WO2017184708A1

WO2017184708A1 - Systems and processes for natural gas liquid recovery

Info

Publication number: WO2017184708A1
Application number: PCT/US2017/028332
Authority: WO
Inventors: William B. Dolan
Original assignee: Basf Corporation
Priority date: 2016-04-22
Filing date: 2017-04-19
Publication date: 2017-10-26
Also published as: TW201807176A

Abstract

Disclosed herein is a process and system for recovering liquid hydrocarbon C3+ components from a natural gas liquid by subjecting a natural gas feed stream to an adsorber and a stabilizer.

Description

SYSTEMS AND PROCESSES FOR NATURAL GAS LIQUID RECOVERY

TECHNICAL FIELD

[0001] The present disclosure relates to a process and a system for treating a flow stream. Specifically, the present disclosure relates to a process and system for recovering natural gas liquid enriched with C3+ component.

BACKGROUND

[0002] Natural gas liquids (NGL) are hydrocarbons such as ethane, propane, butane, pentane, hexane, heptane etc. There are many industrial applications for NGLs in petrochemical plants as well as for space heating, cooking, and transportation fuels, to name a few. NGLs are typically extracted and/or purified in a processing plant prior to use in the various industries. NGL processing plants vary considerably in size, complexity, and configuration. These variations depend on a number of factors such as production characteristics, geography, customer specifications, and market drivers.

[0003] NGL extraction processes often use pressure relief valves as a protective measure from over-pressurization. Gas released through the pressure release valve is often routed to a flare system where the gas gets burned, also known as gas flaring. Gas flaring is particularly common in certain areas in the world lacking pipelines and other gas infrastructure. The NGL recovery process and systems described herein address wasteful gas disposal through gas flaring.

[0004] Nowadays, three process technologies are available for extracting hydrocarbon liquids from natural gas, namely, 1) straight refrigeration; 2) turboexpander; and 3) IPOR (IsoPressure Open Refrigeration). Straight refrigeration units are relatively simple to construct and operate and have proven economical and reliable. However, their operating temperature is limited to about -35 °F resulting in a limited capability for NGL recovery. Turboexpander units have often become the technology of choice for high NGL recovery. However, the turboexpander operates at temperatures as low as -200 °F resulting in high capital and operating costs. IPOR units offer a higher NGL recovery then straight refrigeration and operate at slightly higher temperatures then the turboexpander. Nevertheless certain process units and/or process streams in the IPOR units may still get as cold as -105 °F (about -76 °C) resulting in relatively high capital and operating costs. Moreover, in both the turboexpander and the IPOR technologies, an additional process unit and/or treatment step is needed to remove any water from the initial feed stream due to the cold temperatures.

[0005] There is a need in the art for a cost efficient process and system for high recovery of liquid hydrocarbons from NGL streams.

SUMMARY

[0006] In some embodiments, the present invention may be directed to an NGL recovery process for recovering NGL from a stream having a low C3+ components concentration. The process may comprise: feeding an initial fluid volume having a first concentration of C3+ components into an adsorber, the adsorber comprising a sorbent selective for C3+ components; contacting the initial fluid volume with the sorbent; generating an adsorber effluent volume having a second concentration of C3+ components; generating an adsorber bottom volume having a third concentration of C3+ components, the third concentration being greater than the second concentration; feeding the adsorber bottom volume to a stabilizer; and liquefying a first amount of the adsorber bottom volume.

[0007] In some embodiments, the present invention may be directed to an NGL recovery process for recovering NGL from a stream enriched with C3+ components, the process comprising: feeding an initial fluid volume having a first concentration of C3+ components into a stabilizer; liquefying a first amount of the initial fluid volume fed into the stabilizer; generating a second amount of the initial fluid volume fed into the stabilizer, the second amount having a second concentration of C3+ components; feeding the second amount into an adsorber, the adsorber comprising a sorbent selective for C3+ components; contacting the second amount of the initial fluid volume with the sorbent; generating an adsorber effluent volume having a third concentration of C3+ components; generating an adsorber bottom volume having a fourth concentration of C3+ components, the fourth concentration being greater than the third concentration and greater than the second concentration; and feeding the adsorber bottom volume to the initial fluid volume where the adsorber bottom volume and initial fluid volume may be mixed before being fed into the stabilizer.

[0008] In some embodiments, the present invention may be directed to a method for enriching C3+ components in the fluid volume prior to their extraction. In some embodiments, the present invention may be directed to a method of treating a fluid volume, the method comprising: contacting the fluid volume with a sorbent, wherein: the fluid volume has a first concentration of C3+ components prior to contacting, and a part of the fluid has a second concentration of C3+ components after the contacting, the second concentration being greater than the first concentration.

[0009] In some embodiments, the invention is directed to a system comprising a pressure swing adsorber comprising a sorbent adapted for adsorption of C3+ components from a fluid volume; and a stabilizer for recovery of liquid C3+ components, wherein the entire process operates at a temperatures greater than about 0 °C (about 32 °F). Alternatively if water is removed or methanol is injected to inhibit hydrate formation, the process may be run at temperatures of about -20 °F (about -29 °C) or above to allow for the use of carbon steel or other less costly materials of construction. In some embodiments, if water is present, the coldest temperature in the process may be the lowest operating temperature that will prevent hydrate formation in the various process units.

[0010] The term "C3+ components" refers to hydrocarbons having three or more carbons. For example a non-exhaustive list of C3+ components includes one or more of propane, butane, pentane, hexane, benzene, heptane, octane, nonane, decane, toluene, ethylbenzene, methyl-mercaptan, ethyl-mercaptan, xylene, etc.

[0011] The term "initial fluid volume" refers to a flow stream of starting material fed into the NGL processes and/or systems according to an embodiment. The initial fluid volume may comprise contaminants and/or components in addition to the C3+ components. An illustrative, non-exhaustive list of contaminants and/or components includes one or more of methane, ethane, water, carbon dioxide, etc.

[0012] The term "natural gas liquid" or "NGL" refers to the product resulting in the NGL processes and/or systems according to an embodiment. The product may be enriched with C3+ components but may also comprise residuals of certain contaminants and/or components. The product may comprise a greater concentration of C3+ components than the concentration of C3+ components in the initial fluid volume. Recovery of NGL and recovery of C3+ components may be used interchangeably.

[0013] The term "stabilizer" refers to a type of distillation column in which vapor NGL may be liquefied. The liquefaction will produce the final NGL which may then be trucked or placed in a pipeline to be transported.

BRIEF DESCRIPTION OF THE DRAWINGS

[0014] The above and other features of the present disclosure, their nature, and various advantages will become more apparent upon consideration of the following detailed description, taken in conjunction with the accompanying drawings, in which: [0015] Figure 1A illustrates a simplified diagram of a process for recovering NGL from a stream having low C3+ components concentration according to an embodiment.

[0016] Figure IB illustrates a simplified diagram of a process for recovering NGL from a stream having low C3+ components concentration according to an embodiment.

[0017] Figure 2 depicts a schematic of the process for recovering NGL according to the simplified diagrams of Figures 1A and IB.

[0018] Figure 3 illustrates a simplified diagram of a process for recovering NGL from a stream enriched with C3+ components.

[0019] Figure 4 depicts a schematic of the process for recovering NGL according to the simplified diagram of Figure 3.

[0020] Figure 5 A depicts a simplified diagram of a process for recovering NGL from a stream with water according to an embodiment.

[0021] Figure 5B depicts a simplified diagram of a process for recovering NGL from an initial fluid volume contaminated with water according to an embodiment.

[0022] Figure 6 depicts a simplified diagram of a process for recovering NGL from a stream with carbon dioxide.

[0023] Figure 7 depicts a simplified diagram of a method for treating a fluid volume according to an embodiment.

[0024] Figure 8 depicts a process flow diagram 800 of case study 1 of Example 1.

[0025] Figure 9 depicts a process flow diagram 900 of case studies 2 and 3 of Examples 2 and 3.

[0026] Figure 10 depicts a process flow diagram 1000 of case study 4 of Example 4.

[0027] Figure 11 depicts a process flow diagram 1100 of case study 5 of Example 5.

[0028] Figure 12 depicts a process flow diagram 1200 of case study 6 of Example 6. [0029] Figure 13 depicts a plot comparing C3+ recovery, horsepower, and coldest process temperature of existing straight refrigeration and IPOR technologies to an inventive technology according to an embodiment.

DETAILED DESCRIPTION

[0030] The present invention relates generally to a system for improved purification of gas streams and methods of use thereof. More specifically, the present invention relates to systems and processes for purification and recovery of C3+ components. The present invention is directed to an NGL recovery system and process that provide a C3+ component recovery that is either comparable or higher than the recovery obtained by any one of the liquid hydrocarbon extraction technologies available nowadays. The processes and systems discloses herein are able to achieve high liquid hydrocarbon recovery while operating at temperatures higher than the temperatures of the turboexpander and IPOR technologies, thereby allowing for lower cost materials of construction and operating costs.

[0031] In some embodiments, the present disclosure relates to processes for recovering C3+ components from initial fluid volume streams having a low concentration of C3+ component, from initial fluid volume streams enriched with C3+ components, and from initial fluid volume streams contaminated with water and/or carbon dioxide. In some embodiments, the present invention is directed to a method of treating a fluid volume to generate natural gas liquid. In some embodiments, the present invention is directed to a system comprising an adsorber, such as a pressure swing adsorber or a thermal swing adsorber, and a stabilizer. In the various embodiments disclosed herein, the coldest temperature in the process and/or in the system may range from about -30 °C to about 50 °C, from about 0 °C to about 50 °C, from about 5 °C to about 50 °C, from about 10 °C to about 30 °C, or from about 20 °C to about 40 °C. [0032] The various embodiments are now described with reference to the following figures and examples. Before describing several exemplary embodiments, it is to be understood that the present disclosure is not limited to the details of construction or process steps set forth in the following description. Other embodiments may be practiced or carried out in various ways in accordance with the principles described.

[0033] Figure 1A illustrates a simplified diagram of a process 100 for recovering NGL from a stream having low C3+ components concentration according to an embodiment. Figure IB illustrates a simplified diagram of a process 100B for recovering NGL from a stream having low C3+ components concentration according to another embodiment. Figure 2 depicts a schematic 200 of the process for recovering NGL according to the simplified diagrams of Figures 1A and IB. Figures 1A, IB, and 2 will be discussed concurrently. All numerals beginning with the numbers 1 will refer to elements depicted in Figures 1A and IB, where the numerals ending with a B refer to Figure IB only. All numerals beginning with the number 2 will refer to elements depicted in Figure 2.

[0034] The initial fluid volume fed into the process may be treated after having undergone preliminary treatment to remove certain impurities or increase the concentration of C3+ components elsewhere. Alternatively, the initial fluid volume fed into the process may be untreated and may undergo treatment in the NGL recovery process disclosed herein. An untreated fluid volume may optionally be fed into a compressor 110 or HOB via stream line 105 or 105B to generate the initial fluid volume pursuant to block 205. Initial fluid volume in stream line 105 or 105B may be routed through a compressor. Initial fluid volume in streams 105 or 105B may be mixed with recycle stream 165 to form stream lines 115 or 115B. Stream lines 115 or 115B, having a concentration Cl-A or Cl-AB of C3+ components, may optionally be at least 1.5 times more concentrated than stream line 105 or 105B entering the compressor. The initial fluid volume may range from about 0.2 MSCFH feed/ft 3 adsorbent 1 to about 10 MSCFH feed/ft adsorbent. It is to be understood that in certain embodiments the initial fluid volume may fall outside these ranges due to the considerable variations in processing plant and processing unit sizes, complexity, configurations, customer needs, etc.

[0035] The initial fluid volume in stream line 115 or 115B may have a first concentration of C3+ components (Cl-A or Cl-AB). Cl-A or Cl-AB may range from about 0.1 to about 50, from about 0.1 to about 24, from about 1 to about 50, from about 10 to about 40, from about 10 to about 35, or from about 10 to about 25 mole percent of C3+ components based on the total moles in the initial fluid volume and based on whether or not the optional recycle stream generated from a stabilizer's effluent (discussed in more detail below) will be mixed into the feed stream, as shown with streams 165 and 115 in Figure 1A, or will not be mixed into the feed stream, as shown with stream 165B and 115B in Figure IB. The initial fluid volume, after being mixed with optional recycle stream 165, may be fed via stream line 115 into adsorber 120, the adsorber having a sorbent selective for C3+ components, pursuant to block 210. Alternatively, the initial fluid volume may be fed via stream line 115B into adsorber 120B, pursuant to block 210, and subsequently, optional recycle stream 165B may be fed into adsorber 120B, pursuant to optional block 255. The process may further comprise contacting the initial fluid volume and/or the optional recycle stream with the sorbent, pursuant to block 215, to generate an adsorber bottom stream 125 or 125B (pursuant to block 220) and an adsorber effluent stream 135 or 135B (pursuant to block 225), having concentrations C3-A or C3-AB and C2-A or C2-AB, respectively, of C3+ components. Concentration C3-A or C3-AB from the adsorber bottom volume may be higher than concentration C2-A or C2-AB from the adsorber effluent stream.

¹ MSCFH feed/ft³ stands for (Million Standard Cubic Feet of Feed)/(hour* Cubic Feet of Adsorbent) [0036] In some embodiments, the adsorber may be a pressure swing adsorber. The pressure swing adsorber may comprise a sorbent selective to C3+ components. The adsorber may operate at a temperature range that will prevent hydrate formation in the adsorber (if water is present in the process). The temperature in the adsorber (depending on whether there is water in the process or not) may range from about -30°C to about 200 °C, from about -28 °C to about 200 °C, from about 0 °C to about 200 °C, from about 25 °C to about 150 °C, or from about 25 °C to about 70 °C. The sorbent may be selected from the group consisting of silica gel, alumina, potassium permanganate, zeolite (e.g., molecular sieve zeolites), metal organic frameworks (MOFs), activated carbon, molecular sieve carbon, polymer, resins, clays and combinations thereof. The sorbent may comprise a plurality of particles. In some embodiments, the sorbent may have optimal parameters, such as BET surface area, pore volume, bulk density, mass, volume, and diameter that will increase the sorbent' s affinity to C3+ components.

[0037] In some embodiments, the sorbent may comprise MOFs in a form of a powder, pellets, extrudates, granulates, or a free-standing film. In certain embodiments, the MOF is in the form of MOF particles. In some embodiments the adsorbent material is a zeolitic material having a framework structure composed of Y0₂ and X₂0₃, in which Y is a tetravalent element and X is a trivalent element. In one embodiment Y is selected from the group consisting of Si, Sn, Ti, Zr, Ge, and combinations of two or more thereof. In one embodiment Y is selected from the group consisting of Si, Ti, Zr, and combinations of two or more thereof. In one embodiment Y is Si and/or Sn. In one embodiment Y is Si. In one embodiment X is selected from the group consisting of Al, B, In, Ga, and combinations of two or more thereof. In one embodiment X is selected from the group consisting of Al, B, In, and combinations of two or more thereof. In one embodiment X is Al and/or B. In one embodiment X is Al. In certain embodiments the zeolite is in a form of particles, pellets, extrudates, granulates, a powder, or a free-standing film. In certain embodiments the zeolite is in a form of zeolite particles.

[0038] In certain embodiments, the sorbent may be activated. The activation may include subjecting the sorbent to various conditions including, but not limited to, ambient temperature, vacuum, an inert gas flow, or any combination thereof, for sufficient time to activate the sorbent material.

[0039] In a pressure swing adsorber, contacting the initial fluid volume with the sorbent and generating an adsorber effluent stream 135 or 135B may occur at an initial adsorption pressure. Generating the bottom volume stream 125 or 125B, having a higher concentration of C3+ components (C3-A or C3-AB), may occur at a final desorption pressure. The initial adsorption pressure may range from about 1 bar to about 70 bar, from about 5 bar to about 50 bar, or from about 10 bar to about 30 bar. The final desorption pressure may range from about 0.2 bar to about 6 bar, or from about 0.3 bar to about 2 bar.

[0040] A pressure swing adsorber may be programmed into cycle times, wherein the adsorption pressure is maintained for a predetermined duration optimal for efficient adsorption of the C3+ components (yet inefficient for the adsorption of undesired components). A non-limiting exemplary adsorption cycle time may range from about 20 seconds to about 10 minutes, from about 30 seconds to about 10 minutes, or from about 1 minute to about 4 minutes. After the adsorption cycle, an equalization cycle may be performed for a time period that is about four times shorter than the adsorption cycle time (ranging from about 5 seconds to about 2.5 minutes, from about 7.5 seconds to about 2.5 minutes, or from about 15 seconds to about 1 minute). Typically equalizations times may be long enough to ensure that the bed will not fluidize or lift during the equalizations step. At the completion of the cycle time, the pressure may be reduced to the final desorption pressure. The depressurization step may have a duration that is about twice to four times shorter than the adsorption cycle (e.g., ranging from about 5 seconds to about 2.5 minutes, from about 7.5 seconds to about 2.5 minutes, or from about 15 seconds to about 1 minute, from about 10 seconds to about 5 minutes, from about 15 seconds to about 5 minutes, or from about 30 seconds to about 2 minutes).

[0041] In some embodiments, the concentration C3-A or C3-AB of the adsorber's bottom volume stream 125 or 125B may be greater than the concentration Cl-A or Cl-AB of the initial feed volume of stream line 115 or 115B. In turn, concentration Cl-A or Cl-AB of the initial feed volume of stream line 115 or 115B may be greater than concentration C2-A or C2-AB of adsorber's effluent volume stream 135 or 135B. C3-A or C3-AB may be at least about three times greater than C2-A or C2-AB. In some embodiments, C3-A or C3-AB may be 100 mole% of C3+ components based on the total moles of the fluid in stream 125 or 125B, and stream 135 or 135B may contain no C3+ components, i.e. C2-A or C2-AB may be zero. In some embodiments, C3-A or C3-AB may be at least about two to about 100 times greater than Cl-A or Cl-AB. C3-A or C3-AB may range from about 10 mole% to about 80 mole%, from about 25 mole% to about 80 mole%, or from about 30 mole% to about 80 mole% of C3+ components based on the total number of moles in stream 145 or 145B (or 125 or 125B).

[0042] The process may further comprise optionally feeding the adsorber's bottom volume of stream 125 or 125B into a compressor 130 or 130B, pursuant to block 230, and generating volume stream 145 or 145B. Pursuant to block 235, the process may further comprise feeding volume stream 145 or 145B (or 125 or 125B if no compressor was present) into stabilizer 140 or 140B. The stabilizer may operate at a temperature range and pressure range that will prevent hydrate formation in the stabilizer if water is present in the process. The temperature in the stabilizer may vary depending on whether water is present in the process or not and may range from about -28 °C to about 150 °C, or from about 5 °C to about 150 °C. The pressure in the stabilizer may range from about 5 bar to about 50 bar or from about 10 bar to about 30 bar. If water is present in the process, the operating temperature of the stabilizer may be higher than the temperature of hydrate formation. If water is absent in the process, the operating temperature of the stabilizer may be at the lower range from the temperature ranges recited above.

[0043] Subsequently, the process may comprise, pursuant to blocks 240 and 245, generating a first amount and a second amount of the adsorber's bottom volume, respectively. The first amount of adsorber's bottom volume may be liquefied via stream 155 or 155B and pursuant to block 250. The bottom of the stabilizer may have an operating temperature ranging from about 30 °C to about 200 °C, from about 40 °C to about 120 °C, or from about 50 °C to about 90 °C. The liquid C3+ components may be the final NGL recovered in the process depicted in this embodiment. In some embodiments, the process may comprise recovering about 70% or more, about 80% or more, about 85% or more, about 90% or more, about 95% or more, about 98% or more of the C3+ components present in the initial fluid volume fed to the NGL recovery process calculated based on the mole fraction of the C3+ components in stream 155 or 155B and the mole fraction of the C3+ components in the initial feed stream.

[0044] The second amount of the bottom volume, flowing through the stabilizer's effluent stream, may optionally be recycled via stream 165 directly into the initial feed volume, where streams 165 and 115 may be mixed prior to feeding them to adsorber 120. In other embodiments, the second amount of the bottom volume, flowing through the stabilizer's effluent stream, may optionally be recycled via stream 165B and fed sequentially to adsorber 120B (e.g., feed stream 115B may be fed to adsorber 120B first and recycle stream 165B may be fed to the adsorber afterwards). Prior to recycling, the process may comprise feeding the second amount of the bottom volume to the stabilizer's overhead condenser, operating at a temperature that will prevent hydrate formation in the stabilizer's overhead condenser, in processes where water is present. In some embodiments, if water is absent the stabilizer's overhead condenser may operate at lower temperature than if water had been present. The temperature of the stabilizer's overhead condenser may range from about - 30 °C to about 50 °C, from about 5 °C to about 50 °C, from about 10 °C to about 30 °C, or from about 20 °C to about 40 °C. In some embodiments, it may be advantageous to operate the stabilizer's overhead condenser at higher temperatures that could condense the C3+ components without additional refrigeration.

[0045] Figure 3 illustrates a simplified diagram of a process 300 for recovering NGL from a stream enriched with C3+ components. Figure 4 depicts a schematic 400 of the process for recovering NGL according to the simplified diagram of Figure 3. Figures 3 and 4 will be discussed concurrently. All numerals beginning with the numbers 3 and 4 will refer to elements depicted in Figures 3 and 4, respectively.

[0046] The initial fluid volume fed into the process may have a first concentration of C3+ components (Cl-B). Cl-B may range from about 40 to about 100, from about 50 to about 100, from about 55 to about 90, or from about 65 to about 85 mole percent of C3+ components based on the total moles of the initial fluid volume. The initial fluid volume may be fed via stream line 305 into stream line 315, which is then fed into stabilizer 330, pursuant to block 405. The initial fluid volume may range from about 0.2 MSCFH feed/ft adsorbent to about 10 MSCFH feed/ft adsorbent. The stabilizer may operate at a temperature range that will prevent hydrate formation in the stabilizer (when water is present in the process). When water is absent from the process, the stabilizer may operate at lower temperatures as compared to the operating temperatures when water is present. The stabilizer's operating temperature may range from about -30 °C to about 150 °C, from about 5 °C to about 150 °C and operating pressure may range from about 5 bar to about 50 bar or from about 10 bar to about 30 bar.

[0047] Subsequently, the process may comprise, pursuant to blocks 410 and 420, generating, in the stabilizer, a first amount and a second amount of the initial fluid volume, respectively. The first amount of initial fluid volume, generated in the stabilizer, may be liquefied via stream 325 and pursuant to block 415. The liquid C3+ components may be the final NGL recovered in the process depicted in this embodiment. The process may comprise recovering about 70% or more, about 80% or more, about 85% or more, about 90% or more, about 95% or more, about 98% or more, or from about 70% to about 99% of the C3+ components present in the initial fluid volume fed to the NGL recovery process calculated based on the mole fractions of the C3+ components in the stream 325 and the mole fraction of the C3+ components in the initial feed stream 305.

[0048] The process may comprise feeding the second amount of the bottom volume, generated in the stabilizer, to the stabilizer's overhead condenser. In some embodiments, when water is present in the process, the stabilizer's overhead condenser may operate at a temperature that will prevent hydrate formation in the stabilizer's overhead condenser. In other embodiments, the stabilizer's overhead condenser may operate at lower temperatures that its operating temperature when water is present in the process. The stabilizer's overhead condenser operating temperature may range from about -30 °C to about 50 °C, from about 0 °C to about 50 °C, from about 5 °C to about 50 °C, from about 10 °C to about 30 °C, or from about 20 °C to about 40 °C. The second amount of the initial fluid volume, generated in the stabilizer, may have a second concentration (C2-B) of C3+ components. The process may comprise feeding stream 335, having concentration C2-B of C3+ components, into an adsorber 310, pursuant to block 425. The adsorber may be a pressure swing adsorber and it may comprise a sorbent selective for C3+ components. The sorbent may be selected from the group consisting of silica gel, alumina, zeolite, MOFs and carbon. The sorbent may comprise a plurality of particles. In some embodiments, the sorbent may have optimal parameters, such as BET surface area, pore volume, bulk density, mass, and volume that will increase the sorbent' s affinity to C3+ components. The adsorber may operate at a temperature ranging from about -30 °C to about 200 °C, from about 0 °C to about 200 °C, from about 25 °C to about 150 °C, or from about 25 °C to about 70 °C. In some embodiments, the adsorber may operate at a temperature that will prevent hydrate formation in the adsorber (if water is present in the process).

[0049] The process may further comprise contacting the second amount of the initial fluid volume, generated in the stabilizer, with the sorbent in the adsorber (pursuant to block 430) to generate bottom stream 345 (pursuant to block 440) and effluent stream 355 (pursuant to block 435), having concentrations C4-B and C3-B, respectively, of C3+ components. Concentration C4-B from the bottom volume may be higher than concentration C3-B from the effluent stream. C4-B may also be higher than C2-B, the concentration of stream 335, entering the adsorber. C2-B may be higher than C3-B.

[0050] In some embodiments, C4-B may range from about 10 mole% to about 80 mole%, from about 20 mole% to about 70 mole%, from about 30 mole% to about 65 mole%, or from about 40 mole% to about 60 mole% of C3+ components based on the total moles of the fluid in stream 345. Stream 355 may contain up to about 30 mole%, up to about 20 mole%, up to about 10 mole%, or up to about 5 mole% of C3+ components based on the total moles of the fluid in stream 355, i.e. C3-B may be zero. In some embodiments, C4-B may be at least three times greater than C3-B. In some embodiments, C2-B may range from about 5 mole% to about 60 mole%, from about 5 mole% to about 50 mole%, or from about 20 mole% to about 50 mole% of C3+ components based on the total moles of the fluid in stream 335, and C4-B may be about two to about 100 times greater than C2-B. [0051] In a pressure swing adsorber, contacting the second amount of the initial fluid volume, generated in the stabilizer, with the sorbent and generating an adsorber effluent stream 355 may occur at an initial adsorption pressure. Generating the adsorber's bottom volume stream 345, having a higher concentration of C3+ components, may occur at a final desorption pressure. The initial adsorption pressure may be higher than the final desorption pressure. The initial adsorption pressure may range from about 1 bar to about 70 bar, from about 5 bar to about 50 bar, or from about 10 bar to about 30 bar. The final desorption pressure may range from about 0.2 bar to about 6 bar, or from about 0.3 bar to about 2 bar.

[0052] A pressure swing adsorber may be programmed into cycle times, wherein the adsorption pressure is maintained for a predetermined duration optimal for efficient adsorption of the C3+ components (yet inefficient for the adsorption of undesired components). A non-limiting exemplary adsorption cycle time may range from about 20 seconds to about 10 minutes, or from about 1 minute to about 4 minutes. At the completion of the cycle time, the pressure may be reduced to the final desorption pressure.

[0053] The process may further comprise optionally feeding the adsorber's bottom volume of stream 345, having a concentration C4-B, into a compressor 320, pursuant to block 445, and generating a volume stream 365 to form a stream 315 having a fifth concentration (C5-B) of C3+ components, wherein C5-B may be greater than C4-B.

[0054] Figure 5 A depicts a simplified diagram of a process 500 for recovering NGL from an initial fluid volume stream contaminated with water according to an embodiment. Figure 5B depicts a simplified diagram of a process 500B for recovering NGL from an initial fluid volume contaminated with water according to another embodiment. All numerals beginning with the numbers 5 will refer to elements depicted in Figures 5 A and 5B, where the numerals ending with a B refer to Figure 5B only. [0055] The initial fluid volume may optionally be fed via stream 505 or 505B into compressor 510 or 510B to generate stream 515 or 515B. Streams 515 or 515B may be fed into an adsorber 520 or 520B, such as a pressure swing adsorber. The adsorber may generate an effluent stream 535 or 535B and a bottom stream 525 or 525B having concentrated stream of C3+ components, i.e., the concentration of C3+ components in stream 525 or 525B may be greater than the concentration of C3+ components in stream 515 or 515B. Bottom stream 525 or 525B may optionally be fed into compressor 530 or 530B to obtain stream 545 or 545B.

[0056] Concentrated stream 545 or 545B may comprise water which may be removed prior to the stabilizer. Stream 545 or 545B may be fed into a three phase separator 540 or 540B to remove water from the stream. The three phase separator may generate bottom stream 555 or 555B comprising water, middle stream 565 or 565B comprising liquid organic (enriched with C3+ components), and effluent stream 575 or 575B comprising organic chemicals in a gas phase. The water separated in bottom stream 555 or 555B may be removed from the process and middle and effluent streams 565 or 565B and 575 or 575B may be fed into stabilizer 550 or 550B. Stabilizer 550 or 550B may generate a stabilizer bottom stream 585 or 585B comprising high purity and high concentration of C3+ components. Stabilizer bottom stream 585 or 585B may be liquefied to form the final NGL product. The stabilizer may also generate effluent stream 595 or 595B, having a low concentration of C3+ components. Effluent stream 595 or 595B may pass through the stabilizer's overhead condenser and may then be optionally recycled into the adsorber. In an embodiment, effluent stream 595 may be fed back into the stream 515 (or 505), wherein streams 515 (or 505) and 595 may be mixed prior to feeding them into adsorber 520. In other embdiments, effluent stream 595B may be fed into the adsorber 520B sequentially in a separate step, for example, after feed stream 515B (or 505B) is fed into adsorber 520B. This embodiment may be pursued if stream 595B has a higher a C3+ component concentration then the concentration of C3+ components in streams 515B (or 505B).

[0057] Figure 6 depicts a simplified diagram of process 600 for recovering NGL from an initial fluid volume stream contaminated with carbon dioxide. The initial fluid volume may optionally be fed via stream 605 into compressor 610 to generate stream 615. Stream 615 may be fed into an adsorber 620, such as a pressure swing adsorber. The adsorber may generate an effluent stream 635 and a bottom stream 625 having a concentrated stream of C3+ components, i.e., the concentration of C3+ components in stream 625 may be greater than the concentration of C3+ components in stream 615 (or 605 when there is no compressor). Bottom stream 625 may optionally be fed into compressor 630 to generate stream 645.

[0058] Stream 645 may be fed into stabilizer 640. Stabilizer 640 may generate a stabilizer bottom stream 655 comprising high purity and high concentration of C3+ components. Stabilizer bottom stream 655 may be liquefied to form the final NGL product. The stabilizer may also generate effluent stream 665, having a low concentration of C3+ components and further contaminated with carbon dioxide. Effluent stream 665 may pass through the stabilizer's overhead condenser and may then be fed into a separation device 650 (e.g., membrane, or adsorption vessel with a sorbent that is selective to carbon dioxide over C3+ components) suitable for adsorbing and/or removing carbon dioxide. Separation device 650 may generate two streams 675 and 685. Stream 685 may be enriched with carbon dioxide removed from the process and may contain a small concentration of C3+ components. Stream 675 may be fed into initial fluid volume stream 615.

[0059] Figure 7 illustrates a diagram of process 700 directed to a method of treating a fluid volume, the method comprising: contacting the fluid volume with a sorbent 710, wherein: the fluid volume has a first concentration (CI), in stream 720, of C3+ components prior to contacting, and a part of the fluid has a second concentration (C2), in stream 730, of C3+ components after the contacting, the second concentration being greater than the first concentration. The method may further comprise in block 740, liquefying the part of the fluid volume having a second concentration (i.e. stream 730) of C3+ components, wherein the resulting liquid may have a third concentration of C3+ components (C3 in stream 750), the third concentration may be greater than the second concentration. The part of the fluid volume with lower concentration of C3+ component may be directed via stream 760 to subsequent process steps.

[0060] In some embodiments, the invention is directed to a system comprising a pressure swing adsorber comprising a sorbent adapted for adsorption of C3+ components from a fluid volume; and a stabilizer for recovery of liquid C3+ components (passing through a stabilizer's overhead condenser) at temperatures ranging from about -30 °C to about 50 °C, from about 0 °C to about 50 °C, from about 5 °C to about 50 °C, from about 10 °C to about 30 °C, or from about 20 °C to about 40 °C. In some embodiments, the temperature may be such that it will prevent hydrate formation in the stabilizer' s overhead condenser. The sorbent in the pressure swing adsorber may be selected from the group consisting of silica gel, alumina, zeolite, MOFs and carbon. The sorbent may be adapted to contact the fluid volume such that when the fluid volume has a first concentration of C3+ components, the fluid volume has a second concentration of C3+ components, wherein the second concentration may be from about two to about 100 times greater than the first concentration. In some embodiments the pressure swing adsorber and/or the stabilizer may be constructed of stainless steel or any other material compatible with the fluid volume passing through.

EXAMPLES [0061] The following examples are set forth to assist in understanding the embodiments described herein and should not be construed as specifically limiting the embodiments described and claimed herein. Such variations, including the substitution of all equivalents now known or later developed, which would be within the purview of those skilled in the art, and changes in formulation or minor changes in experimental design, are to be considered to fall within the scope of the embodiments incorporated herein.

Example 1 - Case Study of NGL Recovery from a Feed with Normal - Enriched C3+ Levels

[0062] The following example illustrates a simulated case study performed on the process flow diagram illustrated in Figure 8. The adsorption bed in the simulation had a volume of 18.1 m , a length of 2.8 m, and a diameter of 2.8 m. The process conditions and stream compositions (in mole%) of the input and output streams are illustrated in Table 1 below.

Table 1 - C3+ Components Recovery of Case Study 1

[0063] Table 1 illustrates an increase in the concentration of C3+ components in the stabilizer bottom stream when compared to the concentration of C3+ components in the feed stream. The temperature utilized in the simulation for the stabilizer' s overhead condenser was about 7 °C. The power utilized in the simulation was about 408.3 kw in the first stage and about 519.5 kw in the second stage.

[0064] Table 2 illustrates the process conditions and stream compositions of the various streams in the process. In Figure 8, feed stream 811 is mixed in ΜΓΧ-801 with treated adsorber bottom stream 851 to form stream 849. Stream 849 is fed into a stabilizer 820 to form a stabilizer bottom stream 848 enriched with C3+ components and a stabilizer effluent stream 847, which is recycled to the adsorber system 810. Stream 842 is the adsorber effluent stream containing high levels of CI and C2 components and low residue of C3 component. Stream 842 undergoes treatment through additional process units (compressor K-802) resulting in stream 867 with an elevated temperature and pressure. Stream 843 is the adsorber bottom stream containing high levels of C3+ components and low residues of CI and C2 components. Stream 843 undergoes treatment in additional process units and streams (flowing through K-800, 856, E-803, 804, K-801, 812, E-804, 857, and E-802) varying the temperature and pressure of the fluid.

[0065] Process units K-800, K-801, and K-802 designate compressors for adjusting the pressures of the streams and/or process units. E-803, E-804, and E-802 designate heat exchangers for adjusting the temperatures of the streams and/or process units. MIX-801 designates a mixing valve and/or mixing vessel for combining a plurality of streams. The stream numbers in Figure 8 correspond to the stream numbers in Table 2. Table 2 - C3+ Components Composition in Various Streams of Case Study 1

Example 2 - Case Study of NGL Recovery Process from a Feed with Low C3+ Levels

[0066] The following example illustrates a simulated case study performed on the flowsheet illustrated in Figure 9. The adsorption bed in the simulation had a volume of 8.8 m , a length of 2.9 m, and a diameter of 2.0 m. The process conditions and stream compositions (in mole%) of the input and output streams are illustrated in Table 3 below.

Table 3 - C3+ Components Recovery of Case Study 2

Hexane + 0.36 mole% 6.65 mole%

(C6+)

[0067] Table 3 illustrates an increase in the concentration of C3+ components in the stabilizer bottom stream when compared to the concentration of C3+ components in the feed stream. The temperature utilized in the simulation for the stabilizer' s overhead condenser was about 7 °C. The power utilized in the simulation was about 48 kw in the first stage, about 44 kw in the second stage, and about 35 kw in the third stage. The power utilized by the pumps in the simulation was about 0.09 kw for the first pump and about 0.32 kw for the second pump. Together the total power utilized in the process was about 127.41 kw (170.73 hp). [0068] Table 4 illustrates the process conditions and stream compositions of the various streams in the process. In Figure 9, feed stream 911 is mixed in MIX-900 with a recycle stream 947 from the stabilizer's effluent to form stream 949. Stream 949 is fed into the adsorber system 910. Stream 942 is the adsorber effluent stream containing high levels of CI and C2 components and low residue of C3 component. Stream 942 undergoes treatment through additional process units (compressor K-902) resulting in stream 967 with an elevated temperature and pressure. Stream 943 is the adsorber bottom stream containing high levels of C3+ components and low residues of CI and C2 components. Stream 943 undergoes treatment in additional process units and streams (K-900, 956, E-903, 904, V-901, 903, K- 901, 912, E-904, 957, 962, V-900, 902, K-903, 901, E-902, and 961). Ultimately, stream 963, which is fed to the stabilizer 920, is formed. A stabilizer bottom stream 948 enriched with C3+ components and a stabilizer effluent stream 947, which is recycled to the adsorber system, are generated.

[0069] Process units K-900, K-901, K-902 and K-903 designate compressors for adjusting the pressures of the streams and/or process units. Process units E-903, E-904, and E-902 designate heat exchangers for adjusting the temperatures of the streams and/or process units. MIX-900 designates a mixing valve and/or mixing vessel for combining a plurality of streams. V-901 and V-900 designate process units that may be used for the separation of water from the stream for example. The stream numbers in Figure 9 correspond to the stream numbers in Table 4.

Table 4 - C3+ Components Composition in Various Streams of Case Study 2

[0070] Process units V-901 and V-900 in the simulation were used to remove water for the process as evident from the compositions of streams 904, 903, 962 and 957, 902, 961 summarized in table 5 below. Bottom streams 962 and 961 are enriched with water which is removed from the process with pump P-900 and pump P-901.

Table 5 - Water Composition in Various Streams of Case Study 2

V-901 V-900 V-900 V-900

Stream V-901 Feed V-901 Bottom

Effluent Feed Effluent Bottom 904 903 962 957 902 961

Temperature (C) 20 20 20 20 20 20

Pressure (bar) 2.758 2.758 2.758 7.584 7.584 7.584

Molar Flow

54.25 54.25 0.00 54.25 49.41 0.2468 (kgmole/h)

Methane (mole%) 30.42 30.42 0.00 30.42 33.26 0.00

Ethane (mole%) 20.70 20.7 0.00 20.7 22.19 0.00

Propane (mole%) 31.10 31.10 0.00 31.1 31.49 0.00 i-butane (mole%) 5.47 5.47 0.00 5.47 4.97 0.00 n-butane (mole%) 6.23 6.23 0.00 6.23 5.29 0.00 n-pentane (mole%) 2.88 2.88 0.00 2.88 1.62 0.00

Hexane+

2.22 2.22 0.00 2.22 0.61 0.00 (C6+, mole%)

H₂0 mole % 0.74 0.74 100.00 0.74 0.31 100.00

Example 3 - Case Study of NGL Recovery from a Feed with Low-Normal C3+ Levels [0071] The following example illustrates a simulated case study performed on the flowsheet illustrated in Figure 9. The adsorption bed in the simulation had a volume of 0.8 m , a length of 1.6 m, and a diameter of 0.8 m. The adsorption bed sizes in this and other examples should not be construed as limiting and may range, for example, from about 0.2 ft³/MSCFH feed to about 10 ft³/MSCFH feed. The process conditions and stream compositions of the input and output streams are illustrated in Table 6 below.

Table 6 - C3+ Components Recovery of Case Study 3

[0072] Table 6 illustrates an increase in the concentration of C3+ components in the stabilizer bottom stream when compared to the concentration of C3+ components in the feed stream. The temperature utilized in the simulation for the stabilizer' s overhead condenser was about 27 °C. The power utilized in the simulation was about 10 kw in the first stage, about 10 kw in the second stage, and about 4.8 kw in the third stage. The power utilized by the pumps in the simulation was about 0.22 kw for the first pump and about 80 kw for the feed compressor increasing the pressure from 2.5 bar to 20 bar.

[0073] Table 7 illustrates the process conditions and stream compositions of the various streams in the process. The process in Figure 9 is similar to the process described in Example 2 for Case Study 2. The stream numbers in Figure 9 correspond to the stream numbers in Table 7 below.

Table 7 - C3+ Components Composition in Various Streams of Case Study 3

911 949 942 943 963 947 948

Temperature

25 24.7 27 15.74 28.48 26.67 60 (C)

Pressure

20 20 19.31 1.034 20.68 21.72 22.75 (bar)

Molar Flow

37.36 41.71 30.55 11.16 11.16 4.363 6.795 (kgmole/h)

Methane

67.56 63.62 82.52 11.89 11.89 29.74 0.43 (mole%)

Ethane

13.40 15.67 12.84 23.43 23.43 35.18 15.89 (mole%)

Propane

10.10 12.05 0.82 42.80 42.80 28.91 51.73 (mole%)

i-butane

2.56 2.61 0.18 9.27 9.27 3.04 13.27 (mole%)

n-butane

2.09 2.06 0.14 7.30 7.30 1.76 10.86 (mole%)

n-pentane

1.48 1.35 0.09 4.81 4.81 0.27 7.73 (mole%)

Example 4 - Case Study of NGL Recovery Process from a Feed with Water

[0074] The following example illustrates a simulated case study performed on the flowsheet illustrated in Figure 10.

[0075] Table 8 illustrates the process conditions and stream compositions of the various streams in the process. In Figure 10, feed stream 1011 could optionally be compressed in K-

1004 to form stream 1007, which may then be mixed in MIX- 1001 with a recycle stream

1047 generated from the stabilizer's effluent, to form mixed stream 1049. Stream 1049 is fed into the adsorber system 1010. Stream 1042 is the adsorber effluent stream containing high levels of CI and C2 components and low residue of C3 component. Stream 1042 undergoes treatment through additional process units (compressor K-1002) resulting in stream 1067 with an elevated temperature and pressure. Stream 1043 is the adsorber bottom stream containing high levels of C3+ components and low residues of CI and C2 components.

Stream 1043 undergoes treatment in additional process units and streams (K-1000, 1056, E-

1003, 1004, K-1001, 1012, E-1004, 1057, V-1000, 1002, 1061, 10161, K-1003, P-1001,

1001, E-1002, 1051, V-1001, 1062, P-1000, 10162, 1003, 1006, and 1005). Ultimately, streams 1005, 1006 and 1003 are mixed in MIX- 1000 to form stream 1063, which is fed to the stabilizer 1020. A stabilizer bottom stream 1048 enriched with C3+ components and a stabilizer effluent stream 1047, which is recycled to the absorbent system 1010. Stream 1047 is mixed with feed stream 1007 in MIX- 1001 and then fed to the adsorber system 1010.

[0076] Process units E-1003, E-1004, E-1002 depict heat exchangers and allow temperature variations in the process. Process units K-1000, K-1001, K-1002, K-1003, and K-1004 depict compressors and allow pressure variations in the process. Process units V- 1000 and V-1001 are three phase separators wherein the bottom streams (10161 and 10162) separate liquid water, middle streams (1061 and 1062) separate organic compounds in a liquid phase, and top streams (1002 and 1003) separate organic compounds in a vapor phase. Process units P-1000 and P-1001 designate pumps. Process units MIX-1000 and MIX-1001 designate mixing valves and/or mixing vessels used to combine a plurality of streams. The stream numbers in Figure 10 correspond to the stream numbers in Table 8.

Table 8 - C3+ Components Composition in Various Streams of Case Study 4

[0077] Process units V-1001 and V-1000 in the simulation were used to remove water from the process as evident from the compositions of streams 1057, 10161, 1061, 1002 and 1051, 10162, 1062, 1003 summarized in table 9 below.

Table 9 - Water Composition in Various Streams of Case Study 4

Example 5 - Case Study of NGL Recovery Process from a Feed with Carbon Dioxide

[0078] The following example illustrates a simulated case study performed on the flowsheet illustrated in Figure 11.

[0079] Table 10 illustrates the process conditions and stream compositions of the various streams in the process. In Figure 11, feed stream 1111 could optionally be compressed in K- 1104 to form stream 1107. Stream 1107 may then be mixed with stream 1146 in MIX- 1101. Stream 1146 is generated when the stabilizer's effluent stream 1147 undergoes treatment in process unit X-1101. Specifically, process unit X-1101 may be a separation device, such as a device comprising a membrane or an adsorber. The separation device could remove carbon dioxide from the process through stream 1148A, thereby generating stream 1146 which has a lower amount of carbon dioxide than the amount of carbon dioxide present in the stabilizer effluent stream 1147. Stream 1146 may then be mixed with feed stream 1107 in MIX- 1101 A to form stream 1149.

[0080] Stream 1149 is fed into the adsorber system 1110. Stream 1142 is the adsorber effluent stream containing high levels of CI and C2 components and low residue of C3 component. Stream 1142 undergoes treatment through additional process units (compressor K-1102) resulting in stream 1167 with an elevated temperature and pressure. Stream 1143 is the adsorber bottom stream containing high levels of C3+ components and low residues of CI and C2 components. Stream 1143 undergoes treatment in additional process units and streams (K-1100, 1156, MIX- 1102, 1192, E-1103, 1104, V-1101, 1103, K-1101, 1112, E- 1104, 1157, 1162, V-1100, 1102, 1161, K-1103, P-1101, P-1100, 1101, E-1102, 1151, 1106, and 1105). Ultimately, streams 1105, 1106 and 1103 are mixed in MIX- 1100 to form stream 1163, which is fed to the stabilizer 1120. A stabilizer bottom stream 1148 enriched with C3+ components and a stabilizer effluent stream 1147, which is recycled to the adsorber system 1110 after treatment in X-l 101, are generated.

[0081] Process units E-1103, E-1104, E-1102 depict heat exchangers and allow temperature variations in the process. Process units K-1100, K-1101, K-1102, K-1103, and K-1104 depict compressors and allow pressure variations in the process. Process units V- 1100 and V-1101 may be used to remove water from the process. Process units P-1100 and P-1101 designate pumps. Process units MIX-1100 and MIX-1101 designate mixing valves and/or mixing vessels for combining a plurality of streams. The stream numbers in Figure 10 correspond to the stream numbers in Table 10.

Table 10 - C3+ Components Composition in Various Streams of Case Study 5

(kgmole/h)

Methane

81.37 75.46 88.34 32.63 32.63 40.64 1.97 (mole%)

Ethane

9.32 9.47 9.86 8.19 8.19 9.35 3.76 (mole%)

Propane

2.50 6.55 0.43 26.92 26.92 25.05 34.12 (mole%)

n-butane

2.03 2.68 0.17 11.00 11.00 5.50 32.06 (mole%)

n-pentane

1.01 0.87 0.06 3.59 3.59 0.14 16.84 (mole%)

Hexane+

0.50 0.42 0.03 1.72 1.72 0.00 8.33 (C6+, mole%)

C0₂ 2.46 3.80 0.25 15.61 15.61 18.92 2.92

[0082] Process unit X-1101 in the simulation was used to remove carbon dioxide from the process as evident from the compositions of streams 1147, 1148A and 1146 summarized in table 11 below.

Table 10 - C3+ Components Composition in Various Streams of Case Study 5

Example 6 - Case Study of NGL Recovery Process with Vent Recycle

[0083] The following example illustrates a simulated case study performed on the flowsheet illustrated in Figure 12.

[0084] Table 11 illustrates the process conditions and stream compositions of the various streams in the process. In Figure 12, feed stream 1211 could optionally be compressed in compressor K-1204 to form stream 1207, which may then be mixed in MIX- 1201 with a recycle stream 1247 generated from the stabilizer's effluent and with stream 1295, to form mixed stream 1249. Stream 1249 is fed into the adsorber system 1210. Stream 1242 is the adsorber effluent stream containing high levels of CI and C2 components and low residue of C3 component. Stream 1242 undergoes treatment through additional process units (compressor K-1202) resulting in stream 1267 with an elevated temperature and pressure. Stream 1291 is the adsorber bottom stream containing high levels of C3+ components and low residues of CI and C2 components. Stream 1290 is a vent stream generated during the adsorption process after the adsorption step and concurrent to the feed. In some embodiments, vent stream 1290 may be generated after all one or multiple equalization steps are completed. In some embodiments, vent stream 1290 may be generated before or between equalizations steps.

[0085] The equalization step or steps assist in the separation of non-selective particles from the feed stream which is in contact with the sorbent (i.e, feed gas particles which fill up void spaces in the sorbent). The equalizations step(s) may further assist with a preliminary depressurization of the adsorbent. During the preliminary pressurization, the non-selective particles may be removed from the adsorber, while keeping selective particles in the adsorber. This prevents dilution of the selective particles that are later separated into adsorber effluent stream 1242 and adsorber bottom stream 1291 with the non-selective particles present in the initial feed stream.

[0086] A single equalization may reduce the content of non-selective particles by half. Two equalizations may reduce the content of non-selective particles by about an additional one third (in addition to the reduction resulting from the first equalization). Three equalizations may reduce the content of the non- selective particles by about an additional one fourth (in addition to the reduction resulting from the first and second equalization). Accordingly, the reduction in non- selective particles decreases with the number of equalizations performed. Thus, while equalizations may reduce some of the non-selective particles in the adsorber, in some embodiments, some non- selective particles may still remain in the voids of the sorbent in the adsorber. Lower contents of non- selective particles in the adsorber may be advantageous to further concentrate the adsorber bottom stream with C3+ components.

[0087] Stream 1290 from unit 1210 may be compressed in compressor K-1205 and fed into MIX- 1201 where it may be mixed with feed stream 1207 and stabilizer effluent stream 1247 to form mixed adsorbed feed stream 1249. Adsorber bottom stream 1291 undergoes treatment in additional process units and streams (K-1200, 1250, MIX- 1202, 1292, E-1203, 1204, K-1201, 1212, E-1204, 1257, V-1200, 1202, 12161, 1261, K-1203, 1201, P-1201, E- 1202, 1251, V-1201, 1262, P-1200, 12162, 1203, 1206, and 1205). Ultimately, streams 1205, 1206 and 1203 are mixed in MIX- 1200 to form stream 1263, which is fed to the stabilizer 1220. A stabilizer bottom stream 1248 enriched with C3+ components and a stabilizer effluent stream 1247, which may be recycled to absorbent system 1210, may be formed.

[0088] Process units E-1203, E-1204, and E-1202 depict heat exchangers and allow temperature variations in the process. Process units K-1200, K-1201, K-1202, K-1203, K- 1204, and K-1205 depict compressors and allow pressure variations in the process. Process units V-1200 and V-1201 are three phase separators wherein the bottom streams (12161 and 12162) separate liquid water, middle streams (1261 and 1262) separate organic compounds in a liquid phase, and top streams (1202 and 1203) separate organic compounds in a vapor phase. Process units P-1200 and P-1201 designate pumps. Process units MIX-1200, ΜΓΧ- 1201, and MIX-1202 designate mixing valves and/or mixing vessels used to combine a plurality of streams. The stream numbers in Figure 12 correspond to the stream numbers in Table 11.

Table 11 - C3+ Components Composition in Various Streams of Case Study 6

r r r r r r

Feed Effluent Bottom Feed Effluent Bottom

1249 1242 1291 1263 1247 1248

Temperature (°C) 39.43 43.12 33.50 41.12 22.82 71.11

Pressure (bar) 20.68 20.68 1.03 20.68 20.68 21.72

Molar Flow

1148.33 919.38 170.87 95.38 75.49 (kgmole/h) 172.21

Methane (mole%) 78.13 87.83 26.05 26.25 45.80 1.55

Ethane (mole%) 9.67 9.66 9.02 9.09 12.30 5.05

Propane (mole%) 6.25 0.39 39.61 39.92 33.03 48.62 n-butane (mole%) 2.04 0.13 12.94 13.04 3.47 25.14 n-pentane (mole%) 0.88 0.06 5.59 5.63 0.06 12.67

Hexane+

0.43 0.03 2.77 0.00 6.26 (C6+, mole%) 2.74

H₂0 0.16 0.01 1.02 0.24 0.38 0.07

Example 7 - Inventive Examples Versus Comparative Technologies [0089] Figure 13 depicts a plot comparing C3+ recovery, horsepower, and coldest process temperature of existing straight refrigeration and IPOR technologies to an inventive technology according to an embodiment.

[0090] As illustrated in Figure 13, the inventive technology achieves significantly higher C3+ recovery as compared to the straight refrigeration technology while operating at significantly higher temperatures than the IPOR technology.

[0091] The use of the terms "a," "an," "the," and similar referents in the context of describing the materials and methods discussed herein (especially in the context of the following claims) are to be construed to cover both the singular and the plural, unless otherwise indicated herein or clearly contradicted by context. Recitation of ranges of values herein are merely intended to serve as a shorthand method of referring individually to each separate value falling within the range, unless otherwise indicated herein, and each separate value is incorporated into the specification as if it were individually recited herein. All methods described herein can be performed in any suitable order unless otherwise indicated herein or otherwise clearly contradicted by context. The use of any and all examples, or exemplary language (e.g., "such as") provided herein, is intended merely to better illuminate the materials and methods and does not pose a limitation on the scope unless otherwise claimed. No language in the specification should be construed as indicating any non-claimed element as essential to the practice of the disclosed materials and methods.

[0092] Reference throughout this specification to "one embodiment," "certain embodiments," "some embodiments," "one or more embodiments" or "an embodiment" means that a particular feature, structure, material, or characteristic described in connection with the embodiment is included in at least one embodiment of the present disclosure. Thus, the appearances of the phrases such as "in one or more embodiments," "in certain embodiments," "in some embodiments," "in one embodiment," or "in an embodiment" in various places throughout this specification are not necessarily referring to the same embodiment of the present disclosure. Furthermore, the particular features, structures, materials, or characteristics may be combined in any suitable manner in one or more implementations .

[0093] Although the embodiments disclosed herein have been described with reference to particular embodiments, it is to be understood that these embodiments are merely illustrative of the principles and applications of the present disclosure. It will be apparent to those skilled in the art that various modifications and variations can be made to the method and apparatus of the present disclosure without departing from the spirit and scope of the disclosure. Thus, it is intended that the present disclosure include modifications and variations that are within the scope of the appended claims and their equivalents, and the above-described embodiments are presented for purposes of illustration and not of limitation. [0094] In addition, the term "or" is intended to mean an inclusive "or" rather than an exclusive "or." When the term "about" or "approximately" is used herein, this is intended to mean that the nominal value presented is precise within +10%.

Claims

CLAIMS What is claimed is:

1. A natural gas liquid recovery process for recovering natural gas liquid from a stream having a low C3+ components concentration, the process comprising:

(a) feeding an initial fluid volume having a first concentration of C3+ components into an adsorber, the adsorber comprising a sorbent selective for C3+ components;

(b) contacting the initial fluid volume with the sorbent;

(c) generating an adsorber effluent volume having a second concentration of C3+ components;

(d) generating a bottom volume having a third concentration of C3+ components, the third concentration being greater than the second concentration;

(e) feeding the bottom volume to a stabilizer; and

(f) liquefying a first amount of the bottom volume.

2. The natural gas liquid recovery process of claim 1, wherein the adsorber is a pressure swing adsorber.

3. The natural gas liquid recovery process of claim 2, wherein steps (b) and (c) occur at an initial adsorption pressure and step (d) occurs at a final desorption pressure, and wherein the initial adsorption pressure is greater than the final desorption pressure.

4. The natural gas liquid recovery process of claim 3, wherein an initial adsorption pressure ranges from 1 bar to 70 bar.

5. The natural gas liquid recovery process of claim 4, wherein the initial adsorption pressure ranges from 5 bar to 50 bar.

6. The natural gas liquid recovery process of claim 5, wherein the initial adsorption pressure ranges from 10 bar to 30 bar.

7. The natural gas liquid recovery process of claim 3, wherein a final desorption pressure ranges from 0.2 bar to 6 bar.

8. The natural gas liquid recovery process of claim 7, wherein the final desorption pressure ranges from 0.3 bar to 2 bar.

9. The natural gas liquid recovery process of claim 1,

wherein the third concentration is greater than the first concentration; and

wherein the first concentration is greater than the second concentration.

10. The natural gas liquid recovery process of claim 1, further comprising recycling a second amount of the bottom volume to a stream containing the initial fluid volume.

11. The natural gas liquid recovery process of claim 1, wherein the stabilizer operates at a temperature ranging from about -28 °C to about 150 °C or at a temperature that will prevent hydrate formation in the stabilizer when water is present in the process.

12. The natural gas liquid recovery process of claim 9, wherein the third concentration ranges from about two to about 100 times greater than the first concentration.

13. The natural gas liquid recovery process of claim 9, wherein the third concentration is at least three times greater than the second concentration.

14. The natural gas liquid recovery process of claim 1, further comprising between steps (d) and (e): feeding the bottom volume to a compressor.

15. The natural gas liquid recovery process of claim 1, wherein the first concentration ranges from about 1 mole% to about 50 mole% based on a total number of moles in the initial fluid volume.

16. The natural gas liquid recovery process of claim 1, wherein the adsorber operates at a temperature ranging from -28 °C to 200 °C or at a temperature that will prevent hydrate formation in the adsrober when water is present in the process.

17. The natural gas liquid recovery process of claim 16, wherein the adsorber operates at a temperature ranging from about 0 °C to 150 °C.

18. The natural gas liquid recovery process of claim 17, wherein the adsorber operates at a temperature ranging from about 25 °C to 70 °C.

19. The natural gas liquid recovery process of claim 1, wherein steps (b) and (c) occur over a time period, said time period is proportional to:

the first concentration of C3+ components in the initial fluid volume, and

the initial fluid volume.

20. The natural gas liquid recovery process of claim 19, wherein the time period ranges from 20 seconds to 10 minutes.

21. The natural gas liquid recovery process of claim 20, wherein the time period ranges from 1 minute to 4 minutes.

22. The natural gas liquid recovery process of claim 1, wherein the adsorber and the stabilizer are constructed from carbon steel.

23. The natural gas liquid recovery process of claim 1, wherein the sorbent is selected from the group consisting of silica gel, alumina, zeolite, MOFs, carbon.

24. The natural gas liquid recovery process of claim 10, further comprising before the recycling:

feeding the second amount to a stabilizer overhead condenser operating a temperature ranging from about -30 °C to about 50 °C or at a temperature that will prevent hydrate formation in the stabilizer overhead condenser when water is present in the process.

25. The natural gas liquid recovery process of claim 1, wherein the stabilizer operates at a pressure ranging from 5 bar to 50 bar.

26. The natural gas liquid recovery process of claim 25, wherein the stabilizer operates at a pressure ranging from 10 bar to 30 bar.

27. The natural gas liquid recovery process of claim 1, further comprising before step (a): feeding untreated fluid volume to a compressor to generate the initial fluid volume.

28. The natural gas liquid recovery process of claim 1, wherein the initial fluid volume ranges from about 0.2 MSCFH feed/ft³ adsorbent to about 10 MSCFH feed/ft³ adsorbent.

29. The natural gas liquid recovery process of claim 1, wherein a coldest temperature in the process ranges from about -30 °C to about 50 °C.

30. The natural gas liquid recovery process of claim 1, further comprising recovering 80% or more of the C3+ components present in the initial fluid volume.

31. A natural gas liquid recovery process for recovering natural gas liquid from a stream enriched with C3+ components, the process comprising:

(a) feeding an initial fluid volume having a first concentration of C3+ components into a stabilizer;

(b) liquefying a first amount of the initial fluid volume;

(c) generating a second amount of the initial fluid volume having a second

concentration of C3+ components;

(d) feeding the second amount into an adsorber, the adsorber comprising a sorbent selective for C3+ components;

(e) contacting the second amount of the initial fluid volume with the sorbent;

(f) generating an adsorber effluent volume having a third concentration of C3+ components; (g) generating an adsorber bottom volume having a fourth concentration of C3+ components, the fourth concentration being greater than the third concentration and greater than the second concentration; and

(h) feeding the bottom volume to the initial fluid volume.

32. The natural gas liquid recovery process of claim 31, wherein the adsorber is a pressure swing adsorber.

33. The natural gas liquid recovery process of claim 31, wherein steps (e) and (f) occur at an initial adsorption pressure and step (g) occurs at a final desorption pressure, and wherein the initial adsorption pressure is greater than the final desorption pressure.

34. The natural gas liquid recovery process of claim 33, wherein an initial adsorption pressure ranges from 1 bar to 70 bar.

35. The natural gas liquid recovery process of claim 34, wherein the initial adsorption pressure ranges from 5 bar to 50 bar.

36. The natural gas liquid recovery process of claim 35, wherein the initial adsorption pressure ranges from 10 bar to 30 bar.

37. The natural gas liquid recovery process of claim 32, wherein a final desorption pressure ranges from 0.2 bar to 6 bar.

38. The natural gas liquid recovery process of claim 37, wherein the final desorption pressure ranges from 0.3 bar to 2 bar.

39. The natural gas liquid recovery process of claim 31,

wherein the fourth concentration is greater than the second concentration and greater than the third concentration; and

wherein the second concentration is greater than the third concentration.

40. The natural gas liquid recovery process of claim 31, wherein the stabilizer operates at a temperature ranging from about -28 °C to about 150 °C or at a temperature that will prevent hydrate formation in the stabilizer when water is present in the process.

41. The natural gas liquid recovery process of claim 31, wherein the stabilizer operates at a pressure ranging from 5 bar to 50 bar.

42. The natural gas liquid recovery process of claim 31, wherein the stabilizer operates at a pressure ranging from 10 bar to 30 bar.

43. The natural gas liquid recovery process of claim 31, wherein the fourth concentration is at least three times greater than the third concentration.

44. The natural gas liquid recovery process of claim 31, wherein the fourth concentration ranges from about two to about 100 times greater than the second concentration.

45. The natural gas liquid recovery process of claim 31, further comprising between steps (g) and (h): feeding the bottom volume to a compressor.

46. The natural gas liquid recovery process of claim 31, wherein the first concentration ranges from about 40 mole% to about 100 mole% of C3+ components based on total number of moles in the initial fluid volume.

47. The natural gas liquid recovery process of claim 31, wherein the second concentration ranges from about 5 mole% to about 60 mole% of C3+ components based on a total number of moles in the second amount of the initial fluid volume generated in the stabilizer.

48. The natural gas liquid recovery process of claim 31, wherein the third concentration ranges from about zero to about 30 mole% of C3+ components based on a total number of moles in the adsorber effluent volume.

49. The natural gas liquid recovery process of claim 31, wherein the fourth concentration ranges from about 10 mole% to about 80 mole% of C3+ components based on a total number of moles in the adsorber bottom volume.

50. The natural gas liquid recovery process of claim 31, wherein the adsorber operates at a temperature ranging from -28 °C to 200 °C or at a temperature that will prevent hydrate formation in the adsorber when water is present in the process.

51. The natural gas liquid recovery process of claim 50, wherein the adsorber operates at a temperature ranging from 25 °C to 150 °C.

52. The natural gas liquid recovery process of claim 51, wherein the adsorber operates at a temperature ranging from 25 °C to 70 °C.

53. The natural gas liquid recovery process of claim 31, wherein steps (e) and (f) occur over a time period, said time period is proportional to:

the second concentration of C3+ components in the second amount fed to the adsorber, and

the second amount fed to the adsorber.

54. The natural gas liquid recovery process of claim 53, wherein the time period ranges from 20 seconds to 10 minutes.

55. The natural gas liquid recovery process of claim 54, wherein the time period ranges from 1 minute to 4 minutes.

56. The natural gas liquid recovery process of claim 31, wherein the adsorber and the stabilizer are constructed from carbon steel.

57. The natural gas liquid recovery process of claim 31, wherein the sorbent is selected from the group consisting of silica gel, alumina, zeolite, MOFs, carbon.

58. The natural gas liquid recovery process of claim 31, further comprising between steps (c) and (d): feeding the second amount to a stabilizer overhead condenser operating a temperature ranging from about -30 °C to about 50 °C or at a temperature that will prevent hydrate formation in the stabilizer overhead condenser when water is present in the process.

59. The natural gas liquid recovery process of claim 31, wherein the initial fluid volume ranges from about 0.2 MSCFH feed/ft³ adsorbent to about 10 MSCFH feed/ft³ adsorbent.

60. The natural gas liquid recovery process of claim 31, wherein a coldest temperature in the process ranges from about -30 °C to about 50 °C.

61. The natural gas liquid recovery process of claim 31, further comprising recovering 80% or more of the C3+ components present in the initial fluid volume.

62. A method of treating a fluid volume, the method comprising:

contacting the fluid volume with a sorbent, wherein:

the fluid volume has a first concentration of C3+ components prior to contacting,

a part of the fluid volume has a second concentration of C3+ components after the contacting, the second concentration is greater than the first concentration.

63. The method of claim 62, further comprising liquefying the part of the fluid volume having the second concentration of C3+ components, wherein a liquid resulting from the liquefying has a third concentration of C3+ components, the third concentration is greater than the second concentration.

64. A system comprising:

a pressure swing adsorber comprising a sorbent adapted for adsorption of C3+ components from a fluid volume; and

a stabilizer for recovery of liquid C3+ components at temperatures greater than -30

°C.

65. The system of claim 64, wherein the sorbent is selected from the group consisting of silica gel, alumina, zeolite, MOFs, and carbon.

66. The system of claim 64, wherein the sorbent is adapted to contact the fluid volume such that when the fluid volume has a first concentration of C3+ components, the fluid volume has a second concentration of C3+ components, wherein the second concentration is about two to about 100 times greater than the first concentration.

67. The system of claim 64, wherein the pressure swing adsorber and the stabilizer are constructed from carbon steel.

68. The process of claim 1, wherein the initial fluid volume comprises water.

69. The process of claim 68, further comprising between steps (d) and (e), feeding the bottom volume to a process unit for removing water.

70. The process of claim 69, wherein the process unit for removing water comprises a three phase separator.

71. The process of claim 70, further comprising generating a bottom stream, a middle stream, and a top stream in the three phase separator, wherein the bottom stream comprises water, the middle stream comprises organic liquid C3+ components, and the top stream comprises organic vapor C3+ components.

72. The process of claim 71, wherein step (e) comprises feeding the middle stream and the top stream to the stabilizer.

73. The process of claim 1, wherein the initial fluid volume comprises carbon dioxide.

74. The process of claim 73, further comprising feeding the second amount of the bottom volume generated in the stabilizer into a separation device for removing carbon dioxide.

75. The process of claim 74, wherein the separation device for removing carbon dioxide comprises a vessel comprising a membrane.

76. The process of claim 74, further comprising generating a stream enriched with carbon dioxide and a stream with reduced carbon dioxide content.

77. The process of claim 76, further comprising feeding the stream with reduced carbon dioxide content a stream containing the initial fluid volume.

78. The natural gas liquid recovery process of claim 1, further comprising recycling a second amount of the bottom volume to the adsorber.

79. The process of claim 68, further comprising recycling a second amount of the bottom volume of the stabilizer to the adsorber.

80. The process of claim 68, further comprising recycling a second amount of the bottom volume of the stabilizer to the initial fluid volume.

81. The process of claim 74, wherein the separation device for removing carbon dioxide comprises a pressure swing adsorber with a sorbent selective to carbon dioxide over C3+ components.