Systems and methods of product gas recovery

Abstract

A device may include a primary product processing assembly configured to separate a source gas into an HC product gas and a tail gas. A device may include a CO2 plant configured to separate the tail gas into a CO2 product stream and a non-condensable stream. A device may include the system further comprising a recycle loop. A device may include a deoxygenation component operatively coupled to the recycle loop and configured to remove at least a portion of an oxygen constituent from a selected stream of the recycle loop.

Description

Attorney Docket No. AC02-0003-WOSYSTEMS AND METHODS OF PRODUCT GAS RECOVERYCROSS-REFERENCE TO RELATED APPLICATIONS

[0001] This application claims the benefit of and priority to U.S. Provisional Patent Application No. 63 / 691,890, filed on September 6, 2024 (Attorney Docket No. AC02-0003-P01) and U.S. Provisional Patent Application No. 63 / 748,628, filed on January 23, 2025 (Attorney Docket No. AC02-0003-P02). The foregoing applications are incorporated herein by reference in their entireties for all purposes.BACKGROUND

[0002] Presently known gas recovery systems suffer from a number of challenges. For example, recovery gas streams, such as landfill gas, have a number of constituents that are not primary natural gas constituents (e.g., methane), such as oxygen or CO2. Accordingly, high concentrations of those constituents can lead to excessive energy utilization to maintain high recycle rates, a significant portion of pumping energy committed to recycling non-valuable gas constituents, loss of hydrocarbon product (and / or other products) gas to purge streams, reduction in product quality, increases in operating risk, increases in undesirable side reactions, a reduction in production capacity (given a fixed or limited size for system components), and / or increases in capital and / or operating expenses for the system (e.g., increasing the size of system components to treat the non-valuable gas constituents, and / or increasing of flow rates, operating pressures, catalyst loading, system component utilization rates, and / or membrane capacity to compensate for the non-valuable gas constituents).SUMMARY

[0003] In some aspects, the techniques described herein relate to a gas recovery system, including: a primary product processing assembly configured to separate a source gas into an HC product gas and a tail gas; a CO2 plant configured to separate the tail gas into a CO2 product stream and a noncondensable stream; the system further including a recycle loop; and a deoxygenation component operatively coupled to the recycle loop and configured to remove at least a portion of an oxygen constituent from a selected stream of the recycle loop.

[0004] In some aspects, the techniques described herein relate to a gas recovery system, wherein the deoxygenation component includes a catalytic deoxygenation component.In some aspects, the techniques described herein relate to a gas recovery system, wherein the primary product processing assembly includes an acid gas based primary product processing assembly.

[0005] In some aspects, the techniques described herein relate to a gas recovery system, wherein the primary product processing assembly includes a swing adsorption based primary product processing assembly.Attorney Docket No. AC02-0003-WO

[0006] In some aspects, the techniques described herein relate to a gas recovery system, wherein the primary product processing assembly includes a membrane based primary product processing assembly.

[0007] In some aspects, the techniques described herein relate to a gas recovery system, further including a heat exchanger thermally coupled to the deoxygenation component.

[0008] In some aspects, the techniques described herein relate to a gas recovery system, further including a gas compression component fluidly coupled to the deoxygenation component.

[0009] In some aspects, the techniques described herein relate to a gas recovery system, further including a gas compression component on the upstream side fluidly coupled to the deoxygenation component with a CO2 plant on the downstream side.

[0010] In some aspects, the techniques described herein relate to a gas recovery system, further including a full flow deoxygenation component fluidly coupled to, and / or incorporated within, a CO2 plant.

[0011] In some aspects, the techniques described herein relate to a gas recovery system, wherein the deoxygenation component is interposed between the CO2 plant on an upstream side and a standalone membrane on a downstream side.

[0012] In some aspects, the techniques described herein relate to a gas recovery system, wherein the deoxygenation component is interposed between a standalone membrane on an upstream side and the CO2 plant on a downstream side.

[0013] In some aspects, the techniques described herein relate to a gas recovery system, wherein the tail gas includes a remainder gas stream from the source gas having a primary product stream removed therefrom.

[0014] In some aspects, the techniques described herein relate to a gas recovery system, wherein a primary product of the primary product stream includes at least one of methane or a low carbon count gas constituent.

[0015] In some aspects, the techniques described herein relate to a system, including: a CO2 plant configured to separate a tail gas of a primary product processing assembly into a CO2 product stream and a non-condensable stream; and a catalytic component configured to catalytically oxidize the noncondensable stream.

[0016] In some aspects, the techniques described herein relate to a system, wherein the catalytic component is interposed between the CO2 plant on an upstream side and a standalone membrane on a downstream side.Attorney Docket No. AC02-0003-WO

[0017] In some aspects, the techniques described herein relate to a system, wherein the catalytic component is interposed between a standalone membrane on an upstream side and the CO2 plant on a downstream side.

[0018] In some aspects, the techniques described herein relate to a system, wherein the primary product processing assembly includes an amine based separation system.

[0019] In some aspects, the techniques described herein relate to a system, wherein the tail gas includes a remainder gas stream from a source gas having a primary product stream removed therefrom.

[0020] In some aspects, the techniques described herein relate to a system, wherein a primary product of the primary product stream includes at least one of methane or a low carbon count gas constituent.

[0021] In some aspects, the techniques described herein relate to a system, including: a CO2 plant configured to separate a tail gas of a primary product processing assembly into a CO2 product stream and a non-condensable stream, wherein the CO2 plant includes, in fluid flow order: a deoxygenation component; a dehydration component; and a liquefaction component.

[0022] In some aspects, the techniques described herein relate to a system, wherein the CO2 plant further includes a gas compression component positioned upstream of the deoxygenation component.

[0023] In some aspects, the techniques described herein relate to a system, wherein the CO2 plant further includes a pretreatment component positioned upstream of the gas compression component.

[0024] In some aspects, the techniques described herein relate to a system, wherein the pretreatment component includes a carbon adsorption bed.

[0025] In some aspects, the techniques described herein relate to a system, wherein the tail gas includes a remainder gas stream from a source gas having a primary product stream removed therefrom.

[0026] In some aspects, the techniques described herein relate to a system, wherein a primary product of the primary product stream includes at least one of methane or a low carbon count gas constituent.

[0027] In some aspects, the techniques described herein relate to a gas recovery system, including: a primary gas recovery loop having a feed stream and a recovery stream; a CO2 plant configured to separate the recovery stream into a CO2 product fraction and a remainder; and a means for removing oxygen from the remainder.

[0028] In some aspects, the techniques described herein relate to a gas recovery system, wherein the means for removing oxygen is fluidly interposed into a recycle loop of the gas recovery system.Attorney Docket No. AC02-0003-WOBRIEF DESCRIPTION OF THE FIGURES

[0029] Fig. 1 depicts an example system to remove oxygen in a gas separation system between a CO2 plant and a standalone membrane.

[0030] Fig. 2 depicts an example system, compatible with the system depicted in Fig. 1, including a heat exchanger upstream of the O2 removal assembly.

[0031] Fig. 3 depicts another example system to remove oxygen in a gas separation system between a CO2 plant and a standalone membrane.

[0032] Fig. 4 depicts another example system to remove oxygen in a gas separation system between a primary separation membrane and a standalone membrane.

[0033] Fig. 5 depicts another example system to remove oxygen in a gas separation system between a CO2 plant and a standalone membrane.

[0034] Fig. 6 depicts another example system to remove oxygen in a gas separation system between a CO2 plant and a standalone membrane.

[0035] Fig. 7 depicts another example system to remove oxygen in a gas separation system between a CO2 plant and a standalone membrane.

[0036] Fig. 8 depicts another example system to remove oxygen in a gas separation system between a CO2 plant and a standalone membrane.

[0037] Fig. 9 depicts another example system to remove oxygen in a gas separation system between a CO2 plant and a standalone membrane.

[0038] Fig. 10 depicts another example system to remove oxygen in a gas separation system between a CO2 plant and a standalone membrane.

[0039] Fig. 11 depicts another example system to remove oxygen in a gas separation system between a CO2 plant and a standalone membrane.

[0040] Fig. 12 depicts another example system to remove oxygen in a gas separation system between a CO2 plant and a standalone membrane.

[0041] Fig. 13 depicts another example system to remove oxygen in a gas separation system between a CO2 plant and a standalone membrane.

[0042] Fig. 14 depicts another example system to remove oxygen in a gas separation system between a CO2 plant and a standalone membrane.

[0043] Fig. 15 depicts another example system to remove oxygen in a gas separation system between a CO2 plant and a standalone membrane.

[0044] Fig. 16 depicts another example system to remove oxygen in a gas separation system between a CO2 plant and a standalone membrane.Attorney Docket No. AC02-0003-WO

[0045] Fig. 17 depicts another example system to remove oxygen in a gas separation system between a CO2 plant and a standalone membrane.

[0046] Fig. 18 depicts another example system to remove oxygen between a CO2 plant and a standalone membrane for a CO2 recovery system from a primary gas separation tail gas.

[0047] Fig. 19 depicts another example system to remove oxygen upstream of a CO2 plant and a standalone membrane for a CO2 recovery system from a primary gas separation tail gas.

[0048] Fig. 20 depicts another example system to remove oxygen between a standalone membrane and a CO2 plant for a CO2 recovery system from a primary gas separation tail gas.

[0049] Fig. 21 depicts another example system to remove oxygen within a CO2 plant configured to recover CO2 from a primary gas separation tail gas.DETAILED DESCRIPTION

[0050] Example embodiments of the present disclosure provide for systems capable to perform essentially 100% recovery of a primary product (e.g., natural gas or methane) and a secondary product (e.g., CO2), from a gas source such as landfill gas and / or a biogas. Example embodiments of the present disclosure provide for reduced gas compression costs and recycle rates for a membranebased gas recovery system. Example embodiments of the present disclosure utilize residual pressure from a CO2 plant to operate a standalone membrane, and / or drive recycle gas for the gas recovery system. Example embodiments of the present disclosure integrate secondary recovery of a primary product, for example from a standalone membrane, for recycling to a gas source (e.g., a hydrocarbon enriched stream) and / or to a CO2 plant (e.g., a CO2 enriched stream). Example embodiments of the present disclosure provide for a zero-emission system.

[0051] Example embodiments of the present disclosure include an oxygen removal assembly positioned within the product gas recovery system. Oxygen in significant quantities within a gas recovery system can increase the risk of operations, result in streams within the recovery system that are chemically aggressive, and can increase the costs of operations - for example by increasing the energy requirement to recycle, compress, and / or otherwise treat a non-product constituent of the system. Further, significant oxygen concentrations in the system, which can be increased in systems that utilize a high recycle fraction and / or that achieve high product purities, can limit the treating capacity of the system due to the support of a high fraction of non-product constituents in the system. Still further, high oxygen fractions in the system can build up during recycle to the point where gas stream processing operations no longer function, and / or vent and / or purge streams need to be provided to allow the system to operate, which may increase the emissions of the plant.Attorney Docket No. AC02-0003-WO

[0052] These and other systems, methods, objects, features, and advantages of the present disclosure will be apparent to those skilled in the art from the following detailed description of the preferred embodiment and the drawings.

[0053] Embodiments herein provide for systems, procedures, and / or apparatuses for providing recovered process streams for renewable natural gas recovery and / or upgrading. Aspects of the present disclosure reference “natural gas” for clarity of the description. The term “natural gas” should be understood broadly, and includes renewable natural gas, landfill gas, fossil fuel natural gas, gas from biodigesters, and the like. Example recovered process streams include, without limitation, improved natural gas recovery (e.g., volume, composition, and / or recovery cost), secondary natural gas recovery, and / or carbon dioxide product recovery. In certain embodiments, example systems, procedures, and / or apparatuses for renewable natural gas recovery are applicable to any type of natural gas stream, and / or gas stream including typical natural gas constituents (e.g., low carbon count hydrocarbons, such as methane, ethane, propane, butane, etc.) as a major portion thereof, including for example processing of landfill gases, or any other type of gases, such as biogas, coming from certain food waste streams, farm product streams, manure sources, waste treatment plants, wineries, and / or any facility having organic waste associated therewith. Example and non- limiting product streams for embodiments herein include, without limitation, one or more of a primary natural gas stream, a secondary natural gas stream, and / or a carbon dioxide stream. In certain embodiments, a product stream, as utilized herein, may be provided as an explicit product stream (e.g., provided to an external system, such as a natural gas pipeline, etc.), utilized internally (e.g., in a burner, as a constituent supply stream, for in-situ electricity generation, etc.), stored for later delivery and / or utilization, etc. The description herein referencing a product stream should be understood broadly, where a product stream includes any stream that has been processed herein and is ready for utilization or further processing for a purpose. Throughout this disclosure, the terms carbon dioxide and CO2 are used interchangeably.

[0054] The description herein referencing certain streams as a permeate stream and / or a retentate stream are non-limiting examples for clarity of the present description. The number and arrangement of membranes, streams, and the like, is dependent upon the constituents of various streams, the characteristics of the membranes utilized (e.g., selectivity, permeability to various constituents being separated, operating pressures, etc.), system pressures, temperatures, and / or flow rates, or the like. The description herein referencing certain streams as product streams, permeate streams, retentate streams, intermediate streams, recycle streams, recovery streams, or the like, are non-limiting examples provided for clarity of the present description. Arrangements depicted herein, including arrangements described herein and / or consistent with descriptions herein, are non-limiting examples,Attorney Docket No. AC02-0003-WO and can be adjusted as described herein and / or as understood to one of skill in the art having the benefit of the present disclosure, and further such arrangements are not limited to naming conventions utilized herein.

[0055] Gas separation and purification processes may be used to maximize the value of carbon dioxide (CO2) capture and / or recovery at renewable natural gas (RNG) facilities and organic waste processing facilities, such as landfills and biodigesters. Disclosed herein are systems, apparatus, and methods that enable the capture of CO2 from organic waste. The disclosed systems, apparatus, and methods may also enable the conversion of captured CO2 into a usable form.

[0056] Systems depicted herein are depicted schematically, and depicted components thereof may be omitted and / or an omitted component may be added and / or substituted. For example, components to implement and / or adjust stream order and / or connection points (e.g., valves and / or manifolds) may be added, omitted, and / or substituted to implement described flow arrangements. In another example, pressurization components (e.g., a pump) may be added, for example to ensure desired flow rates and / or operating pressures are maintained, and / or depicted pressurization components may be omitted if they are not needed to support the desired flow rates and / or operating pressures for a particular embodiment.

[0057] It can be seen that embodiments herein can be configured for zero emissions, or stated differently, the source gas may be completely separated into a hydrocarbon product stream and a CO2 product stream, with no significant mass vented from the system as a purge gas, effluent, or the like. In certain embodiments, for example where some components are removed in conditioning steps (e.g., H2S, water, volatile organic compounds, oxygen, etc.), a zero emission embodiment is one where the entire remainder of the source gas after the conditioning is separated into a hydrocarbon product stream and a CO2 product stream, with no significant mass vented from the system. It will be understood that the embodiments herein provide for numerous benefits to gas recovery systems, and systems with zero emissions or with non- zero emissions are contemplated herein.

[0058] It can be seen that embodiments herein can be configured for minimum possible emissions, or stated differently the source gas may be completely separated into a hydrocarbon product stream, a CO2 product stream, and a minimum amount of purge material that allows for the separation to be performed with sufficient gas quality for the hydrocarbon product stream and / or CO2 product stream. For example, an adsorption component (e.g., a volatile organic compounds (VOC) pressure swing adsorber and / or temperature swing adsorber) may utilize flush gas to regenerate the adsorber, where the flush gas and entrained VOCs may be vented and / or oxidized to minimize flush gas emissions and prevent build-up of the VOCs (or other removed impurities) within the gas recovery systemAttorney Docket No. AC02-0003-WO and / or as a significant fraction of either product stream. Any swing adsorption component, as referenced herein, may be based on a pressure swing adsorption, temperature swing adsorption, vacuum swing adsorption, and / or any combination of these, regardless of whether the illustrative example depicts a TSA, PSA, or TSA / PSA (or similar terminology). It will be understood that the embodiments herein provide for numerous benefits to gas recovery systems, and systems with minimum possible emissions, or with higher levels of emissions, are contemplated herein.

[0059] Selection of components, stream arrangements, or the like, for embodiments herein may be selected or implemented based on a number of factors, such as the existing biogas upgrading process being employed, the purity and / or cleanliness of the inlet gas (e.g., presence of trace compounds, contaminants, the product fraction of the inlet gas including natural gas and / or CO2), the volume of methane and / or carbon dioxide that can potentially be re-captured, the intended utilization (e.g., onsite vs. shipping off-site), a comparison of grid electricity costs vs. using the methane to produce electricity on-site, the need or ability to use the electricity for non-CCh related uses, if returned methane (and / or natural gas) is desired as an outcome of the process, to meet one or more emissions requirements or comply with a policy, a capital expenditure associated with methane utilization, available space and / or infrastructure for new and / or upgraded equipment, a potential amount of revenue generated through renewable identification numbers (RINs) or other government incentive, an available transportation equipment, supply and demand for a given market, or the like.

[0060] The present disclosure relates to product gas recovery systems including, without limitation landfill gas recovery, other natural gas recovery, biomass gas recovery, and / or other gas recovery systems using similar unit operations, such as an amine gas recovery system, an adsorption based system, and / or a membrane based gas recovery system. The example applications are non-limiting.

[0061] Gas recovery streams often utilize recycling operations to enhance product purity and / or total recovery of product constituents. Systems that include a recycle can potentially build up concentrations of constituents that are not an intended product, which can increase pumping costs of essentially inert material, can lead to reductions in product purity, and / or constituent concentrations can build to the point where they are detrimental to the recovery process - for example due to non- negligible rates for side reactions and / or due to the concentration of the constituent (e.g., oxygen concentrations that exceed a threshold). In certain embodiments, high recycle rates, high product purity values, and / or low emissions values tend to increase the concentrations of non-product constituents in the steady state system.

[0062] During the CO2 processing steps, the non-condensable gases are removed to achieve a high- purity stream of CO2 (usually 99.95% pure or higher). Non-condensable gases are removed in the CO2 condensation step by syphoning them off together with some of the CO2 present in theAttorney Docket No. AC02-0003-WO condenser. Composition of this non-condensable stream is usually 75% CO2 and the remainder may include whichever non-condensable gases are present in the raw CO2 gas coming into the system. When significant CH4 is present in this stream, a standalone membrane 134 can be used to separate the CH4 from the CO2 and other non-condensable gases. In embodiments, the CH4 may be a product of the system. Depending on the selectivity of the standalone membrane 134 and the operating conditions, the system can be designed so that the retentate from the standalone membrane 134 is relatively high in CH4, and the permeate from the standalone membrane 134 is relatively high in CO2. Some of the other non-condensable that are present, such as O2, will tend to pass through on the permeate side of the membrane as well, often with a significant fraction also staying on the retentate side. In embodiments, more than half of the oxygen passes through on the permeate side.

[0063] An example standalone membrane 134 enables a zero emissions process due to its ability to recover both the CH4 from the retentate side of the standalone membrane 134 (which may be sent back to the RNG plant or used for power generation, etc., and which may include most of the N2) as well as the CO2 from the permeate side of the standalone membrane 134 (which may be sent back to the inlet side of the CO2 recovery plant). However, if the O2 concentration is high in the raw CO2 feed gas stream to the CO2 plant, the O2 will quickly build up in the system due to this re-cycle step, leading to a continued increase in O2 levels flowing through the CO2 plant. Increasing O2 levels in this feed stream may result in higher power requirements (lower CO2 processing efficiencies) as well as potential risks when the O2 concentration reaches certain levels (e.g., above certain thresholds, such as ~4%, may result in a flammable environment; such thresholds depend upon the specific composition of the gas stream), and take up capacity in the system to process this gas.

[0064] Due to the conditions at which the non-condensable stream (exiting the CO2 plant 122 and passing to the standalone membrane 134) is collected, for example with only CO2 and non- condensable gases at high pressure (e.g., 18 barg), is typically a smaller stream than the feed stream 104, typically includes no other contaminants such as sulfur or VOC’s, is very dry (e.g., dewpoint of -60 °C), and will typically have a higher oxygen concentration than the feed stream 104 (e.g., improving the rate of reaction in the catalytic component, allowing for a reduced catalyst loading, increased window of appropriate temperatures, improved mass transfer rates near the catalyst surface, etc.), embodiments of the present disclosure removing the oxygen from the non-condensable gas stream are more efficient in several axes (e.g., catalyst cost, power inputs, process complexity, etc.) compared to previously known systems that remove residual oxygen from the feed stream 104.

[0065] An example non-condensable stream is high in CO2 with a significant amount of residual CH4 (e.g., 75-80% CO2, 10-15% CH4, and 5-8% O2). Removing the O2, and optionally moisture as well (e.g., moisture generated in catalytic reactions on a deoxygenation catalyst), at this step allowsAttorney Docket No. AC02-0003-WO the permeate CO2 stream to be re-circulated to the inlet of the CO2 plant without a build-up of O2 in the system, and in some cases can reduce the overall O2 concentration in the process gas stream going through the CO2 plant leading to improved efficiencies and capacity utilization. In embodiments, the combined oxygen removal and standalone membrane operations result in a recirculated CO2 stream at high purity (e.g., -99%). In certain embodiments, a deoxygenation component, such as an oxidizing catalyst, removes oxygen while any oxidizing constituents are present in the treated gas, for example CH4 and / or VOCs. With respect to the CO2 product stream, the deoxygenation component may be present as a “full flow” deoxygenation component, where all of the product CO2 is treated with the deoxygenation component downstream of the potential introduction of VOCs into the final CO2 product stream (e.g., typically this will include mixing of trace VOCs present in the feed gas 104, that is not fully treated by the deoxygenation component), for example as depicted in Figs. 4, 19, and 21 . Such full flow embodiments provide for a highly polished CO2 product stream that contains virtually no VOCs and is robust to variability in the feed gas to the CO2 plant, for example due to VOC slugs and / or variability in a feed gas to the primary gas separation process and / or in a tail gas resulting from such a process (e.g., due to performance variability, dynamic or cyclical response of separation systems, etc.). In certain embodiments, the deoxygenation component may be present as a “partial flow” deoxygenation component, where the output of the deoxygenation component is mixed with other streams before contributing to the CO2 product stream, for example as depicted in Figs. 1-3, 5-18, and 20). Such partial flow embodiments are beneficial, for example to control maximum concentrations of constituents in the system that may build up due to recycle operations (e.g., O2, VOCs, and / or any constituent that is oxidizable under the conditions present at the deoxygenation component). In certain embodiments, a system may include both a full flow deoxygenation component and a partial flow deoxygenation component.

[0066] The terms deoxygenation component, O2 removal assembly, include components having an oxygen removal component such as an oxidation catalyst. In certain embodiments, additional components may be included therewith, for example to ensure that the gas conditions entering the oxidation catalyst are sufficient for proper operations, including for example the temperature and / or pressure of the gas. In certain examples, such additional components may be depicted for illustration, for example at Figs. 2 and 4, but they may optionally be included for any embodiments depending upon the properties of the feed gas (e.g., to the primary separation process), the tail gas of the primary separation process (and / or the source gas to the CO2 plant), the resulting gas conditions from the operations of various components in the system as a whole, and / or the operational variability in these. Such additional components may be considered as a part of an O2 removal assembly, and / or may be included with an O2 removal assembly or deoxygenation component.Attorney Docket No. AC02-0003-WO

[0067] An example advantage relevant to certain embodiments of the present disclosure, is that the disclosed waste stream (the non-condensable gas from the CO2 plant) comes out of the condenser at 250-300 psig and can first run through the O2 removal assembly 2002 using the waste pressure to remove the O2 before going through the standalone membrane 134. The pressure drop across the catalytic component of the O2 removal assembly 2002 is minimal (-around 10-20 psi), so there is plenty of pressure to do both steps without having to re-compress. In some embodiments, some additional de-compression may be utilized downstream of the O2 removal assembly 2002 and / or the standalone membrane 134, to operate the remaining parts of the system. In embodiments, some CH4 may be lost in the oxygen removal process, as the CH4 reacts with the catalyst and O2 to produce CO2 and H2O, but the loss is minimal. After the O2 is removed in the oxygen removal process (e.g., typically including removing H2O created in the catalytic reaction), the stream is directed through the standalone membrane 134, and the CO2 and CH4 are separated. The high CH4 stream (e.g., retentate) goes back to the biogas upgrading plant (pressure is available in this stream to go back into the process upstream or downstream of the compressor), and the high CO2 stream (permeate) can go back to the suction side of the CO2 plant compressor. By taking out the O2, the build-up of O2 when re-circulating the permeate back around to the CO2 plant is eliminated (and / or settles at a lower equilibrium concentration), enabling recovery of the entire non-condensable stream without having to vent off any of the product to avoid build-up of O2, and reducing pumping losses and / or gas treatment losses.

[0068] Another example advantage relevant to certain embodiments of the present disclosure is that the stream coming from the de-oxy unit going into the standalone membrane 134 may be at elevated temperature (e.g., -50 °C), which may be at or near desirable temperature for operation of the standalone membrane 134, and / or reduce operational costs to condition the gas to a desirable temperature for operation of the standalone membrane 134. Some of the elevated temperature may be due to energy released during catalysis, and some of the elevated temperature may be residual energy from heating (and / or compressing) the inlet to the de-oxy unit. A heat exchanger (e.g., reference Fig. 2) may be utilized to exchange heat between the typically cold non-condensable stream exiting the CO2 plant, and the heated gas exiting the de-oxy unit, which both recovers some of the residual heat into the de-oxy unit inlet (e.g., reducing the heating burden for any heating component utilized to condition the de-oxy unit inlet) and efficiently reduces the temperature of the de-oxy unit outlet before passing to the standalone membrane 134. Further, additional CO2 may be produced from the catalysis of O2.

[0069] In an embodiment, O2 removal can be done on the permeate side of the SAM, ignoring the methane stream, however there may be insufficient pressure to achieve desired flow and / or operatingAttorney Docket No. AC02-0003-WO pressure for a catalytic component, and may require compression (e.g., to 10-20 psi above the pressure desired downstream of the catalytic component).

[0070] Referencing Fig. 1 , an example system includes an amine assembly 2000 performing primary separation (e.g., separating a natural gas and / or methane primary product stream from a feed gas 104 stream, and providing a tail gas 101 to a CO2 plant that includes a CO2 rich stream from the primary product processing (the amine assembly 2000 in the example of Fig. 1)). The amine assembly 2000 may instead include another primary separation system, such as a swing adsorption system (e.g., a PSA or TSA / PSA, not shown, and / or a membrane based system, such as depicted in Figs. 3-17). The amine assembly 2000 creates a product gas 118 and a CO2 rich tail gas 101 passed to a CO2 plant 122 for CO2 recovery. The example system includes a standalone membrane 134 that enhances CO2 recovery (and amine recovery in certain configurations), with an O2 removal assembly 2002 fluidly interposed between the standalone membrane 134 and the non-condensable gas stream of the CO2 plant. The example system includes the retentate and / or CCh-poor stream 107 from the standalone membrane 134, which may be utilized as a purge stream, a recycle stream to any portion of the system (e.g., to the feed gas, at any stage within the conditioning operations for the feed gas, including upstream or downstream of compression operations), provided to a burner (e.g., to reduce concentrations of oxidizable constituents, and / or to provide heat energy), and / or utilized for energy recovery (e.g., in any manner, including oxidation, fuel cell reaction, mechanical / pressure energy recovery, etc.). Embodiments throughout the present disclosure may utilize the retentate and / or poor-CC stream 107 similarly to the examples set forth in relation to the example system of Fig. 1. The example standalone membrane 134 provides a CO2 rich stream 105 (e.g., on a permeate side) that is recycled to the CO2 plant 122 in the example of Fig. 1.

[0071] Referencing Fig. 2, an example O2 removal assembly 2002 and a heat exchanger 2102 that thermally couples the inlet and outlet streams of the O2 removal assembly 2002 is schematically depicted. The example embodiment of Fig. 2 may be included in any embodiments throughout the present disclosure, including without limitation embodiments depicted in Figs. 1 and 3-20, and / or any other embodiments having an O2 removal assembly 2002 and / or deoxygenation component 1802. The non-condensable stream from the CO2 plant 122 is typically cold, the O2 removal assembly 2002 is typically an oxidation catalyst requiting a significant temperature for proper operation, which is typically a higher temperature than can be tolerated by the standalone membrane 134. Accordingly, the heat exchanger 2102 can increase the temperature of the non-condensable stream leaving the CO2 plant 122 while decreasing the temperature of the treated non-condensable stream passed to the standalone membrane 134, significantly reducing the energy burden ofAttorney Docket No. AC02-0003-WO temperature management to condition gas streams for operation of the O2 removal assembly 2002 and / or standalone membrane 134.

[0072] Referencing Fig. 3, an example gas recovery system is depicted utilizing an O2 removal assembly 2002 between the CO2 plant 122 and the standalone membrane 134. The example of Fig.3 utilizes a CO2 rich stream from a membrane 108 of a primary separation process, where the primary separation process of Fig. 3 includes a second membrane 114 that provides primary product gas 1 18 and a recycle stream 120 that is passed back to the feed gas 104, between a conditioning component 103 and a compression component 106, in the example.

[0073] Referencing Fig. 4, an example gas recovery system is depicted utilizing an O2 removal assembly 2002 between a second membrane utilized in the primary gas recovery loop (e.g., providing the product gas 118) and the standalone membrane 134. The O2 removal assembly 2002 in the example of Fig. 4 may alternatively be positioned between a non-condensable stream of the CO2 plant 122 (e.g., the purge, recycle, and / or energy recovery stream) and the standalone membrane 134 (e.g., where the purge, recycle, and / or energy recovery stream is recycled to the standalone membrane 134, and / or where a second standalone membrane (not shown) is utilized) , and / or may be present where the non-condensable stream of the CO2 plant 122 may be recycled to the primary gas recovery loop (which provides a mechanism for oxygen build-up in the recycle loop). In certain embodiments, the O2 removal assembly 2002 may be fluidly interposed into the main recycle loop (e.g., from the TSA / PSA 510, to the activated carbon bed 512, to the first membrane 108, and recycled to the TSA / PSA 510) between any components thereof. Additionally, an N2 removal 514 component is fluidly interposed after membrane2 1 14 to and provides the product 1 18. The example of Fig. 4 depicts a number of optional compression components (e.g., pumps) that may be provided to condition the gas stream at various locations. The example optional compression components are non-limiting, and any embodiments of the present disclosure may include a compression component at any location to condition the gas stream for appropriate flow and pressure values. The example of Fig. 4 includes conditioning components 554, 558, 510, 512 for the primary product processing subsystem, which are optional and depicted for illustration, and which may be included in whole or part in any embodiment depicted throughout the present disclosure. Where a recycle to the primary product processing subsystem is present, such recycle may be returned to any position in the primary product processing subsystem, typically upstream of the first membrane 108, and the return location may depend upon the composition, temperature, and / or pressure of the recycled stream. The conditioning components may be depicted in a simplified form, such as conditioning component 103, and / or individual aspects of the conditioning components may be depicted, for example to illustrate certain aspects of the present disclosure. In the example of Fig. 4,Attorney Docket No. AC02-0003-WO the HC enriched stream from the first membrane 108 is passed to the second membrane, and the CO2 enriched stream from the first membrane 108 is utilized, at least selectively, to flush the TSA / PSA 510, with the flush remainder provided to an oxidizer 560 in the example (e.g., to reduce potential HC and / or VOC emissions).

[0074] Referencing Fig. 5, an example system includes the O2 removal assembly 2002 interposed between the CO2 plant 122 and a standalone membrane 134 in a system utilizing a CO2 PSA unit 602 that provides CO2 rich gas 604 to the CO2 plant, and recycles a product rich stream 608 (e.g., where the product is a hydrocarbon gas) to enhance primary product recovery. In the example of Fig. 5, the O2 removal assembly 2002 is in a recycle loop, due to the recycle of a hydrocarbon rich stream 610 to the primary product processing subsystem, where operations of the O2 removal assembly can manage oxygen concentrations in the system (e.g., including steady state and / or transient oxygen concentrations). In the example of Fig. 5, a CO2 rich stream 132 from the standalone membrane 134 may be purged, recycled to the CO2 plant, provided to a burner or oxidizer (e.g., to manage emissions), be utilized in an energy recovery system, and / or recycled to another location in the system.

[0075] Referencing Fig. 6, another example system that is similar to the example of Fig. 5 is schematically depicted. The example of Fig. 5 provides the tail gas 101 for CO2 recovery, provided from the first membrane 108 of the primary separation process, to a CO2 PSA unit 602, which recovers hydrocarbons from the tail gas 101, and provides them as a recycle stream 608 to the primary separation process. The example CO2 PSA unit 602 further provides a CO2 rich stream 604 to the CO2 plant 122 for final CO2 product stream 124 generation. The example of Fig. 6 provides the tail gas 101 as two separate streams, a first tail gas 101 A from the first membrane 108 to the CO2 plant 122, and a second tail gas 10 IB from the second membrane 114 to a CO2 PSA unit 602.

[0076] Referencing Fig. 7, another example system that is similar to the example of Fig. 5 is schematically depicted. In the example of Fig. 7, both tail gas streams 101 A, 101B are provided to the CO2 PSA unit, with the system otherwise similar to the example of Fig. 6.

[0077] Referencing Fig. 8, an example embodiment includes the tail gas 101 provided by a first membrane 108, where the primary separation process includes a VOC PSA 510 configured to remove VOCs and / or other selected constituents from the feed gas 104 before processing thorough the membranes 108, 114, and where a non-condensable stream from the CO2 plant 122 is at least selectively provided to either an O2 removal assembly 2002 and then to a standalone membrane 134 or utilized as a flush gas for the VOC PSA 510. In certain embodiments, the non-condensable stream may be provided to one or the other of the O2 removal assembly 2002 or the VOC PSA 510 (as a flush gas), and / or the non-condensable stream may be split between these, which may furtherAttorney Docket No. AC02-0003-WO depend upon the operating conditions of the system. In certain embodiments, the non-condensable stream is utilized for only one or the other of the O2 removal assembly 2002 or the VOC PSA 510. The expended flush gas 119 is passed from the system, potentially by venting, oxidizing, providing to a burner, and / or performing energy recovery on the stream (e.g., depending upon the VOC and / or other content providing usable energy, as well as the available energy recovery schemes to recover that energy). Referencing Fig. 9, an example system that is similar to the example of Fig. 8 is schematically depicted. The example system includes the tail gas 101 provided by the second membrane 114.

[0078] Referencing Fig. 10, an example system utilizes the CO2 rich stream from the first membrane 108, at least selectively, as a tail gas 101 for the CO2 plant, and / or as a flush gas 1001 for the VOC PSA 510. Further to the example of Fig. 10, a CO2 rich stream 132 from the standalone membrane 134 is at least selectively utilized as a flush gas for the VOC PSA 510, and / or as a recycle to the CO2 plant 122 (combinable with the flush gas 1001 in the example of Fig. 10). The example of Fig. 10 contemplates that the CO2 rich stream from the first membrane 108 may be always utilized as the flush gas 1001, always utilized as the tail gas 101, selectively utilized for one or the other, and / or at least selectively shared between the tail gas 101 and the flush gas 1001 . The example of Fig. 10 contemplates that the CO2 rich stream 132 from the standalone membrane 134 may be always utilized as a flush gas, always utilized for a recycle to the CO2 plant, selectively utilized for one or the other, and / or at least selectively shared between the tail gas and the recycle to the CO2 plant 122. The example of Fig. 10 contemplates that the CO2 rich streams from the first membrane 108 and the standalone membrane 134 may be used alternatively for the flush gas and tail gas, and / or may be combined during some or all operating conditions of the system. Referencing Fig. 11, an example system that is similar to the example of Fig. 10 is schematically depicted. The example of Fig. 11 utilizes the CO2 rich stream from the second membrane 114 to provide the tail gas 101 and / or flush gas 1001, and otherwise includes all options as set forth in relation to Fig. 10 preceding.

[0079] Referencing Fig. 12, an example system for providing a primary product stream 118 and CO2 product stream 124 from a feed stream 104 is schematically depicted. The example system includes a tail gas 101 from a first membrane 108 provided to a CO2 PSA unit 602, which provides a CO2 rich stream 604 to the CO2 plant, with the residual stream 608 utilized as a flush gas for the VOC PSA 510. Referencing Fig. 13, an example system that is similar to the example of Fig. 12 is schematically depicted, with the tail gas 101 provide from the second membrane 114 of the primary separation process. Referencing Fig. 14, an example system that is similar to the example of Fig. 12 is schematically depicted, with the residual stream 608 optionally and / or selectively provided as a flush gas for the VOC TSA / PSA 510, and / or provided as a recycle stream to the primary separationAttorney Docket No. AC02-0003-WO process (combined with the feed gas 104 in the example of Fig. 14, but which may be additionally or alternatively provided at a different position in the primary separation process, such as before the TSA / PSA 510, before the membrane 108, and / or before or after a pressurization component (e.g., depending upon the pressure and / or composition of the residual stream 608 and the pressures within the primary separation process). Referencing Fig. 15, an example system that is similar to the example of Fig. 14 is schematically depicted, with the tail gas 101 A, 101B provided by both membranes 108, 114, with the tail gas 101B from the second membrane 114 passed to a CO2 PSA unit 602, and with the residual stream 608 utilized to flush the TSA / PSA 510 and / or as a recycle stream to the primary separation process. Referencing Fig. 16, an example system that is similar to the example of Fig. 14 is schematically depicted, with the tail gas 101 A, 101B from both membranes passed to the CO2 PSA unit 602, and with the residual stream 608 utilized to flush the TSA / PSA 510 and / or as a recycle stream to the primary separation process. Source gas 104 enters the system, and eventually flow passes between membrane! 108 and membrane2 114. An N2 removal 514 component is optionally fluidly interposed after the membrane2 114 and to provide a final product stream 118. Referencing Fig. 17, an example system that is similar to the example of Fig. 12, with the flush gas for the VOC PSA 510 being provided by one or both of the residual stream 608 and the CO2 rich stream of the standalone membrane 134.

[0080] Referencing Fig. 18, an example gas recovery system includes a primary product processing assembly 1804 for a source gas 104. The example primary product processing assembly 1804 may include any type of processing assembly for separating a hydrocarbon constituent from the source gas. Example and non-limiting processing assemblies include, without limitation, a membrane based separation, adsorber based separation (e.g., temperature swing adsorption, pressure swing adsorption, vacuum adsorption, and / or a combination of these), and / or an acid gas based (e.g., amine) separation. The primary product processing 1804 may further include pre-treatment and / or conditioning components, depending upon the constitution of the source gas and / or the target constitution of the hydrocarbon product gas, where the pre-treatment and / or conditioning components may include, without limitation, volatile organic compound (VOC) removal, sulfur and / or H2S removal, dehydration, pressurization, or the like. The primary product processing assembly 1804 provides an HC product gas stream 118 and a tail gas stream 101. The tail gas stream 101 includes an elevated CO2 content, and may be, without limitation, a tail gas from an amine unit, a CO2 rich stream from one or more membrane separators of the primary product processing assembly, and / or a residual non-product gas from a PSA / TSA unit.

[0081] In the example of Fig. 18, the tail gas 101 is treated by a CO2 plant 122, and which may include a conditioning component, a compression component, a dehydration component, and / or aAttorney Docket No. AC02-0003-WO liquefaction component. The example CO2 plant 122 produces a CO2 product stream 124 and a noncondensable stream 1822. In the example of Fig. 18, the non-condensable stream 1822 is passed to a deoxygenation component 1802 that removes oxygen from the non-condensable stream 1822, and the deoxygenated non-condensable stream 1820 is passed to a standalone membrane 134 that separates the deoxygenated non-condensable stream into a CO2 enriched stream 132 and an HC enriched stream 610. An example CO2 plant utilizes a liquefaction and / or cryogenic process that condenses out the CO2 forming the CO2 product stream, and with remaining components (e.g., O2, N2, CH4, H2, etc.) forming the non-condensable stream 1822. Either or both of the HC rich 610 or CO2 rich 132 streams may be recycled in the system, which would result in a buildup of oxygen in the system at steady state operation, without the deoxygenation component 1802. For example, the HC rich stream 610 may be recycled to the primary product processing 1804 at any selected location, for example with the source gas 104, downstream of one or more conditioning components, and / or between membranes of the primary product processing 1804. The location of the HC rich recycle may be determined according to the composition of the HC rich stream, the pressure and / or temperature of the HC rich stream, the physical layout of the system, or the like. In another example, the CO2 rich stream 132 may be recycled to the CO2 plant 122, for example with the tail gas 101, downstream of one or more conditioning components, and / or before the liquefaction component of the CO2 plant 122. The location of the CO2 rich recycle may be determined according to the constitution of the CO2 rich stream, the pressure and / or temperature of the CO2 rich stream, the physical layout of the system, or the like. In certain embodiments, both of the HC rich stream 610 and the CO2 rich stream 132 may be recycled, in whole or in part. In certain embodiments, one or both of the HC rich stream 610 and / or CO2 rich stream 132 may, at least in part, be vented, utilized as a flush gas for an adsorption unit in the system, oxidized (e.g., in a burner), and / or utilized for energy recovery operations. Where a stream is utilized in part, that part may be in parallel (e.g., the HC rich stream 610 divided into recycle and energy recovery streams) and / or in series (e.g., the CO2 rich stream 132 is recycled to the CO2 plant during certain operating conditions, and utilized as a flush gas and / or divided between a flush gas stream and a recycle stream during other operating conditions). The described examples are non-limiting and provided for illustration of certain aspects of the system utilizing the deoxygenation component 1802.

[0082] Referencing Fig. 19, another example of a system utilizing a deoxygenation component 1802 is schematically depicted. In the example of Fig. 19, the deoxygenation component 1802 is positioned to treat the tail gas 101 between the primary product processing 1804 and the CO2 plant 122, providing stream 1902 to the CO2 plant 122. Referencing Fig. 20, another example of a system utilizing a deoxygenation component 1802 is schematically depicted. In the example of Fig. 20, theAttorney Docket No. AC02-0003-WO deoxygenation component 1802 is positioned to treat a recycle stream between the standalone membrane 134 the CO2 plant (provided as the CO2 enriched stream 132 from the standalone membrane 134). Referencing Fig. 21, another example of a system utilizing a deoxygenation component 2112 is schematically depicted. In the example of Fig. 21, the deoxygenation component 2112 is positioned to treat a stream within a CO2 plant 2102, for example upstream of a dehydration component 2114, where the CO2 plant 2102 is a part of another system (e.g., similar to any one of Figs. 1-20, positioned in place of the CO2 plant 122) and treats a tail gas 2104 of a primary product processing component (e.g., any tail gas 101, 101A, 101B as set forth in Figs. 1-20, and / or any other CO2 rich tail gas from a primary separation process). The specific arrangement of Fig. 21 positions the deoxygenation component 2112 downstream of a pretreatment component, such as the gas compression component 2110, to take advantage of the inherent pressure at that location, while avoiding unnecessary dehydration and liquefaction operations on the oxygen that would otherwise be present, but the specific arrangement of Fig. 21 is non-limiting, and the position of the deoxygenation component may be in other places within the CO2 plant and still benefit from a number of aspects of the present disclosure. The example of Fig. 21 includes a carbon adsorption bed 2108 operating as a conditioning component, as well as a liquefaction component 2118 that produces the resulting non-condensable stream 1822 and the CO2 product stream 124.

[0083] The deoxygenation component, or O2 removal assembly, as used herein, is configured to remove oxygen from the relevant stream according to any oxygen removal techniques known in the art. In certain embodiments, the oxygen removal technique that is selected should also be compatible with other gases in the stream, for example the product gas such as methane or similar natural gas constituents. An example and non-limiting O2 removal assembly includes a catalytic reactor with an appropriate catalyst (e.g., a palladium catalyst that can remove oxygen from a stream including methane). The oxygen removal process and catalyst selection is dependent on temperature and pressure at which the stream is treated.

[0084] In the catalytic removal example, the temperature at the selected location should be sufficient for catalytic activity to remove the oxygen (typically between 300-600 °C), and the pressure at the example location should be sufficient to support flow through the catalytic component (e.g., 10-20 psi) and in certain embodiments to perform separation operations with the standalone membrane. In certain embodiments, for example where the temperature and / or pressure of the stream at the location of the O2 removal assembly is not sufficient, the embodiment may include gas conditioning operations, for example to add or reduce the temperature, and / or to increase the temperature.

[0085] An example O2 removal assembly may include any other components or aspects that are indicated, for example to condition the gas stream, remove other undesired constituents, ensure theAttorney Docket No. AC02-0003-WO gas stream is dry, or the like. In certain embodiments, for example where sulfur or VOCs are present in the gas stream, other portions of the system may have already been removed and the gas stream is in a condition for direct treatment by a catalytic component. In a typical system, the noncondensable stream from the CO2 plant is very dry (e.g., dew point ~ -60 °C) and further conditioning may not be required. In certain embodiments, the O2 removal assembly may be any type of device, including for example an absorption, adsorption, and / or membrane based device. In certain embodiments, the system may include a heat exchanger that utilizes some of the temperature generated in the O2 removal assembly to heat another stream, for example where the reaction in the O2 removal assembly is an exothermic reaction.

[0086] The present disclosure may be utilized with any previously known gas recovery systems, with appropriate adjustments. Without limitation to any other aspect of the present disclosure, example embodiments herein may be utilized with any embodiments having a standalone membrane as set forth in pending patent applications: PCT International Application PCT / US2024 / 033071, filed June 7, 2024; PCT International Application PCT / US2024 / 033079, filed June 7, 2024; and PCT International Application PCT / US2024 / 033087, filed June 7, 2024, and may relate to membrane technology, amine systems, PSA systems, or the like. Each one of the foregoing PCT applications is incorporated herein by reference in the entirety for all purposes.

[0087] Certain logical groupings of operations herein, for example methods or procedures of the current disclosure, are provided to illustrate aspects of the present disclosure. Operations described herein are schematically described and / or depicted, and operations may be combined, divided, reordered, added, or removed in a manner consistent with the disclosure herein. It is understood that the context of an operational description may require an ordering for one or more operations, and / or an order for one or more operations may be explicitly disclosed, but the order of operations should be understood broadly, where any equivalent grouping of operations to provide an equivalent outcome of operations is specifically contemplated herein. For example, if a value is used in one operational step, the determining of the value may be required before that operational step in certain contexts (e.g., where the time delay of data for an operation to achieve a certain effect is important), but may not be required before that operation step in other contexts (e.g. where usage of the value from a previous execution cycle of the operations would be sufficient for those purposes). Accordingly, in certain embodiments an order of operations and grouping of operations as described is explicitly contemplated herein, and in certain embodiments re-ordering, subdivision, and / or different grouping of operations is explicitly contemplated herein.

[0088] Example and illustrative embodiments are set forth herein to provide a clear description of aspects of the present disclosure. Methods described herein may be embodied, in whole or part, inAttorney Docket No. AC02-0003-WO systems that perform the steps thereof, and may be distributed across devices in a number of ways, or all of the functionality may be integrated into a dedicated, standalone device, or other hardware.Components of systems set forth herein may be arranged in a number of ways to achieve goals as set forth herein, and / or to achieve other goals that are evident from the disclosure herein. All such permutations and combinations are intended to fall within the scope of the present disclosure.

Claims

1. Attorney Docket No. AC02-0003-WOCLAIMS1. A gas recovery system, comprising: a primary product processing assembly configured to separate a source gas into an HC product gas and a tail gas; a CO2 plant configured to separate the tail gas into a CO2 product stream and a noncondensable stream; the system further comprising a recycle loop; and a deoxygenation component operatively coupled to the recycle loop and configured to remove at least a portion of an oxygen constituent from a selected stream of the recycle loop.

2. The gas recovery system of claim 1, wherein the deoxygenation component comprises a catalytic deoxygenation component.

3. The gas recovery system of claim 1, wherein the primary product processing assembly comprises an acid gas based primary product processing assembly.

4. The gas recovery system of claim 1, wherein the primary product processing assembly comprises a membrane based primary product processing assembly.

5. The gas recovery system of claim 1, wherein the primary product processing assembly comprises a swing adsorption based primary product processing assembly.

6. The gas recovery system of claim 1, further comprising a heat exchanger thermally coupled to the deoxygenation component.

7. The gas recovery system of claim 1, further comprising a gas compression component fluidly coupled to the deoxygenation component.

8. The gas recovery system of claim 1, wherein the deoxygenation component is interposed between the CO2 plant on an upstream side and a standalone membrane on a downstream side.

9. The gas recovery system of claim 1, wherein the deoxygenation component is interposed between a standalone membrane on an upstream side and the CO2 plant on a downstream side.

10. The gas recovery system of claim 1, wherein the tail gas comprises a remainder gas stream from the source gas having a primary product stream removed therefrom.

11. The gas recovery system of claim 10, wherein a primary product of the primary product stream comprises at least one of methane or a low carbon count gas constituent.

12. A system, comprising: a CO2 plant configured to separate a tail gas of a primary product processing assembly into a CO2 product stream and a non-condensable stream; and a catalytic component configured to catalytically oxidize the non-condensable stream.Attorney Docket No. AC02-0003-WO13. The system of claim 12, wherein the catalytic component is interposed between the CO2 plant on an upstream side and a standalone membrane on a downstream side.

14. The system of claim 12, wherein the catalytic component is interposed between a standalone membrane on an upstream side and the CO2 plant on a downstream side.

15. The system of claim 12, wherein the primary product processing assembly comprises an amine based separation system.

16. The system of claim 12, wherein the tail gas comprises a remainder gas stream from a source gas having a primary product stream removed therefrom.

17. The system of claim 16, wherein a primary product of the primary product stream comprises at least one of methane or a low carbon count gas constituent.

18. A system, comprising: a CO2 plant configured to separate a tail gas of a primary product processing assembly into a CO2 product stream and a non-condensable stream, wherein the CO2 plant comprises, in fluid flow order: a deoxygenation component; a dehydration component; and a liquefaction component.

19. The system of claim 18, wherein the CO2 plant further comprises a gas compression component positioned upstream of the deoxygenation component.

20. The system of claim 19, wherein the CO2 plant further comprises a pretreatment component positioned upstream of the gas compression component.

21. The system of claim 20, wherein the pretreatment component comprises a carbon adsorption bed.

22. The system of claim 21, wherein the tail gas comprises a remainder gas stream from a source gas having a primary product stream removed therefrom.

23. The system of claim 22, wherein a primary product of the primary product stream comprises at least one of methane or a low carbon count gas constituent.

24. A gas recovery system, comprising: a primary gas recovery loop having a feed stream and a recovery stream; a CO2 plant configured to separate the recovery stream into a CO2 product fraction and a remainder; and a means for removing oxygen from the remainder.

25. The gas recovery system of claim 24, wherein the means for removing oxygen is fluidly interposed into a recycle loop of the gas recovery system.

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