor.

In some embodiments, the electrolysis unit comprises an alkaline water electrolysis system. In some embodiments, the electrolysis unit comprises a proton exchange membrane electrolysis system. In some embodiments, the electrolysis unit comprises a steam electrolysis system.

In another aspect, the present disclosure provides a method for generating compounds with two or more carbon atoms (C₂₊compounds), comprising: (a) directing oxygen (O₂) and methane (CH₄) into an oxidative coupling of methane (OCM) reactor that reacts the O₂and CH₄in an OCM process to yield a product stream comprising (i) C₂₊compounds including ethylene (C₂H4) and (ii) carbon dioxide (CO₂); (b) directing the product stream from the OCM reactor into a separations system that employs a CO₂separation unit that separates the CO₂from the product stream to enrich the C₂₊compounds in the product stream; and (c) directing at least a portion of the CO₂separated in (b) to the OCM reactor.

In some embodiments, the product stream is directed into the separations system through one or more additional units.

In another aspect, the present disclosure provides a method for generating compounds with two or more carbon atoms (C₂₊compounds), comprising: (a) directing oxygen (O₂) and methane (CH₄) into an oxidative coupling of methane (OCM) reactor that reacts the O₂and CH₄in an OCM process to yield a product stream comprising C₂₊compounds including ethylene (C₂H4) and heat; (b) using an evaporator to transfer at least a portion of the heat from the product stream to an organic working fluid in a closed fluid flow cycle as part of an organic Rankine cycle (ORC) system, to evaporate the organic working fluid, which closed fluid flow cycle includes the evaporator, a turbine, a condenser, and a pump; (c) directing the organic working fluid evaporated in (b) to the turbine to generate power; (d) directing the organic working fluid from the turbine to the condenser that condenses the organic working fluid; and (e) directing the organic working fluid condensed in (d) to the pump.

In some embodiments, the organic working fluid is selected from the group consisting of hydrocarbons, silicon oils, and perfluorocarbons. In some embodiments, a boiling point of the organic working fluid is less than a boiling point of water.

In some embodiments, the thermoelectric generator comprises a thin film thermoelectric module. In some embodiments, the thermoelectric generator comprises a micro thermoelectric module.

Additional aspects and advantages of the present disclosure will become readily apparent to those skilled in this art from the following detailed description, wherein only illustrative embodiments of the present disclosure are shown and described. As will be realized, the present disclosure is capable of other and different embodiments, and its several details are capable of modifications in various obvious respects, all without departing from the disclosure. Accordingly, the drawings and description are to be regarded as illustrative in nature, and not as restrictive.

INCORPORATION BY REFERENCE

All publications, patents, and patent applications mentioned in this specification are herein incorporated by reference to the same extent as if each individual publication, patent, or patent application was specifically and individually indicated to be incorporated by reference.

BRIEF DESCRIPTION OF THE FIGURES

The novel features of the invention are set forth with particularity in the appended claims. A better understanding of the features and advantages of the present invention will be obtained by reference to the following detailed description that sets forth illustrative embodiments, in which the principles of the invention are utilized, and the accompanying drawings or figures (also “FIG.” and “FIGS.” herein), of which:

FIG. 1 shows a typical oxidative coupling of methane (OCM) system with advanced separation;

FIG. 2 shows an OCM system with auto refrigeration (e.g., methane refrigeration);

FIG. 3 shows an exemplary OCM system with a silver complexation ethylene recovery subsystem;

FIG. 4 shows an exemplary pressure swing adsoprtion (PSA) system;

FIG. 5A shows a schematic of CO₂separation methods;

FIG. 5B shows a schematic of CO₂separation methods;

FIG. 5C shows a schematic of CO₂separation methods;

FIG. 6 shows typical CO₂distillation system;

FIG. 7 shows a water electrolysis sub system;

FIG. 8 shows an OCM system with CO₂as a quench medium;

FIG. 9 shows an organic Rankine cycle (ORC) subsystem;

FIG. 10 shows an exemplary typical OCM system;

FIG. 11 shows an exemplary OCM system with a single stage PSA unit;

FIG. 12 shows an exemplary OCM system with a multi stage PSA unit;

FIG. 13 shows an exemplary retrofit of OCM to a cracker, with a single stage PSA unit;

FIG. 14 shows an exemplary retrofit of OCM to a cracker, with a multi stage PSA unit;

FIG. 15 shows exemplary configurations of ethylene to liquids (ETL) systems without PSA;

FIG. 16 shows exemplary configurations of ETL systems with PSA;

FIG. 17 shows an exemplary PSA unit integrated with an OCM-ETL system for a midstream application;

FIG. 18 shows an exemplary PSA unit integrated with an OCM-ETL system in a natural gas liquids (NGL) application;

FIG. 19 shows an exemplary PSA unit integrated with an OCM-ETL system for a refining application; and

FIG. 20 shows an exemplary alternate scheme for a PSA unit integrated with an OCM-ETL system for a refining application.

DETAILED DESCRIPTION

While various embodiments of the invention have been shown and described herein, it will be obvious to those skilled in the art that such embodiments are provided by way of example only. Numerous variations, changes, and substitutions may occur to those skilled in the art without departing from the invention. It should be understood that various alternatives to the embodiments of the invention described herein may be employed.

The term “higher hydrocarbon,” as used herein, generally refers to a higher molecular weight and/or higher chain hydrocarbon. A higher hydrocarbon can have a higher molecular weight and/or carbon content that is higher or larger relative to starting material in a given process (e.g., OCM or ETL). A higher hydrocarbon can be a higher molecular weight and/or chain hydrocarbon product that is generated in an OCM or ETL process. For example, ethylene is a higher hydrocarbon product relative to methane in an OCM process. As another example, a C₃₊hydrocarbon is a higher hydrocarbon relative to ethylene in an ETL process. As another example, a C₅₊hydrocarbon is a higher hydrocarbon relative to ethylene in an ETL process. In some cases, a higher hydrocarbon is a higher molecular weight hydrocarbon.

The term “OCM process,” as used herein, generally refers to a process that employs or substantially employs an oxidative coupling of methane (OCM) reaction. An OCM reaction can include the oxidation of methane to a higher hydrocarbon and water, and involves an exothermic reaction. In an OCM reaction, methane can be partially oxidized and coupled to form one or more C₂₊compounds, such as ethylene. In an example, an OCM reaction is 2CH₄+O₂→C₂H₄+2H₂O. An OCM reaction can yield C₂₊compounds. An OCM reaction can be facilitated by a catalyst, such as a heterogeneous catalyst. Additional by-products of OCM reactions can include CO, CO₂, H₂, as well as hydrocarbons, such as, for example, ethane, propane, propene, butane, butene, and the like.

The term “non-OCM process,” as used herein, generally refers to a process that does not employ or substantially employ an oxidative coupling of methane reaction. Examples of processes that may be non-OCM processes include non-OCM hydrocarbon processes, such as, for example, non-OCM processes employed in hydrocarbon processing in oil refineries, a natural gas liquids separations processes, steam cracking of ethane, steam cracking or naphtha, Fischer-Tropsch processes, and the like.

The terms “C₂₊” and “C₂₊compound,” as used herein, generally refer to a compound comprising two or more carbon atoms. For example, C₂₊compounds include, without limitation, alkanes, alkenes, alkynes and aromatics containing two or more carbon atoms. C₂₊compounds can include aldehydes, ketones, esters and carboxylic acids. Examples of C₂₊compounds include ethane, ethene, acetylene, propane, propene, butane, and butene.

The term “non-C₂₊impurities,” as used herein, generally refers to material that does not include C₂₊compounds. Examples of non-C₂₊impurities, which may be found in certain OCM reaction product streams, include nitrogen (N₂), oxygen (O₂), water (H₂O), argon (Ar), hydrogen (H₂) carbon monoxide (CO), carbon dioxide (CO₂) and methane (CH₄).

The term “small scale,” as used herein, generally refers to a system that generates less than or equal to about 250 kilotons per annum (KTA) of a given product, such as an olefin (e.g., ethylene).

The term “world scale,” as used herein, generally refers to a system that generates greater than about 250 KTA of a given product, such as an olefin (e.g., ethylene). In some examples, a world scale olefin system generates at least about 1000, 1100, 1200, 1300, 1400, 1500, or 1600 KTA of an olefin.

The term “item of value,” as used herein, generally refers to money, credit, a good or commodity (e.g., hydrocarbon). An item of value can be traded for another item of value.

The term “carbon efficiency,” as used herein, generally refers to the ratio of the number of moles of carbon present in all process input streams (in some cases including all hydrocarbon feedstocks, such as, e.g., natural gas and ethane and fuel streams) to the number of moles of carbon present in all commercially (or industrially) usable or marketable products of the process. Such products can include hydrocarbons that can be employed for various downstream uses, such as petrochemical or for use as commodity chemicals. Such products can exclude CO and CO₂. The products of the process can be marketable products, such as C₂₊hydrocarbon products containing at least about 99% C₂₊hydrocarbons and all sales gas or pipeline gas products containing at least about 90% methane. Process input streams can include input streams providing power for the operation of the process. In some cases, power for the operation of the process can be provided by heat liberated by an OCM reaction. In some cases, the systems or methods of the present disclosure have a carbon efficiency of at least about 50%, at least about 55%, at least about 60%, at least about 65%, at least about 70%, at least about 75%, at least about 80%, at least about 85%, or at least about 90%. In some cases, the systems or methods of the present disclosure have a carbon efficiency of between about 50% and about 85%, between about 55% and about 80%, between about 60% and about 80%, between about 65% and about 85%, between about 65% and about 80%, or between about 70% and about 80%.

The term “C₂₊selectivity,” as used herein, generally refers to the percentage of the moles of methane that are converted into C₂₊compounds.

The term “specific oxygen consumption,” as used herein, generally refers to the mass (or weight) of oxygen consumed by a process divided by the mass of C₂₊compounds produced by the process.

The term “specific CO₂emission,” as used herein, generally refers to the mass of CO₂emitted from the process divided by the mass of C₂₊compounds produced by the process.

Separations

Various non-cryogenic separation techniques have been increasingly employed for gas separations, purifications and recovery of hydrocarbons. Membrane based processes and adsorbents have been intensively studied for large scale applications for olefins recovery. Since the development of synthetic adsorbents and pressure swing adsorption (PSA) cycles, adsorption has been playing an increasingly important role in gas separation and purification.

PSA technology can be used in a large variety of applications: Hydrogen purification, air separation, CO₂removal, noble gases purification, methane upgrading, n-iso paraffin separation and so forth. While new applications for gas separations by adsorption are continually being developed, the most important applications have been air separation (for production of O₂and N₂) and hydrogen separation (from fuel gas). Approximately 20% of O₂and N₂are currently produced by PSA. The increasing industrial applications for adsorption have stimulated a growing interest in research and new applications.

Processes of the present disclosure can employ a variety of different separations techniques, alone or in combination. For example, OCM processes can employ amine and caustic systems for CO₂removal, molecular sieve guard beds for water removal, and cryogenic distillation or other separation techniques for recovery and purification of hydrocarbon components. Cryogenic separation can refer to separations using temperature levels below 120 K or about −153° C. Other techniques include Selexol™ and Rectisol™ processes for CO₂removal.

OCM product effluent can comprise a mixture of hydrocarbons including but not limited to methane, ethane, ethylene, propane, propylene, butanes, butenes, and higher hydrocarbons. OCM product effluent can also comprise varying amounts of other components such as H₂, N₂, CO, CO₂and H₂O. The product of an OCM reaction can include ethylene. The ethylene product can be polymer grade, refinery grade or chemical grade. Depending on the purity level required, different separation and/or purification techniques can be employed with the OCM process. To recover high purity ethylene, separation methods such as those discussed herein can be used to remove a wide range of components.

Advantages of the advanced OCM processes described herein can include reducing the cost, reducing the number of unit operations (“units”) used, and hence improving the overall process for producing high purity polymer grade ethylene. Overall conversion and carbon efficiency can also be improved. The separation methods disclosed herein can also improve the overall conversion and carbon efficiency.

The different separation and purification techniques discussed herein can be used to separate the OCM product effluent (e.g., process gas) into a plurality of streams, including but not limited to a first stream comprising methane, hydrogen, carbon monoxide and other lighter inerts and a second stream comprising ethane, ethylene, propylene, and higher hydrocarbons. Separation systems or subsystems employed can include those discussed herein, such as a cryogenic demethanizer, a membrane separation system, or a PSA based system.

The separation techniques discussed herein can be employed to remove CO₂, such as from an OCM product effluent stream. One or more separations techniques can be used to remove CO₂including but not limited to absorption, adsorption, CO₂distillation, and membrane separation. The separation technique can be non-cryogenic.

FIG. 1 shows a block flow diagram for an exemplary OCM process. Oxygen 110 and methane 121 can be fed into an OCM reactor 101 for conversion into higher hydrocarbon compounds including ethylene. The OCM product stream 111 can be directed to a compressor 102, and the compressed product stream 112 can be fed into a separations system 103. The separations system can include pretreatment units 104, such as impurity and CO₂removal units, as well as separations units 105, such as cryogenic, non-cryogenic, complexation, membrane, and other separations units. The separations system can be a combination of more than one separation techniques, such as those discussed in this application. The separation system can replace CO₂removal, moisture removal, and cryogenic separation systems of existing OCM process systems. The compressor system may not be required for some types of separation processes. From the separations system, CO₂can be vented 113, ethane 114 can be recovered, for example for recycling to the OCM reactor, ethylene product 115 can be recovered, and C₃₊products 116 can be recovered. Additionally, CO₂117 and methane 118 can be directed from the separations system into a methanation unit 106. The methanation unit can produce methane from the CO₂, for recycling 119 back to the OCM reactor. Additional methane 120 can be added to the OCM reactor supply stream 121.

Auto Refrigeration

OCM process systems can use refrigeration subsystems to condense overhead vapors, for example from a demethanizer, a deethanizer, and/or a C₂splitter. The temperatures employed can be in the range from about 12° C. to about −100° C. These low temperatures can be achieved through the use of multiple refrigeration systems, such as ethylene refrigeration and propylene refrigeration systems, to provide different levels of refrigeration. These can be similar to those employed in existing steam crackers.

Alternatively, an open loop methane refrigeration system can be employed to provide refrigeration for a demethanizer. OCM product effluent can comprise methane as the major component, for example at a concentration of at least about 50 mol %, 60 mol %, 70 mol %, 80 mol %, or 90 mol %. The demethanizer can have the lowest temperature requirements in the entire separations unit. Use of methane refrigeration (e.g., auto-refrigeration) can provide benefits such as elimination of the need for an additional refrigeration system (e.g., new) for any added capacity. For grassroots or greenfield OCM applications, this can considerably reduce refrigeration compressor sizes needed. In some cases, an entire refrigeration system can be eliminated. FIG. 2 shows a block flow diagram for an exemplary open loop methane refrigeration system, such as can be used in gas processing plants and steam crackers to produce chilling for condensing overhead vapors from a demethanizer. Most elements of FIG. 2 correspond to the description in FIG. 1; the separations unit 205 can include an open loop methane refrigeration system to provide cooling for the separations. The system can be combined with a single or multiple stage (e.g., two-stage) expansion system (e.g., Joule Thompson) to chill the incoming feed. In certain cases, multiple separate lighter products are recovered, such as a light H₂-rich stream, a low pressure methane rich stream, and a high pressure methane rich stream.

Mixed Refrigeration

Another alternative to ethylene and propylene refrigeration subsystems is the use of a mixed refrigeration system. The mixed refrigerant can be, for example, a mix of methane, ethylene and propylene. The mixed refrigerant can be a mix of ethane and propane. A wide range of possible mixed refrigerants can be employed, and can be selected based on, for example, the availability of certain components and the degree of refrigeration required. A mixed refrigerant system can provide advantages for use with an OCM reactor system, including the use of only one refrigeration sub system. Rather than two refrigeration systems each comprising multiple stages of refrigerant compressor, associated vessels, exchangers, and other components, the process can use a single refrigeration system. This can substantially reduce capital cost. This can also reduce equipment count, which can be a benefit especially for OCM retrofits at places where plot space may be a concern.

Pi Complexation

Pi complexation techniques can be used to separate alkenes from alkanes. Some metal ions complex selectively with unsaturated organic compounds. Some of these complexes are reversible while others are irreversible. For example, aqueous silver salt in solution forms reversible complexes with olefins, and forms irreversible complexes with acetylenes. This property can be employed in an OCM process to recover ethylene and propylene from OCM reactor effluent.

As shown in FIG. 3, separation of ethylene and/or propylene by metal complexation can be divided into three major sections: absorption, purification or venting of impurities, and desorption. An exemplary process is provided for separation of ethylene and/or propylene from a purified multi-component gas stream from the OCM reactor. FIG. 3 shows a process for purifying a stream containing ethylene using an aqueous silver nitrate solution. Metal complexation (e.g., silver or cuprous ion complexation) can be used to separate ethylene and/or propylene from a purified multi-component gas stream produced via OCM comprising C₂compounds, C₃compounds, and lighter components such as hydrogen and nitrogen. First, the multi-component gas stream 310 can be introduced into an absorber 301 with aqueous silver salt solution, such that the ethylene and/or propylene undergo absorption or complexing with the silver metal ions, and such that trace acetylenes react with the silver metal ions. Vent gas 311 can be removed from the absorber. Then, the silver salt solution stream 312 can be vented 313 in a vent column 302 at reduced pressure to remove any dissolved low molecular weight components. Then, the resulting silver salt solution stream can be treated in a stripper 303 to separate the absorbed or complexed ethylene and/or propylene from the silver salt solution, and further treated in a treatment unit 304 to release the trace acetylenes. Purified ethylene 316 can be recovered, and some product can be recycled 317. The aqueous silver salt stream 318 can then be recycled to the first step, in some cases after regeneration in a regeneration unit 305 with AgMnO₄320. MnO₂321 can be removed from the regeneration unit. H₂O₂319 can be added to the solvent stream being returned to the absorber.

Useful adsorbents include but are not limited to metal compounds, such as silver or copper, supported on high surface area carriers with a plurality of pores. These adsorbents can be used in pressure swing adsorption or temperature swing adsorption processes. When operating pressure and/or temperature is changed, the silver or copper compound can release the alkene-rich component from the adsorbent. These adsorbents can be very effective for selective adsorption of alkenes such as ethylene, propylene, and mixtures of these from gaseous mixtures.

When a gaseous component solubilizes in a liquid and complexes with its ions, the loading of the gas can be affected by its partial pressure and the temperature and the concentration of the complexing ions in the solution. Therefore, by changing the physical conditions separately or collectively, the active gaseous component can either be formed into or out of the solution. Adjusting or swinging one or more physical parameters can be used to carry out an ethylene or propylene separation using an aqueous silver nitrate solution. Purification or venting of impurities can result in a product stream that is free or substantially free of impurities including but not limited to CO₂, sulfur compounds, acetylenes, and hydrogen. Acetylene and hydrogen can cause operational problems and so the process gas can be treated to bring the concentration of such impurities to within an acceptable limit.

Metal complexation can be used in combination with other processes, such as membrane based processes.

Membranes

Membranes can be used to perform a variety of separations, such as separations of olefins and paraffins, or separations of CO₂. A membrane can be essentially a barrier that separates two phases and restricts transport of various chemicals in a selective manner. Polymer membranes can be used to separate mixtures such as propylene/propane mixtures and ethylene/butene mixtures. Separations in polymeric membranes are dependent on the solubility and diffusion of the species through the membrane. While zeolite-based separations are predominantly depended on molecular size differences, the differing permeation of olefins through a polymeric membrane can be largely attributed to differences in solubility, which can depend on the critical temperature and the kinetic diameter. Membrane separations can be employed even when there are small molecular size differences.

The OCM process can utilize a membrane based separation process to further enhance the efficiency and energy consumption of the process. Cryogenic distillation can be used for the separation of alkenes, but is highly energy intensive. Membrane based separations can be used for a variety of purposes in the context of an OCM process, such as to separate and purify ethylene product from OCM reactor effluent, to separate a stream rich in CO₂, to separate a stream containing lighter hydrocarbons and inerts, or to separate C₂compounds from C₁and lighter compounds.

Membranes can include but are not limited to isotropic membranes, anisotropic membranes, and electrically charged membranes. A membrane can be a ceramic membrane, a metal membrane, or a liquid membrane. An isotropic membrane can be a microporous membrane or a non-porous dense membrane. Membranes can be used for separations including but not limited to CO₂separation, paraffin-olefin separation, or selective recovery of pure ethylene from the OCM reactor effluent. Polymer derived carbon molecular sieve membranes can be used to separate paraffins from olefins. These membranes can be used, for example, to separate ethylene from a mix of methane and ethane.

Membrane separations can be used in combination with other types of separation and purification subsystems to remove other impurities such as acid gases, hydrogen, and nitrogen.

Transport through a membrane can take place when a driving force is applied to the components in the feed. A driving force can be a pressure differential or a concentration (activity) gradient across the membrane. Membrane based separation techniques can be used in an OCM process by applying either of the above mentioned driving forces. A membrane based separation can also be a component of a hybrid separation set-up, such as a membrane and an absorption system (e.g., a membrane contactor) or a membrane in a pressure swing adsorption (PSA) or a temperature swing adsorption (TSA) system.

An OCM reactor can employ membranes as a part of the reactor system to effectively separate the ethylene product within the reactor system itself. A section of the reactor can include membranes that aid in recovering the ethylene product, with a methane rich stream being recycled to a methanation system and eventually to the OCM reactor. Such a system can also use advanced heat recovery or quench methods so as to facilitate the use of membranes.

Pressure Swing Adsorption (PSA) and Adsorption Technology

Cryogenic separation (e.g., distillation) can be used for the recovery of ethylene, propylene, and other components from olefin plants, refinery gas streams, and other sources. These separations can be difficult to accomplish because of the close relative volatilities, and can have significant temperature and pressure requirements for operation. The ethane/ethylene distillation can be performed at about −25° C. and 320 pounds per square inch gauge (psig) in a column containing over 100 trays. Distillation of propane and propylene can be performed at about −30° C. and 30 psig. These can be some of the most energy intensive distillations in the chemical and petrochemical industry. In general, the use of distillation towers to separate recover and purify components is an energy intensive process.

The present disclosure provides the use of adsorbents that can achieve separation and purification of olefin rich streams. In particular, the present disclosure applies the use of PSA-based adsorbent systems to separate, purify, and recover olefins like ethylene and propylene from streams containing one or more impurities such as methane, hydrogen, carbon monoxide, carbon dioxide, ethane, or others. The streams, or parts of the streams, can be generated via an OCM process, an ETL process, or combinations thereof. The streams can be final product streams where PSA is used to recover and purify the final product. The streams can be intermediate streams which are purified prior to use as a feed in a subsequent process, such as an ETL process, an ethylene cracker (steam cracker), a refining unit, a fuel gas system, a natural gas recovery plant or any other product fractionation or product treatment unit.

Pressure Swing Adsorption (PSA)

A pressure swing adsorption (PSA) process cycle is one in which desorption takes place at a different (e.g., lower) pressure than the adsorption pressure. Reduction of pressure can be used to shift the adsorption equilibrium and affect regeneration of the adsorbent. Low pressure may not be as effective as temperature elevation in totally reversing adsorption, unless very high feed to purge pressure ratios are applied. Therefore, most PSA cycles are characterized by high residual loadings and thus low operating loadings. These low capacities at high concentration require that cycle times be short for reasonably sized beds (e.g., seconds to minutes). These short cycle times are attainable because particles of adsorbent respond quickly to changes in pressure. Major uses for PSA processes include purification as well as applications where contaminants are present at high concentrations.

As shown in FIG. 4, the PSA system can comprise two fixed bed adsorbers 401 and 402 undergoing a cyclic operation of four steps—adsorption, blowdown, purge, and pressurization. The PSA system can receive a feed 410 and produce a product stream 411, with a PSA off gas stream 412. For improving the performance of the basic Skarstrom™ cycle (FIG. 4), additional operation steps can be employed such as pressure equalization, product pressurization, and co-current depressurization. Besides these steps, the number of beds can be modified to achieve the optimal operation and multi-bed processes can be used in commercial applications like hydrogen recovery. Similarly, a TSA system can be used where a swing in temperature causes the sorption and desorption.

PSA cycles are used primarily for purification of wet gases and of hydrogen. High pressure hydrogen employed in processes such as hydrogenation, hydrocracking, and ammonia and methanol production can be produced by PSA beds compounded of activated carbon, zeolites and carbon molecular sieves. Other exemplary applications include: air separation, methane enrichment, iso/normal separations, and recovery of CO and CO₂.

Adsorbents

Adsorbents can be natural or synthetic materials, such as those having amorphous or microcrystalline structure. Exemplary adsorbents useful for large scale operation include but are not limited to activated carbon, molecular sieves, silica gels, and activated alumina. Other useful adsorbents include pi complexation sorbents, silver and copper complexation adsorbents, zeolites, synthetic zeolites, mesoporous materials, activated carbons, high surface area coordination polymers, molecular sieves, carbon molecular sieves (CMS), silica gels, MCM, activated alumina, carbon nanotubes, pillared clays, and polymeric resins.

For systems where the incoming stream is a multi-component mixture of gases and the number of compounds to be separated cannot be removed by a single adsorbent, different layers of adsorbents can be used. For example, hydrogen purification from a methane stream in a reforming operation, where H₂is contaminated with H₂O, CO₂, CO, and unconverted CH₄, can employ activated carbon to remove H₂O and CO₂in combination with additional layers of different adsorbents used to increase the loading of CO.

Zeolites, molecular sieves, and carbon molecular sieves (CMS) can be used for most industrial separations employing PSA. Inorganic materials, like special kinds of titanosilicates, can be used for kinetic separations.

For systems specifically configured to separate ethane/ethylene and propane/propylene, exemplary types of adsorbents include zeolites/molecular sieves and pi complexation sorbents. Zeolites/molecular sieves can be used for kinetic separation, such as separation based on higher diffusivity of olefins over that of paraffins. The use of 4 A zeolite is one such example. Pi complexation sorbents, such as AgNO₃/SiO₂, can give excellent results as compared to 4 A zeolite. PSA units as discussed herein can employ a range of different sorbents, including but not limited to a zeolite/molecular sieve sorbent, a pi complexation based sorbent, a carbon molecular sieve sorbent or any other form of activated carbon, carbon nanotubes, polymeric resin based sorbents, or other sorbents.

Adsorbents can be selected based on a number of different criteria. Adsorbent selection criteria can include capacity for the target components (e.g., affinity for the desired components to be separated from the multi-component feed stream), selectivity between components competing for same adsorption sites, regenerability of the adsorbent, (e.g., the ability of the adsorbent to release the adsorbed target components at a reasonable pressure rate of gas diffusion into the adsorbent—this can also affect the size of the bead that is chosen and consequently the pressure drop across the bed; an insufficient diffusion rate can require smaller diameter beads that can result in higher pressure drop and hence increased operating costs), and chemical compatibility (e.g., selecting an adsorbent resistant to chemical attack that may poison or destroy the adsorbent, such as liquid hydrocarbons causing physical breakdown of the adsorbent resulting in loss of efficiency and back pressure).

CO₂Separation

There are many technologies available for CO₂capture, such as from flue gases, natural gas, or from any process gas rich in CO₂. Various processes for post-combustion or pre-combustion capture can be used reduce CO₂emissions. FIG. 5A, FIG. 5B, and FIG. 5C show exemplary schematics of different separation methods available to separate CO₂from a process gas or a flue gas.

OCM processes can utilize an amine based absorption system for CO₂removal, which can be followed by use of a caustic scrubber to obtain high degree of separation. The amine system is prone to corrosion, solvent degradation, and above all, has high energy requirements. Separations with sorbents and/or solvents can involve placing the CO₂containing gas in intimate contact with a liquid absorbent or a solid sorbent that is capable of capturing the CO₂. As shown in FIG. 5A, a stream with CO₂510 can be directed into a capture vessel 501, where it contacts sorbent which captures CO₂from the stream. The stream, with reduced or removed CO₂, can then exit 511 the vessel. Sorbent 512 loaded with captured CO₂can be transferred to a sorbent regeneration vessel 502 where it releases the CO₂after being heated (e.g., with the use of energy 513), after a pressure decrease, or after any other change in the conditions around the sorbent, thereby regenerating the sorbent. Spent sorbent 515 and CO₂516 can be removed from the vessel, and make up sorbent 513 can be added. After the regeneration step the sorbent can be sent back to capture more CO₂in a cyclic process. The sorbent can be a solid. Solid sorbent can remain in a single vessel rather than being cycled between vessels; sorption and regeneration can be achieved by cyclic changes (e.g., in pressure or temperature) in the vessel where the sorbent is contained. A make-up flow of fresh sorbent can be used to compensate for natural loss of activity and/or sorbent losses.

Amine scrubbing technology can be used to remove acid gases from process gases. Primary amines (e.g., MEA, DGA), secondary amines (e.g., DEA, DIPA), tertiary (e.g., MDEA, TEA), sterically hindered amines, chilled ammonia, potassium carbonate, and other compounds can be used to remove CO₂from process gases. Traditional amine based systems can be characterized by high energy requirements and solvent degradation. Improved solvents, which can require less energy for regeneration of the solution, include the Benfield process and two stage diethanolamine. Combination with an OCM process can reduce the energy consumption of amine scrubbing processes. Improved solvents can reduce the energy requirements by as much as 40% compared to the traditional MEA solvents. This has the potential of reducing the energy, and hence steam, consumption of the OCM process, thereby increasing the amount of steam available for export from the OCM, or making alternative waste heat recovery methods feasible.

Physical absorption solvents used can include but are not limited to glycol dimethylethers (e.g., Selexol) and propylene carbonate (e.g., IPTS/EC). Regeneration of the solution can be performed by vacuum flashing and air stripping; this approach can consume significantly less energy than in chemical absorption. In using physical solvents CO₂can be released mainly by depressurization, thereby avoiding the high heat of consumption of amine scrubbing processes.

Mixed or hybrid solvents can include but are not limited to Sulfinol™ (sulfolane, water, and amine), such as Sulfinol-M and Sulfinol-X.

Solid adsorbents, such as zeolites and activated carbon, can be used to separate CO₂from gas mixtures. In pressure swing adsorption (PSA), a gas mixture can flow through a packed bed of adsorbent at elevated pressure until the concentration of the desired gas approaches equilibrium. The bed can be regenerated by reducing the pressure. In temperature swing adsorption (TSA), the adsorbent can be regenerated by raising its temperature. In general usage, adsorption is not yet considered attractive for large scale separation of CO₂because the capacity and CO₂selectivity of available adsorbents are low. However, when the OCM process is a recycle process, an adsorbent based separation method can be used to separate bulk CO₂followed by consuming the remaining CO₂in a methanation reactor system, or by using a caustic scrubber to treat the remaining CO₂.

Many different types of membrane materials (e.g., polymeric, metallic, ceramic) can be used for CO₂capture to preferentially separate CO₂from a range of process streams. FIG. 5B shows an exemplary schematic of separation of CO₂from a gas stream 530 in a separation vessel 520 using a membrane 521. CO₂can be removed from the stream via the membrane, and CO₂and other gases can exit the vessel in separate streams 531 and 532. The main limitation of currently existing membranes is the occurrence of severe plasticization of the membrane in the presence of high pressure CO₂. Due to excessive swelling of the polymer membrane upon exposure to CO₂, the performance (e.g., selectivity) can decrease significantly, thus reducing the purity of the CO₂and consequently reducing the possibilities for reuse of the gas. Energy requirements can be significantly lower for membrane based technologies; for example, membrane technology can use 70-75 kWh per ton of recovered CO₂compared to significantly higher values for pressure swing adsorption (e.g., 160-180 kWh), cryogenic distillation (e.g., 600-800 kWh), or amine absorption (e.g., 330-340 kWh), making membrane technology an attractive option for integration with OCM for CO₂separation.

Membrane and amine technologies can be combined to form a hybrid process to capture CO₂. Micro-porous hollow fiber membranes can be used for CO₂separation using amine-based chemical absorption processes. Micro-porous membranes can be used in a gas-liquid unit where the amine solution is contacted with CO₂containing gas. Using the membrane can lead to a reduction in the physical size and weight of the gas-liquid contacting unit. The separation is based on reversible chemical reaction, and mass transfer occurs by diffusion of the gas through the gas/liquid interface as in traditional contacting columns. Such a hybrid membrane contactor can provide a high contact area between gas and liquid, reduce or essentially eliminate foaming and flooding problems, and give better operational flexibility while reducing solvent degradation problems.

A membrane contactor can combine the advantages of membrane technology and solvent absorption for CO₂separation. A membrane contactor is a combination of advanced membrane techniques with an effective absorption process. A membrane contactor is a hybrid mass exchanger where a porous membrane separates two phases. The selective sorbent performs the separation while the membrane facilitates the mass exchange process by expanding the phase contact surface area. The modified surface properties can improve the selectivity of the process by selectively inhibiting the transport of one of the mixture constituents. Compared to a conventional column device, membranes can allow for up to five times increase in yield per unit volume. Since the sorptive liquid flows within capillaries and both phases are not directly contacting each other, membrane absorbers can operate in any spatial configuration (horizontal or vertical) and at any flux rations between both phases. Also, there is no flooding or uneven packing moisturization. Since the system operates with unchanging yields, independent of the diameter and height; scaling up is fairly simple. Membranes used can be micromembranes or ultrafiltration membranes made a variety of different polymer and ceramic materials. Polypropylene fiber membranes can be used to separate CO₂from CH₄, for example by using amines like MEA as absorption liquid. Hollow fiber membranes, such as porous polypropylene, perfluoroalkoxy (PFS), and asymmetric poly(phenylene oxide) hollow fiber membranes with a dense ultrathin skin at the outside of the membrane can also be used. Besides amines as absorption liquid, other absorption liquids may be used, such as aqueous sarcosine salt solutions, for example in a gas-liquid membrane contactor system. A membrane contactor can be used to separate the CO₂from the OCM effluent in which CH₄is the major component. Membrane contactors can also be used for separation of olefins and paraffins, and the separation of CO₂from light gases.

An activator, such as piperazine, diethanolamine, and arsenic trioxide, can be used to further enhance the effectiveness of CO₂capture. DGA and tertiary amines may provide more improvement than primary or secondary amines.

Gas selective poly ionic liquid membranes, which are polymerized room temperature ionic liquids (RTIL), can be used to be highly selectively separate CO₂. RTILs can be synthesized as a monomer and subsequently polymerized to obtain gas selective membranes. The ionic nature of the polymers can result in tight arrangements between the oppositely charged ionic domains in the poly RTIL, which can eventually prevent the membrane from excessive swelling and deterioration of its performance at increased pressure and/or temperature. This intrinsic property of poly RTIL can be used to increase the resistance against plasticization and to restrict strong swelling of the polymer membrane to maintain its permeation properties in the presence of a strong plasticizing agent such as CO₂at higher pressures. For example, an imidazolium-based poly RTIL can be used as base material and the length of the alkyl chain can serves to strengthen or weaken the ionic interactions within the poly RTIL. High pressure mixed CO₂/CH₄gas separation measurements at different temperatures.

Gas components like CO₂, from N₂or CH₄can be separated with supported ionic liquid membranes. Ionic liquids are molten salts with a very low melting point (many are liquids at room temperature). Many ionic liquids show a high solubility for carbon dioxide and hence can be highly suitable for use with an OCM process. For example, ionic liquids can include but are not limited to imidazolium, pyrollidinium, pyridinium, cuanidinium, phosphonium, morpholinium, piperidinium, sulfonium, ammonium, hexafluorophosphate, tetraflouroborate, alkylsulphate, triflate, dicyanamide, bis(trifluoromethylsulfonyl)imide, and combinations thereof. Specific advantages of ionic liquids include very low to negligible vapor pressure, good dissolution characteristics for many substances, and lack of flammability or toxicity. Ionic liquids can have good thermal, mechanical and chemical stability as well as favorable densities and viscosities. The required specifications can be adjusted easily by the large number of possible combinations of anions and cations when formulating an ionic liquid. Ionic liquids can be used as chemical solvents, catalysts, electrolytes in fuel cells as well as for gas-separation and storage by absorption. Ionic liquid membrane systems can comprise an adequate porous support material, e.g. a polymer film, coated by ionic liquids. The system separated CO₂and sulfur compounds from different gas mixtures. Competitive selectivity and permeability are obtained for the separations. Novel membrane materials, such as polyetherimides, can be used as membrane material with improved plasticization resistance for CO₂removal, for example with an OCM process. Other membrane materials that can be used include polymeric membranes based on polyamides, polysemicarbazides, polycarbonates, polyarylates, polyaniline, poly(phenylen oxide), polysulfones, and polypyrrolones. In some cases, the polymeric membrane is solvent resistant and can reduce the plasticization effects of hydrocarbons in the feed stream, e.g., polyketone, polyether ketone, polyarylene ether ketone, polyimide, polyetherimide, and polyphenylene sulphide, which have intrinsic solvent inertness and can therefore withstand organic rich operation conditions.

An adequate porous support material, e.g. a polymer film, coated by ionic liquids can be used in continuous separation of CO₂and sulfur compounds from different gas mixtures, including a methane rich stream. This separation can improve the efficiency of OCM processes. The OCM reactor effluent can enter the supported ionic liquid separation subsystem, and CO₂and other contaminants can be removed from the process gas. Other contaminants can include but are not limited to traces of sulfur compounds, inerts, CO, SO₂, H₂S, and tetrahydrothiophene (THT).

CO₂can be separated from other gases by cooling and condensation, for example as shown in FIG. 5C. A stream containing CO₂550 can be compressed in a compressor 540, and the compressed stream 551 can be directed to a distillation column 541. Some components can be recovered from the overhead stream 552, with heat recovered in a heat exchanger 542. Other components can be recovered from the bottoms 555. Cryogenic separation is widely used commercially for streams that already have a high concentration of CO₂(typically greater than 90%). Cryogenic separation of CO₂has the advantage that it enables direct production of high purity liquid CO₂that can be used as a feedstock to convert the carbon to higher value hydrocarbons, or otherwise be captured. The amount of energy required can be high, and water may need to be removed before the feed gas is cooled.

Low temperature distillation can give better results when there is a high concentration of CO₂in the feed gas. For the OCM process gas, the CO₂concentration can be increased by, for example, having a recycle stream, or by using a modified OCM reactor where excess CO₂is used as a quench medium for the reaction heat. Low temperature separation can refer to separations using temperature levels above −90° C.

FIG. 6 shows a schematic of CO₂separation using distillation. OCM reactor effluent 606 can be fed to a treatment unit 601, such as a molecular sieve dryer, a sulfur removal bed, or an acetylene removal bed. The treated gas is fed to the first distillation column 602 that separates the bulk of the methane from the CO₂and other heavier hydrocarbons. Depending on the CO₂concentration in the stream 606, the bottom stream 608 may contain 50%, 60%, 70%, 80%, 90% (or anywhere in between) of the incoming CO₂. The overhead from 607 contains majority of the methane and other light gases and is fed to the column 603. Column 603 further recovers methane rich gas 611, which can be the feed to a methanation system. The bottoms product 616 may be recycled or sent as a purge to the fuel gas system. The CO₂rich gas 608 is distilled in the CO₂column 604 to recover pure CO₂609 in the overhead. The bottoms product 610 can contain some methane along with ethane, ethylene, and other heavier hydrocarbons, and can be sent to recover the ethylene product in a separator 605. The CO₂product can be sent to methanation unit, and a part of the CO₂can be recycled to achieve the desired concentration of CO₂in the feed stream 606. Such a CO₂distillation sub system can offer many benefits, including but not limited to reducing the loop size of the OCM process considerably, as the function of the existing cryogenic demethanizer can be reduced by a large extent. Additionally, amine and caustic systems can be replaced by cryogenic or low temperature distillation systems.

Alkaline salt-based processes can be used for carbon dioxide removal. These processes can utilize the alkali salts of various weak acids, such as sodium carbonate and potassium carbonate. These processes can provide advantages such as low cost and minimal solvent degradation. Processes that can be used for H₂S and CO₂absorption include those using aqueous solutions of sodium or potassium compounds. For example, potassium carbonate can absorb CO₂at high temperatures, an advantage over amine-based solvents.

Hot potassium carbonate (K₂CO₃) solutions can be used for the removal of CO₂from high-pressure gas streams, among other applications. Potassium carbonate has a low rate of reaction. To improve CO₂absorption, mass transfer promoters such as piperazine, diethanolamine, and arsenic trioxide can be used. Less toxic promoters such as borate can also be used, for example with flue gas streams (see, e.g., Ghosh et al., “Absorption of carbon dioxide into aqueous potassium carbonate promoted by boric acid”, Energy Procedia, pages 1075-1081, February 2009, which is hereby incorporated by reference in its entirety). To limit corrosion, inhibitors can be added. These systems can be known as activated hot potassium carbonate systems. Licensed hot activated potassium carbonate systems include the Benfield™ and the Catacarb™ process. The processes can be used for bulk CO₂removal from high-pressure streams, but can also produce high-purity CO₂.

Flue gas impurities such as SOx and NOx can reduce the operational efficiency of the potassium carbonate as a solvent. SO₂and NO₂may not able to be released from the solvent under industrial conditions. Selective precipitation of the impurity salts formed by SOx and NOx can be used to remove such compounds (see, e.g., Smith et al., “Recent developments in solvent absorption technologies at the CO2CRC in Australia” Energy Procedia, pages 1549-1555, February 2009, which is hereby incorporated by reference in its entirety).

A variety of materials can be used as CO₂sorbents through chemical reactions and physical absorptions, including but not limited to soda-lime, active carbon, zeolites, molecular sieves, alkali metal oxides, silver oxide, lithium oxide, lithium silicate, carbonates, silica gel, alumina, amine solid sorbents, metal organic frameworks and others.

Physical impregnation of CO₂-reactive polymers, such as tetraethylene pentamine or polyethyleneimine, inside a porous support, such as alumina, pumice, clay or activated carbon, can be used for CO₂removal. Amine based sorbents can be easily regenerated. Alternatively, a mixture of an amine compound with a polyol compound can be impregnated in a porous support. The polyol compound can be used to increase the CO₂desorption rate of the amine. The supported amine-polyol sorbent can comprise from about 1 wt % to about 25 wt % amine and from about 1 wt % to about 25 wt % polyol, with the balance being the support. Solid sorbent can adsorb and desorb CO₂a relatively high rates at ambient temperatures. Enhanced CO₂cyclic removal capacities in either dry or humid air flows can further be achieved by using a solid sorbent at an increased amine concentration of amines from about 35 wt % to about 75 wt %.

Solid sorbents that can selectively remove multiple gases can be used to remove CO₂, H₂O, nitrogen oxides, and hydrocarbons. This can be achieved by using composite adsorbents, for example by using a mixed adsorbent of alumina and zeolite to remove CO₂and H₂O simultaneously.

CO₂can be separated from flue gas using an ion pump method instead of relying on large temperature and pressure changes to remove CO₂from a solvent. Ion pump methods can dramatically increase the overlying vapor pressure of CO₂. As a result, the CO₂can be removed from the downstream side of the ion pump as a pure gas. The ion pumping can be obtained from techniques including but not limited to reverse osmosis, electro dialysis, thermal desalination methods, or an ion pump system having an oscillation flow in synchronization with an induced electric field.

By making use of energy such as renewable or nuclear energy, carbon dioxide and water can be recycled into sustainable hydrocarbon fuels in a non-biological process. Various pathways can enable such a conversion, for example by H₂O and CO₂dissociation followed by fuel synthesis. The methods of dissociation can include heat, electricity, and solar driven methods such as thermolysis, thermochemical loops, electrolysis, and photoelectrolysis. High temperature electrolysis can make efficient use of electricity and heat, provide high reaction rates, and integrate well with fuel synthesis.

Synthetic analogues of enzymes as a polymer thin film supported on micro-porous substrates can be used to separate CO₂from gas mixtures. For example, a polymer thin film containing carbonic anhydrase mimicking sites can supported on a porous substrate and can separate CO₂from a stream containing O₂and N₂. The system can be, for example, about 30% lower in cost compared to amine-based systems.

Process Configurations

Electrolysis to Generate Oxygen and Hydrogen for OCM Process

Electrolysis can be used to produce industrial hydrogen. OCM processes can have a lot of synergistic benefit from deploying a water electrolysis subsystem with the OCM process. The water electrolysis unit can replace an air separation unit (ASU) to supply the oxygen required for the OCM process. The products from the electrolytic unit can be consumed within the OCM process: oxygen can be consumed within the OCM reactor and hydrogen can be used in a methanation reactor. Availability of more hydrogen in the methanation unit has the potential to increase the carbon efficiency to about 100%, by converting the CO₂produced in the OCM reaction to methane, which can be recycled back to the OCM reactor. The OCM unit can be a net exporter of high purity excess hydrogen, after consuming the entirety of the CO₂produced in the OCM Process.

The water electrolysis subsystem can be an electrolytic cell employing alkaline water electrolysis, a proton exchange membrane electrolysis system, or a steam electrolysis system. The electricity source to the electrolytic sub system can be renewable, such as photo voltaic/solar power, which can make the entire system 100% carbon efficient with a zero carbon footprint. A storage system for oxygen, or a backup power supply, may be used to ensure the continuous supply of oxygen and hydrogen.

With steam electrolysis, a substantial part of the energy needed for the electrolysis process can be added as heat, which can be much cheaper than electric energy, and which the OCM reactor can produce in abundance. Therefore, integration of steam electrolysis can take advantage of the extra heat from the OCM reactor to provide energy for the steam electrolysis. This can be of particular benefit to OCM deployments where no additional steam or power is required.

FIG. 7 depicts an exemplary electrolysis subsystem combined with an OCM system. The electrolysis subsystem 701 can take water 710 and electric power 711 as inputs and generate pure oxygen 712 and hydrogen 713 as products. The oxygen can be fed into an OCM reactor 702 with a methane feed 714, for conversion to higher hydrocarbon products including ethylene. The OCM product stream can be compressed in a compressor 704 and separated in a separations unit 705. Higher hydrocarbon products 716 can be recovered from the separations unit, and other compounds such as methane and CO₂can be recycled 717 and/or purged 718. The recycle stream can be directed to a methanation unit 703, which can generate methane 715 using the hydrogen from the electrolysis subsystem. The extra hydrogen that is now available to the methanation unit can enable the conversion of most or all of the CO₂produced in the OCM process to methane, which can drive the process to a higher efficiency. The process can also be almost 100% emission free. The CO₂produced in the process that may be discarded as waste may be converted to methane and hence to ethylene in the OCM reactor.

Different Quench Media for the OCM Reaction

The OCM reaction is highly exothermic. Various quenching media can be used to extract the OCM reaction heat. For example, CO₂can be injected to extract the heat, which results in the OCM effluent containing excess CO₂; such effluent can be suitable for the advanced CO₂recovery methods described herein. FIG. 8 shows an exemplary system where CO₂814 is removed from an OCM product stream 812 (generated in an OCM unit 801 from an oxygen stream 810 and a methane stream 811) in a CO₂separation unit 802 and recycled from back to the OCM reactor 801. A waste gas or purge stream 815 can also be removed from the CO₂separation unit. The OCM product stream 813 can then be separated in a separations unit 803 into a product stream 816 comprising ethylene and a purge and/or recycle stream 817. Separation methods can include low temperature separation, membrane separation, or other separation methods discussed herein. The OCM loop can be decreased to just a CO₂recycle stream. The system can also comprise a methanation unit (not shown).

Such an approach can provide advantages including a smaller recycle loop and more efficient CO₂removal methods, resulting in lower capital expenditure (CAPEX). This can also result in the feasibility of small distributed scale OCM units, since after the removal of excess CO₂, the relatively richer ethylene stream needs fewer treatment and recovery steps.

Heat Recovery

Waste heat from the OCM process can be used to generate superheated high pressure steam that can be used in the process, exported to other users on site, or can be used to generate power. Excess process heat can also be used to preheat the feed streams. Other uses for excess heat can be less capital intensive, and offer a greater operational flexibility and low maintenance. Thermoelectric energy conversion can be used to convert waste heat to power. Example uses for waste heat include single fluid rankine cycles (e.g., steam cycle, hydrocarbons, and ammonia), binary/mixed fluid cycles (e.g., ammonia/water or mixed hydrocarbon cycle).

Organic Rankine Cycle

The organic Rankine cycle (ORC) can be used to generate power from heat. In ORC, an organic component is used instead of water. The organic compound can be a refrigerant, a hydrocarbon (e.g., butane, pentane, hexane), silicon oil, or a perfluorocarbon. The boiling point of the organic fluid can be lower than that of water, which can allow recovering heat at a lower temperature than in the traditional steam Rankine cycle.

Owing to the exothermicity of the OCM reaction, the ORC system can be deployed as a waste heat recovery method for use with OCM. Waste heat at relatively low temperature can be recovered by an intermediate heat transfer loop and used to evaporate the working fluid of the ORC.

FIG. 9 shows an exemplary OCM system with an ORC subsystem. The working fluid can be chosen which can be condensed with cooling water or air at normal atmospheric pressure. FIG. 9 shows the heat source as the OCM reaction heat from an OCM unit 901. Heat can be recovered from the OCM product stream 910 in an evaporator 902, and the product stream 911 can then be directed for downstream processing from the OCM unit. The heat recovered in the evaporator can be used to evaporate a working fluid stream 912, which can then be directed to a turbine 903 to generate power in a generator 904. From the turbine, the working fluid 913 can be directed to a condenser 905 and cooled using a cooling medium 914. The cooled working fluid 915 can then be pumped by a pump 906 in a stream 916 back to the evaporator.

Thermoelectric Power Generation

The OCM process can make use of a heat exchanger with thermoelectric (TE) generators for heat recovery. A Thermoelectric Power Generator (TPG) can have four basic components: Heat source, P and N type semiconductor stack (or a TE module), heat sink (cold side), and an electrical load (output voltage). The TE module can include two or more of P-type and N-type semiconductor pellets connected in series or parallel depending on the served load.

The TE devices can be solid state engines that do not require any working fluid. Thermoelectric materials can provide efficiencies of up to 15% or greater. Thermoelectric generators coupled with heat exchangers can produce electricity even at temperatures as low as 350 K with low maintenance. TE modules can be used with OCM including large bulk TE modules and thin film or micro TE modules.

For high temperatures, micro TE modules can be used. Micro TE modules can also have low equipment weights. TE devices can be very reliable, scalable, and modular. Some TE modules can give best results at small scales. The OCM process can generate medium level waste heat that is highly suitable for a TE device to generate power.

OCM and ETL Systems with Advanced Separations Sub-Systems

PSA technology can be applied to processes including those involving a hydrocarbon stream containing a mix of the following hydrogen, carbon dioxide, carbon monoxide, methane, ethane, ethylene, propane, propylene, butanes, butenes and/or other higher hydrocarbons needing to be purified or separated into desirable products (e.g., ethylene, methane, hydrogen, or propylene).

Hydrocarbon streams can be produced via traditional refining and petrochemical processes. Hydrocarbon streams can be produced from OCM or ETL reactor systems.

The present disclosure provides the use of PSA in processes and systems for oxidative coupling of methane (OCM) and ethylene-to-liquids (ETL) operations, and the application of adsorbent based processes used in conjunction with OCM and ETL processes to generate significant process improvements and enhance the economic value of the processes. OCM systems are described in, for example, U.S. patent application Ser. No. 14/592,668, which is entirely incorporated herein by reference. ETL systems are described in, for example, U.S. patent application Ser. No. 14/591,850, which is entirely incorporated herein by reference.

An OCM system, such as that shown in FIG. 10, can include an OCM or OCM-post-bed-cracking (PBC) reactor 1002, a process gas compression system 1003, a process gas treatment system 1004, a cryogenic separations system, and a methanation system 1001. The feed to the OCM system can be an oxygen feed 1012 and a methane source feed 1011 (such as a natural gas feed stream or other methane source). In some cases, additional ethane feed can be supplied to the PBC section of the OCM reactor, where paraffins such as ethane in the OCM product stream and/or additional ethane can be cracked to olefins such as ethylene. The separations sub-system can comprise a series of fractionation towers, like a demethanizer 1005, deethanizer 1006, C₂splitter 1007, depropanizer 1008, debutanizer, and others. Overhead 1013 from the demethanizer can be directed into the methanation system along with hydrogen or natural gas 1010 to produce additional methane. The bottoms stream 1014 from the demethanizer can be directed to the deethanizer. The overhead stream 1015 from the deethanizer can be directed to the C₂splitter, and there split into ethylene 1016 and ethane 1017 streams. The bottoms stream 1018 from the deethanizer can be directed to the depropanizer, and there split into a C₃product stream 1019 and a C₄₊product stream 1020. The cryogenic separations system can comprise additional ethylene and propylene refrigeration sub-systems to provide for the chilling requirements of the system.

OCM Process Standalone with Advanced Separations Systems

In certain cases, the separations section of the OCM system can be eliminated, or partially eliminated, by utilizing an advanced separations method as discussed in this application. The advanced separation method can be a PSA unit or a membrane based method, or a cryogenic system. FIG. 11 shows an exemplary schematic of OCM with a PSA unit. The PSA unit can separate methane, CO₂, CO, and/or H₂from ethane, ethylene, propane, propylene, and/or higher hydrocarbons. Methane 1111 and oxygen 1112 can be directed into an OCM reactor 1102 and reacted to produce higher hydrocarbon products including ethylene. The OCM product can be compressed in a process gas compression system 1103, treated in a process gas treatment system 1104, and separated in the PSA 1105 into a product stream 1113 and a recycle stream 1114. The recycle stream can be directed to a methanation unit 1101, which can also receive a natural gas stream 1110 and produce methane for the OCM reactor. The extent of separation and degree of recovery can depend on the type of adsorbent(s), pressure differential, and number of PSA stages employed. The feed to the PSA unit can have one or more of the following components: H₂, N₂, O₂, CO, CO₂, CH₄, ethane, ethylene, acetylene, propane, propylene, butanes, butenes, butadiene, water, and higher paraffinic and olefinic components. The PSA product gas can comprise components including but not limited to: H₂, N₂, CO, CO₂, CH₄, O₂, ethane, ethylene and acetylene. PSA product gas can comprise components from 0% to 99.99% recovery. The PSA tail gas can comprise 99.99%, 90%, 80%, 70%, 60%, 50% ethylene. The PSA tail gas can comprise at least 99.99%, 90%, 80%, 70%, 60%, 50% ethylene. The PSA tail gas can comprise about 99%, 90%, 80%, 70%, 60%, 50%, 40%, 30%, 20%, 10%, 0% ethane. The PSA tail gas can comprise at least about 99%, 90%, 80%, 70%, 60%, 50%, 40%, 30%, 20%, 10%, 0% ethane. The PSA tail gas can comprise about 60%, 50%, 40%, 30%, 20%, 10%, 0% methane, hydrogen, acetylene, N₂, O₂, H₂O or CO₂. The PSA tail gas can comprise at least about 60%, 50%, 40%, 30%, 20%, 10%, 0% methane, hydrogen, acetylene, N₂, O₂, H₂O or CO₂. Based on the process configuration, including the type of adsorbents employed, pressure differential and the operation, various different recoveries are possible.

As discussed above, the PSA unit can comprise one or more adsorbent materials that can be suitable to achieve the component recoveries. The sorbent can be a zeolite/molecular sieve based material, a carbon based sorbent, or a n-complexation sorbent. In some cases the sorbent material can be a polymeric resin, carbon nanotubes, and carbon fibers. The PSA unit can be configured to have layers of different sorbents so as to result in high recoveries from the multi-component feed streams to the desired products.

In certain cases the PSA can be a multi stage unit (see, e.g., FIG. 12). In such a unit, an OCM reactor 1202 can receive a methane stream 1211 and an oxygen stream 1212, and react the methane and oxygen to produce higher hydrocarbon products including ethylene in an OCM product stream. The OCM product stream can be compressed in a first compressor 1203 and directed to a first PSA separation 1204. The tail gas 1214 from the first PSA can be compressed in a second compressor 1205 and fed to a second PSA separation 1206, the tail gas 1216 from which can be compressed in a third compressor 1207 and separated in a third PSA separation 1208. The tail gas from the third PSA can be the final purified stream 1217 containing ethylene up to 99.9% purity. PSA product streams 1213, 1215, and 1218 can be directed to recycle, such as via a methanation unit 1201 along with a natural gas stream 1210. Each PSA stage can be a dual-bed PSA or a multi-bed PSA system.

In certain cases, the process requirements can dictate that only a limited amount of recovery is required in the PSA unit and subsequent recovery and purification is performed in a fractionation column or the gas is a feed for a downstream process unit. The downstream process unit can be an ETL system, an ethylene steam cracker system, a gas processing plant, NGL extraction plant, a refinery off-gas separations system, or other process unit.

Retrofits for OCM

OCM can be employed to convert a feedstock comprising methane to ethylene and other olefins. Historically, ethylene has been produced via steam cracking of gaseous or liquid hydrocarbon feedstocks like ethane, propane, LPG, or naphtha. As in most of the refining and petrochemical operations, a steam cracking operation can involve a cryogenic fractionation or a separations section that consists of a series of fractionation columns to successively recover various components at high product purity.

The present disclosure includes the application of PSA processes to an OCM retrofit of an existing ethylene cracker (e.g., steam cracker).

An example application for OCM combined with a PSA unit involves an existing petrochemical plant such as a steam cracker is considering low cost ways to add ethylene capacity. A typical revamp to add capacity could include addition of, or debottlenecking of, the existing fractionation towers for the entire flow addition for the revamp. However, as shown in FIG. 13, the use of a PSA unit as disclosed herein can provide a low cost alternative to traditional revamps. An OCM unit with a PSA unit retrofitted to an existing steam cracker can be an effective way of adding ethylene capacity at a low marginal cost. The advantages of adding a PSA unit include that no additional cryogenic separation is required for the added capacity. For ethylene revamps, one of the key areas during debottlenecking may be the refrigeration systems and/or the fractionation columns, but utilizing the PSA to separate or pre-separate the additional product stream can result in a simpler and easier debottlenecking. As in shown in FIG. 13, for example, the tail gas from the PSA can be sent to the cracker system where the ethylene is recovered.

FIG. 13 shows an example of an OCM process integrated with an existing ethylene cracker using a PSA system for separations. The OCM reactor 1301 takes in methane 1310 and oxygen 1311 and produces an OCM effluent 1312 having CO₂, CH₄and C₂H4, in some cases amongst other components, such as H₂and CO. The OCM reaction can be exothermic and can produce steam 1313. The OCM effluent can be compressed in a compressor 1302 and optionally treated in an acid gas removal system 1303, and fed into a pressure swing adsorption (PSA) unit 1304. In some cases the acid gas removal system may have an additional knock out drum to condense and separate any condensates and water. It also can include a drier to remove water. The PSA unit can produce a product stream that can include H₂, CH₄, ethane, CO₂and CO. The overhead stream 1315 can be fed into a methanation subsystem 1305 (e.g., methanation reactor) to provide methane for the OCM reactor, and some of the overhead stream can be purged 1316 to a fuel gas system, for example. Additional methane can be provided by way of a natural gas stream or other methane stream. The PSA tail gas 1317 can comprise most of the ethylene, the content of which may range from 50% to 99.9% depending on the process configuration and operation of the PSA system. The PSA tail gas can also comprise H₂, CO, CO₂, CH₄, ethane, propane, propylene, butanes, butenes, and other components. The process of FIG. 13 can further include an existing ethylene cracker 1306. The PSA tail gas can be fractionated using existing separations capacity in the ethylene cracker. The heavy components can be processed in the fractionation towers of the ethylene cracker, optionally first being compressed in the existing process gas compressor of the ethylene cracker. In some cases, the heavy components stream can be routed to the CO₂removal unit of the existing ethylene cracker subsystem to meet the CO₂specification. The OCM reactor can receive a C₂recycle stream 1319 from the cracker complex.

The combination of a new OCM unit and an existing ethylene cracker can provide synergistic benefits. It can provide for a low cost alternative to add ethylene capacity to the existing cracker. In some cases, prior to retrofit of an ethylene cracker with OCM, the entire overhead from the existing demethanizer is used as fuel gas, and can now be available as one of the feeds to the methanation unit. In some cases, the demethanizer overhead off-gas comprises up to 95% methane, which can be converted to ethylene in the OCM reactor, hence increasing the total ethylene capacity. In some cases, the hydrogen content in the existing demethanizer overhead is substantial, and may be enough to meet the hydrogen requirement of the methanation unit.

In some cases, retrofitting an ethylene cracker with OCM reduces (or allows for reduction of) the severity of cracking in the existing cracker, enabling value addition by increasing the production of pyrolysis gasoline components in the cracker effluent, as the OCM reactor produces the ethylene that may be needed to achieve the total system capacity. The cracker can then be operated on high propylene mode to produce more propylene and at the same time meeting the ethylene production rate by the new OCM unit. This retrofit can result in greater flexibility for the ethylene producer with respect to the existing cracker operation.

In some instances, the overall carbon efficiency can be increased as the methane and hydrogen from the existing demethanizer off-gases can be utilized to convert the carbon dioxide and carbon monoxide to methane, which is fed to the OCM reactor.

In some instances, ethane and/or propane recycle streams from the existing cracker can be routed to the OCM unit (e.g., instead of the cracking furnaces). These recycle streams are typically routed to the cracking furnaces where they are cracked to extinction. This can provide an advantage over routing the recycle streams to OCM over the cracking furnace, such as higher selectivity to ethylene in the OCM process.

In certain cases, more than one stages or PSA columns may be employed to achieve higher recovery and higher product purity. As in shown FIG. 14, for example, up to 99.9% recovery is possible using the multi stage PSA units. An OCM reactor 1402 can receive a methane stream 1410 and an oxygen stream 1411, and react the methane and oxygen to produce higher hydrocarbon products including ethylene in an OCM product stream. The OCM product stream can be compressed in a first compressor 1403 and directed to a first PSA separation 1404. The tail gas 1412 from the first PSA can be compressed in a second compressor 1405 and fed to a second PSA separation 1406, the tail gas 1414 from which can be compressed in a third compressor 1407 and separated in a third PSA separation 1408. The tail gas from the third PSA can be the final purified stream 1417 can be directed to a cracker unit, such as an existing cracker unit, where it can be processed and separated into an ethylene product stream 1418, a propylene product stream 1419, and an additional product stream 1420. PSA product streams 1413, 1415, and 1416 can be directed to recycle, such as via a methanation unit 1401, along with a demethanizer off gas stream 1421 from the cracker unit. Each PSA stage can be a dual-bed PSA or a multi-bed PSA system.

The application of a PSA unit to OCM systems, standalone or retrofits to existing facilities exhibits immense potential in terms of cost savings and ease of integration and retrofit to existing facilities.

ETL Systems

FIG. 15 shows various exemplary configurations for an OCM-ETL process. In the upper left, FIG. 15 shows a stand alone skimmer configuration, where a methane stream 1505 can be directed into an OCM reactor 1501 with an oxygen feed 1506 and optionally an ethane feed 1507. The OCM reactor product stream can be directed into a compressor 1502 and then into an ETL reactor 1503. The ETL product stream can be directed into a gas separations unit 1504, where it can be separated into a C₂₊product stream 1508, a C₅₊product stream 1509, and an overhead stream 1510 comprising methane which can be returned to a pipeline, sold to a consumer, or otherwise used. In the upper right, FIG. 15 shows a stand alone recycle configuration, where a methane feed stream 1518 (e.g., from a natural gas pipeline) is directed into a treatment unit 1511 and then into a separations system (e.g., cryogenic) 1512. A methane feed stream 1519 can be directed to an OCM reactor 1513, while another methane stream 1520 can be purged or used for power generation. A C₂₊stream 1521 can also be recovered from the separations system. An oxygen feed stream 1522 and optionally an ethane stream 1523 can also be directed into the OCM reactor, and the reactor can produce an OCM product stream. The OCM product stream can be directed into a compressor 1514 and then into an ETL reactor 1515. The ETL product stream can be processed in a knockout drum 1516 or other separator to remove a C₅₊product stream 1524. The remaining ETL product stream can be directed to a compressor 1517 and recycled to the treatment unit. In the lower left, FIG. 15 shows a hosted skimmer configuration, where a methane stream 1532 can be directed from a separations system 1526 (e.g., cryogenic) into an OCM reactor 1527 with an oxygen feed 1533 and optionally an ethane feed 1534. The OCM reactor product stream can be directed into a compressor 1528 and then into an ETL reactor 1529. The ETL product stream can be directed into a gas separations unit 1530, where it can be separated into a C₂₊product stream 1535, a C₅₊ product stream 1536, and an overhead stream 1537 comprising methane which can be returned to a recompressor 1531. In the lower right, FIG. 15 shows a hosted recycle configuration, where a methane stream is directed into a treatment unit 1538 and then into a separations system (e.g., cryogenic) 1539. A methane feed stream 1546 can be directed to an OCM reactor 1541, while another methane stream can be directed to a recompressor 1540. A C₂₊stream 1551 can also be recovered from the separations system. An oxygen feed stream 1547 and optionally an ethane stream 1548 can also be directed into the OCM reactor, and the reactor can produce an OCM product stream. The OCM product stream can be directed into a compressor 1542 and then into an ETL reactor 1543. The ETL product stream can be processed in a knockout drum 1544 or other separator to remove a C₅₊product stream 1549. The remaining ETL product stream can be directed to a compressor 1545 and recycled 1550 to the treatment unit.

FIG. 16 shows similar configurations as FIG. 15, with an added pressure swing adsoprtion (PSA) unit to pre-separate the OCM effluent to remove most of the methane, hydrogen, CO and CO₂from the olefinic stream, which is then fed to the ETL reactor. This can result in a feed to the ETL reactor that is concentrated in olefins. Though the process remains similar, the entire ETL and separations train becomes considerably smaller; that is, larger capacities can be achieved in the same set-up or same footprint. In some cases this can improve the ETL reaction operation. In the upper left, FIG. 16 shows a stand alone skimmer configuration, where a methane stream 1606 can be directed into an OCM reactor 1601 with an oxygen feed 1607 and optionally an ethane feed 1608. The OCM reactor product stream can be directed into a compressor 1602 and then into a PSA unit 1603. A light stream 1609 comprising methane, hydrogen, CO and CO₂can be directed from the PSA back to a pipeline, sold to a consumer, or otherwise used. An olefinic stream can be directed from the PSA to an ETL reactor 1604. The ETL product stream can be directed into a gas separations unit 1605, where it can be separated into a C₂₊product stream 1610, a C₅₊product stream 1611, and an overhead stream 1612 comprising methane which can be returned to a pipeline, sold to a consumer, or otherwise used. In the upper right, FIG. 16 shows a stand alone recycle configuration, where a methane feed stream 1628 (e.g., from a natural gas pipeline) is directed into a treatment unit 1620 and then into a separations system (e.g., cryogenic) 1621. A methane feed stream 1629 can be directed to an OCM reactor 1622, while another methane stream 1630 can be purged or used for power generation. A C₂₊stream 1631 can also be recovered from the separations system. An oxygen feed stream 1632 and optionally an ethane stream 1633 can also be directed into the OCM reactor, and the reactor can produce an OCM product stream. The OCM product stream can be directed into a compressor 1623, and at least a portion 1634 of the OCM product stream can be directed from the compressor into a PSA unit 1624. A light stream 1635 comprising methane, hydrogen, CO and CO₂can be directed from the PSA back to the treatment unit. An olefinic stream 1636 can be directed from the PSA to an ETL reactor 1625. The ETL product stream can be processed in a knockout drum 1626 or other separator to remove a C₅₊product stream 1637. The remaining ETL product stream can be directed to a compressor 1627 and recycled to the treatment unit. In the lower left, FIG. 16 shows a hosted skimmer configuration, where a methane stream 1647 can be directed from a separations system 1640 (e.g., cryogenic) into an OCM reactor 1641 with an oxygen feed 1648 and optionally an ethane feed 1649. The OCM reactor product stream can be directed into a compressor 1642 and then into and then into a PSA unit 1643. A light stream 1650 comprising methane, hydrogen, CO and CO₂can be directed from the PSA to a recompressor 1646. An olefinic stream can be directed from the PSA to an ETL reactor 1644. The ETL product stream can be directed into a gas separations unit 1645, where it can be separated into a C₂₊product stream 1651, a C₅₊product stream 1652, and an overhead stream 1653 comprising methane which can be returned to the recompressor. In the lower right, FIG. 16 shows a hosted recycle configuration, where a methane stream is directed into a treatment unit 1660 and then into a separations system (e.g., cryogenic) 1661. A methane feed stream 1669 can be directed to an OCM reactor 1663, while another methane stream can be directed to a recompressor 1662. A C₂₊stream 1677 can also be recovered from the separations system. An oxygen feed stream 1670 and optionally an ethane stream 1671 can also be directed into the OCM reactor, and the reactor can produce an OCM product stream. The OCM product stream can be directed into a compressor 1664 and at least a portion 1672 of the OCM product stream can be directed from the compressor into a PSA unit 1665. A light stream 1673 comprising methane, hydrogen, CO and CO₂can be directed from the PSA back to the treatment unit. An olefinic stream 1674 can be directed from the PSA to an ETL reactor 1666. The ETL product stream can be processed in a knockout drum 1667 or other separator to remove a C₅₊product stream 1675. The remaining ETL product stream can be directed to a compressor 1668 and recycled 1676 to the treatment unit.

The ETL reactor can be a tubular, packed bed, moving bed, fluidized bed, or other reactor type. An ETL reactor can be an isothermal or adiabatic reactor. The ETL system can benefit from a feed concentrated in olefins. The ETL reactor system can use a recycle stream to control and moderate the temperature increase in the reactor bed due to the highly exothermic nature of the ETL reactions. ETL systems are described in, for example, U.S. patent application Ser. No. 14/591,850, which is entirely incorporated herein by reference.

In certain embodiments, one or more of the fractionation towers can be deemed redundant if using the PSA, as an example, a demethanizer may not be required and the sales gas or purge gas to fuel can be sent from the PSA itself.

Retrofit Applications for Midstream and Refining

Systems, such as those of FIG. 17, can be integrated with an existing gas processing plant where one or more of the existing subsystems can be utilized. The utilization may arise from the fact that the existing subsystems are no longer used, or have an additional capacity available to allow for the integration.

FIG. 17 shows an exemplary application of an OCM-ETL system using a PSA system for pre-separations to an existing gas processing plant, where one or more existing sub systems may be utilized. As shown in FIG. 17, the existing separations sub-system can be integrated with the OCM-ETL system to add value by converting natural gas to higher value liquid hydrocarbons. The PSA unit can be used to pre-separate the lighter components like methane, hydrogen, carbon monoxide, carbon dioxide, ethane, and other components, and the olefin rich stream can be sent to the ETL reactor that converts the olefins to higher molecular weight liquid hydrocarbons. One advantage of using a PSA system is the reduction in net additional feed to the existing separation system, which can be de-bottlenecked easily. If the separation system is no longer in use, addition of a PSA can bring about larger total capacities that can be achieved by adding larger OCM-ETL systems. A natural gas stream 1720 can be directed to a treatment unit 1701 and then into a separations system (e.g., cryogenic) 1702. At least portion of a methane stream 1724 from the separations unit can be directed to an OCM reactor 1705, while a portion of the methane stream can be directed to a compressor 1703 and used as sales gas 1721 or other purposes. A higher hydrocarbon stream can be directed from the separations system to a C₂removal unit 1704, which can produce a natural gas liquids stream 1722 and a C₂stream 1723. The C₂stream can be fed into the OCM reactor with the methane stream and an oxygen stream 1725, and reacted to form higher hydrocarbon products including ethylene. The OCM product stream can be directed into a heat recovery system 1706, which can generate a high pressure superheated (HPSH) steam stream 1726. The OCM product stream can then be directed to a knockout drum to recover a condensate stream 1727. The OCM product stream can then be directed to a compressor 1708, which can operate using the HPSH steam stream. From the compressor, the OCM product stream can be directed to a PSA unit 1709. From the PSA unit, light stream comprising methane, hydrogen, CO and CO₂can be directed to a methanation unit 1710, and an olefinic stream can be directed to an ETL reactor 1711 and reacted to form higher hydrocarbon products. The ETL product stream can be directed to a heat recovery unit 1712, where boiler feed water (BFW) 1728 can be heated, at least a portion of which can be fed 1729 to the heat recovery unit 1706. The ETL product stream can then be directed to another knockout drum 1713. The overhead stream from the knockout drum can be directed to a low temperature separations unit 1714, while the bottoms stream from the knockout drum can be directed to a C₄removal unit 1715, which can produce a C₄stream 1730 and a C₅₊stream 1731. Overhead from the low temperature separations unit, as well as product from the methanation reactor, can be directed back to the compressor 1703.

OCM-ETL systems of the present disclosure can be integrated into and combined into conventional NGL extraction and NGL fractionation sections of a midstream gas plant. Where NGLs in the gas stream are declining (or gas is dry), the deployment of OCM-ETL can utilize an existing facility to produce additional liquid streams. The implementation of OCM-ETL can allow for the generation of on specification “pipeline gas.” The products from the facility can be suitable for use (or on specification or “spec”) as pipeline gas, gasoline product, hydrocarbon (HC) streams with high aromatic content, and mixed C₄products. The PSA systems discussed above can be employed to separate, pre-separate or purify the hydrocarbon feed streams in the integrated NGL OCM-ETL system. FIG. 18 shows an exemplary NGL extraction facility integrated with an OCM-ETL system. As shown in FIG. 18, for example, the feed to the PSA 1802 can be the net incoming gas from the treatment system 1801, which can treat a methane stream (e.g., natural gas) 1810. The PSA system can separate the feed to the OCM reactor 1803, which is mostly methane and lighter components with some ethane to utilize a PBC section of the OCM reactor, and the feed to the ETL reactor 1805, which can first be processed in a natural gas liquids extraction system 1804. The feed to the ETL system can be the PSA tail gas and OCM effluent comprising ethylene, propylene, ethane, propane, hydrogen, methane, and other components. In some cases, the OCM effluent can be directly fed to the ETL reactor. In some cases the OCM effluent is hydrogenated and fed to the ETL system. In some cases, as shown for example in FIG. 18, the OCM effluent is fed back to the PSA unit for separation; additional natural gas 1811 can be added, and a stream can be recovered 1812 (e.g., for use as pipeline gas). In some examples, the system may have a methanation unit that takes in the effluent from ETL reactor or OCM reactor and converts the CO, CO₂and H₂to methane, thereby further increasing the carbon efficiency of the process. The existing NGL extraction and product fractionation 1806 sub-systems can then be used to fractionate the final products, including into a mixed C₄stream 1814 and a C₅₊product stream 1815.

Refining

Refinery gas typically contains valuable components like hydrogen, methane, ethane, ethylene, propane, propylene, and butane. Most commonly, refinery off-gases (ROG) are exported to the fuel gas system, thereby losing the value of the components contained therein. The OCM-ETL process can be used to improve the value of products as the OCM converts the methane to ethylene and the ETL converts olefins (e.g., those existing in the ROG and those generated by OCM) to higher value liquids as C₄components, gasoline blends, or aromatic components.

FIG. 19 shows an exemplary PSA unit integrated to a refinery process scheme. A refinery gas plant 1901 can receive gas 1910 from cracking or other units. The PSA unit 1903 (after, for example, treatment of the gas in a treatment unit 1902) can separate components in refinery gas plant off gas to methane and a C₂₊cut which contains most or all of the olefinic materials. The methane can be used as refinery fuel 1911 and/or directed to an OCM unit 1904 with post-bed cracking. The OCM feed can be supplemented with additional natural gas 1912. The olefinic materials can be directed to an ETL reactor 1905. The OCM effluent can also be routed to the PSA where the olefins produced in the OCM are also sent to the ETL reactor. In some cases, the OCM effluent can be routed to the ETL reactor. In some cases, the OCM effluent may be hydrogenated before being sent to the PSA unit or ETL reactor. Some techniques may dictate the use of a cryogenic demethanizer in place of the PSA, but the application of PSA to pre-separate the refinery off-gas into a product stream and a tail gas stream containing the heavier hydrocarbons which is the feed to ETL reactor can result in significant cost savings. The product stream can contain methane, ethane, CO, CO₂, and other components, with of each component from 1 to 99%. A C₃₊stream 1913 from the refinery gas plant can be directed to a product fractionation system 1906, which can provide a C₂/C₃stream 1914 (which can be directed to the OCM reactor), an iC₄stream 1915, a gasoline blend stream 1916, and/or a kerosene/jet stream 1917.

As shown in FIG. 20, in some cases the system can have a methanation unit to further improve the carbon efficiency of the process. A refinery gas plant 2001 can receive gas 2010 from cracking or other units. The PSA unit 2003 (after, for example, treatment of the gas in a treatment unit 2002) can separate components in refinery gas plant off gas to methane and a C₂₊cut which contains most or all of the olefinic materials. The methane can be used as refinery fuel 2011 and/or directed to a methanation unit 2004, and then to an OCM reactor 2005 with post-bed cracking. The methanation feed can be supplemented with additional natural gas 2012. The olefinic materials can be directed to an ETL reactor 2006. The OCM effluent can be routed to the ETL reactor. In some cases, the OCM effluent can also be routed to the PSA where the olefins produced in the OCM are also sent to the ETL reactor. In some cases, the OCM effluent may be hydrogenated before being sent to the PSA unit or ETL reactor. Some techniques may dictate the use of a cryogenic demethanizer in place of the PSA, but the application of PSA to pre-separate the refinery off-gas into a product stream and a tail gas stream containing the heavier hydrocarbons which is the feed to ETL reactor can result in significant cost savings. The product stream can contain methane, ethane, CO, CO₂, and other components, with of each component from 1 to 99%. A C₃₊stream 2013 from the refinery gas plant can be directed to a product fractionation system 2007, which can provide a C₂/C₃stream 2014 (which can be directed to the OCM reactor), an iC₄stream 2015, a gasoline blend stream 2016, and/or a kerosene/jet stream 2017.

Methods and systems of the present disclosure can be combined with or modified by other methods and systems, such as those described in U.S. patent application Ser. No. 14/591,850, filed Jan. 7, 2015, now published as U.S. Patent Pub. No 2015/0232395; U.S. patent application Ser. No. 13/936,783, filed Jul. 8, 2013, now published as U.S. Patent Pub. No. 2014/0012053; U.S. patent application Ser. No. 13/936,870, filed Jul. 8, 2013, now published as U.S. Patent Pub. No. 2014/0018589; U.S. patent application Ser. No. 13/900,898, filed May 23, 2013, now published as U.S. Patent Pub. No 2014/0107385; U.S. patent application Ser. No. 14/553,795, filed Nov. 25, 2014, now published as U.S. Patent Pub. No. 2015/0152025; U.S. patent application Ser. No. 14/592,668, filed Jan. 8, 2015, now published as U.S. Patent Pub. No. 2015/0210610; and U.S. patent application Ser. No. 14/789,953, filed Jul. 1, 2015, each of which is entirely incorporated herein by reference.

While preferred embodiments of the present invention have been shown and described herein, it will be obvious to those skilled in the art that such embodiments are provided by way of example only. It is not intended that the invention be limited by the specific examples provided within the specification. While the invention has been described with reference to the aforementioned specification, the descriptions and illustrations of the embodiments herein are not meant to be construed in a limiting sense. Numerous variations, changes, and substitutions will now occur to those skilled in the art without departing from the invention. Furthermore, it shall be understood that all aspects of the invention are not limited to the specific depictions, configurations or relative proportions set forth herein which depend upon a variety of conditions and variables. It should be understood that various alternatives to the embodiments of the invention described herein may be employed in practicing the invention. It is therefore contemplated that the invention shall also cover any such alternatives, modifications, variations or equivalents. It is intended that the following claims define the scope of the invention and that methods and structures within the scope of these claims and their equivalents be covered thereby.

Claims

1. A method for generating compounds with two or more carbon atoms (C2+ compounds), comprising: (a) directing oxygen (O2) and methane (CH4) into an oxidative coupling of methane (OCM) reactor that reacts said O2 and CH4 in an OCM process to yield a product stream comprising (i) C2+ compounds including ethylene (C2H4) and (ii) carbon monoxide (CO) and/or carbon dioxide (CO2); and(b) directing said product stream from said OCM reactor into a separations system that employs a refrigeration unit having a refrigerant that includes methane from said product stream, to enrich said C2+ compounds in said product stream.
2. The method of claim 1, wherein said product stream is directed into said separations system through one or more additional units.
3. The method of claim 1, further comprising separating methane from said product stream for use in said refrigeration unit.
4. The method of claim 1, further comprising directing CO and/or CO2 from said product stream to a methanation reactor that reacts said CO and/or CO2 to yield a methanation product stream comprising methane.
5. The method of claim 4, further comprising directing at least a portion of said methane in said methanation product stream to said OCM reactor.
6. The method of claim 1, further comprising separating said product stream into (i) an ethylene product stream comprising ethylene and (ii) a C3+ product stream comprising compounds with three or more carbon atoms (C3+ compounds).
7. The method of claim 1, further comprising directing ethane from said product stream to said OCM reactor.
8. The method of claim 1, further comprising, prior to directing said product stream into said separations system, compressing said product stream.

CROSS-REFERENCE

This application is a Continuation of U.S. application Ser. No. 14/868,911, filed Sep. 29, 2015, which claims priority to U.S. Provisional Patent Application No. 62/141,789, filed Apr. 1, 2015, which are entirely incorporated herein by reference.

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Related Publications (1)

	Number	Date	Country
	20200172452 A1	Jun 2020	US

Provisional Applications (1)

	Number	Date	Country
	62141789	Apr 2015	US

Continuations (1)

	Number	Date	Country
Parent	14868911	May 2015	US
Child	16445562		US

Advanced oxidative coupling of methane

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