EP2307530A1 - Process for removing a gaseous contaminant from a contaminated gas stream - Google Patents

Process for removing a gaseous contaminant from a contaminated gas stream

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Publication number
EP2307530A1
EP2307530A1 EP09793930A EP09793930A EP2307530A1 EP 2307530 A1 EP2307530 A1 EP 2307530A1 EP 09793930 A EP09793930 A EP 09793930A EP 09793930 A EP09793930 A EP 09793930A EP 2307530 A1 EP2307530 A1 EP 2307530A1
Authority
EP
European Patent Office
Prior art keywords
gas
liquid
gas stream
process according
vessel
Prior art date
Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
Withdrawn
Application number
EP09793930A
Other languages
German (de)
French (fr)
Inventor
Diki Andrian
Rick Van Der Vaart
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
Shell Internationale Research Maatschappij BV
Original Assignee
Shell Internationale Research Maatschappij BV
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by Shell Internationale Research Maatschappij BV filed Critical Shell Internationale Research Maatschappij BV
Priority to EP09793930A priority Critical patent/EP2307530A1/en
Publication of EP2307530A1 publication Critical patent/EP2307530A1/en
Withdrawn legal-status Critical Current

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Classifications

    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10L—FUELS NOT OTHERWISE PROVIDED FOR; NATURAL GAS; SYNTHETIC NATURAL GAS OBTAINED BY PROCESSES NOT COVERED BY SUBCLASSES C10G, C10K; LIQUEFIED PETROLEUM GAS; ADDING MATERIALS TO FUELS OR FIRES TO REDUCE SMOKE OR UNDESIRABLE DEPOSITS OR TO FACILITATE SOOT REMOVAL; FIRELIGHTERS
    • C10L3/00—Gaseous fuels; Natural gas; Synthetic natural gas obtained by processes not covered by subclass C10G, C10K; Liquefied petroleum gas
    • C10L3/06—Natural gas; Synthetic natural gas obtained by processes not covered by C10G, C10K3/02 or C10K3/04
    • C10L3/10—Working-up natural gas or synthetic natural gas
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D45/00—Separating dispersed particles from gases or vapours by gravity, inertia, or centrifugal forces
    • B01D45/12—Separating dispersed particles from gases or vapours by gravity, inertia, or centrifugal forces by centrifugal forces
    • B01D45/16—Separating dispersed particles from gases or vapours by gravity, inertia, or centrifugal forces by centrifugal forces generated by the winding course of the gas stream, the centrifugal forces being generated solely or partly by mechanical means, e.g. fixed swirl vanes
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D46/00—Filters or filtering processes specially modified for separating dispersed particles from gases or vapours
    • B01D46/0027—Filters or filtering processes specially modified for separating dispersed particles from gases or vapours with additional separating or treating functions
    • B01D46/003—Filters or filtering processes specially modified for separating dispersed particles from gases or vapours with additional separating or treating functions including coalescing means for the separation of liquid
    • B01D46/0031—Filters or filtering processes specially modified for separating dispersed particles from gases or vapours with additional separating or treating functions including coalescing means for the separation of liquid with collecting, draining means
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D50/00—Combinations of methods or devices for separating particles from gases or vapours
    • B01D50/20—Combinations of devices covered by groups B01D45/00 and B01D46/00
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10L—FUELS NOT OTHERWISE PROVIDED FOR; NATURAL GAS; SYNTHETIC NATURAL GAS OBTAINED BY PROCESSES NOT COVERED BY SUBCLASSES C10G, C10K; LIQUEFIED PETROLEUM GAS; ADDING MATERIALS TO FUELS OR FIRES TO REDUCE SMOKE OR UNDESIRABLE DEPOSITS OR TO FACILITATE SOOT REMOVAL; FIRELIGHTERS
    • C10L3/00—Gaseous fuels; Natural gas; Synthetic natural gas obtained by processes not covered by subclass C10G, C10K; Liquefied petroleum gas
    • C10L3/06—Natural gas; Synthetic natural gas obtained by processes not covered by C10G, C10K3/02 or C10K3/04
    • C10L3/10—Working-up natural gas or synthetic natural gas
    • C10L3/101—Removal of contaminants
    • C10L3/102—Removal of contaminants of acid contaminants
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J3/00—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification
    • F25J3/06—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification by partial condensation
    • F25J3/0605—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification by partial condensation characterised by the feed stream
    • F25J3/061—Natural gas or substitute natural gas
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J3/00—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification
    • F25J3/06—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification by partial condensation
    • F25J3/063—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification by partial condensation characterised by the separated product stream
    • F25J3/0635—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification by partial condensation characterised by the separated product stream separation of CnHm with 1 carbon atom or more
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J3/00—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification
    • F25J3/06—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification by partial condensation
    • F25J3/063—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification by partial condensation characterised by the separated product stream
    • F25J3/067—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification by partial condensation characterised by the separated product stream separation of carbon dioxide
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J2205/00—Processes or apparatus using other separation and/or other processing means
    • F25J2205/10—Processes or apparatus using other separation and/or other processing means using combined expansion and separation, e.g. in a vortex tube, "Ranque tube" or a "cyclonic fluid separator", i.e. combination of an isentropic nozzle and a cyclonic separator; Centrifugal separation
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J2215/00—Processes characterised by the type or other details of the product stream
    • F25J2215/04—Recovery of liquid products
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J2270/00—Refrigeration techniques used
    • F25J2270/90—External refrigeration, e.g. conventional closed-loop mechanical refrigeration unit using Freon or NH3, unspecified external refrigeration
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
    • Y02C—CAPTURE, STORAGE, SEQUESTRATION OR DISPOSAL OF GREENHOUSE GASES [GHG]
    • Y02C20/00—Capture or disposal of greenhouse gases
    • Y02C20/40—Capture or disposal of greenhouse gases of CO2

Definitions

  • the invention relates to a process for removing one or more gaseous contaminants, such as carbon dioxide or hydrogen sulphide, from a contaminated gas stream containing methane, especially a natural gas stream.
  • the invention further relates to a device for carrying out the process and to the purified gas stream obtainable by the process.
  • WO 2004/070297 a process for removing gaseous contaminants from a natural gas stream is described.
  • water is removed from the feed gas stream by cooling, the cooling resulting in methane hydrate formation.
  • This step is followed by separation of the hydrates and further cooling of the remaining gas stream, resulting in the formation of solid acidic contaminants.
  • a cleaned natural gas stream is obtained. Heating is used to convert the solid contaminants into a slurry or liquid.
  • the slurry or liquid is removed from the separation zone.
  • special measures are necessary to remove also the smallest solid particles from the gas stream.
  • WO 2003/062725 a process is described for the removal of freezable species from a natural gas stream by cooling a natural gas stream to form a slurry of solid acidic contaminants in compressed liquefied natural gas.
  • the solids are separated from the liquid by means of a cyclone. It will be clear that a complete separation of the liquid from the solids is not easily achieved.
  • WO 2007/030888 a process is described similar to the process described in WO 2004/070297, followed by washing the cleaned natural gas stream with methanol.
  • the process according to the present invention comprises no more than two steps requiring relatively simple equipment only. In the first step the contaminated gas stream containing methane is cooled until liquid contaminants condense, followed by a simple gas/liquid separator, not needing any rotating equipment and not needing any energy for a distillation section.
  • the process provides a process for removing one or more gaseous contaminants from a contaminated feed gas stream, the process comprising 1) providing the contaminated feed gas stream, 2) cooling the contaminated feed gas stream to a temperature at which liquid contaminant is formed as well as a contaminant depleted gaseous phase, and 3) separating the two phases by introducing them into a gas/liquid separator vessel, comprising a gas/liquid inlet at an intermediate level, a liquid outlet arranged below the gas/liquid inlet and a gas outlet arranged above the gas/liquid inlet, in which vessel a normally horizontal coalescer is present above the gas/liquid inlet and over the whole cross-section of the vessel and in which vessel a centrifugal liquid separator is arranged above the coalescer and over the whole cross-section of the vessel, the liquid separator comprising one or more swirl tubes.
  • the process is a rather easy and uncomplicated process. It actually comprises only a cooling step, followed by a simple gas/liquid separation step, the separation step not involving any moving equipment and not comprising any energy consuming steps.
  • a vertical gas/liquid separator vessel the process can be performed in a device only needing a relatively small plot space.
  • the gas/liquid inlet comprises an admittance with a supply and distribution assembly extending horizontally in the separator vessel.
  • the inlet is a simple pipe, having a closed end and a number of perforations evenly distributed over the length of the pipe.
  • the pipe may have a tapered or conical shape.
  • One or more cross pipes may be present to create a grid system to distribute the gas-liquid mixture more evenly over the cross-section of the vessel.
  • the assembly includes a chamber, e.g. a longitudinal box- like structure, connected to the gas inlet and having at least one open vertical side with a grid of guide vanes disposed one behind each other, seen in the direction of the flow.
  • the gas is evenly distributed by the guide vanes over the cross-section of the column, which brings about an additional improvement of the liquid separation in the coalescer/centrifugal separator combination.
  • a further advantage is that the supply and distribution assembly separates from the gas any waves of liquid which may suddenly occur in the gas stream, the separation being effected by the liquid colliding with the guide vanes and falling down inside the column.
  • the box structure narrows down in the direction of the flow. After having been distributed by the vanes over the column cross-section, the gas flows up to the coalescer.
  • the longitudinal chamber has two open vertical sides with a grid of guide vanes. Suitable gas/liquid inlets are described in e.g.
  • a suitable, commercially available gas/liquid inlet is a Schoepentoeter inlet device.
  • coalescers There are numerous horizontal coalescers available, especially for vertical columns.
  • a well-known example of a coalescer is a wire mesh. All of these are relatively tenuous (large permeability) and have a relatively large specific (internal) plot space. Their operation is based on drop capture by collision of drops with internal surfaces, followed by drop growth on these surfaces, and finally by removal of the grown drop either by the gas or by gravity.
  • the horizontal coalescer can have many forms which are known per se and may, for example, consist of a bed of layers of gauze, especially metal or non-metal gauze, e.g. organic polymer gauze, or a layer of vanes or a layer of structured packing. Also unstructured packings can be used and also one or more trays may be present. All these sorts of coalescers have the advantage of being commercially available and operating efficiently in the column according to the invention. See also Perry's Chemical Engineers' Handbook, Sixth edition, especially Chapter 18. See also EP 195464.
  • the centrifugal liquid separator in one of its most simple forms may comprise a horizontal plate and one or more vertical swirl tubes extending downwardly from the plate, each swirl tube having one or more liquid outlets below the horizontal plate at the upper end of the swirl tube.
  • the centrifugal liquid separator comprises one or more vertical swirl tubes extending upwardly from the plate, each swirl tube having one or more liquid outlets at the upper end.
  • the plate is provided with a downcomer, preferably a downcomer that extends to the lower end of the separator vessel.
  • the centrifugal liquid separator comprises two horizontal trays between which vertical open-ended swirl tubes extend, each from an opening in the lower tray to some distance below a coaxial opening in the upper tray, means for the discharge of secondary gas and of liquid from the space between the trays outside the swirl tubes, and means provided in the lower part of the swirl tubes to impart to the gas/liquid a rotary movement around the vertical axis .
  • the liquid separator is also preferably provided with vertical tube pieces which project down from the coaxial openings in the upper tray into the swirl tubes and have a smaller diameter than these latter. This arrangement enhances the separation between primary gas on the one hand and secondary gas and liquid on the other hand, since these latter cannot get from the swirl tubes into the openings in the upper tray for primary gas .
  • the means for discharging the secondary gas from the space between the trays consist of vertical tubelets through the upper tray, and the means for discharging liquid from the space between the trays consist of one or more vertical discharge pipes which extend from this space to the bottom of the column.
  • This arrangement has the advantage that the secondary gas, after having been separated from liquid in the said space between the trays, is immediately returned to the primary gas, and the liquid is added to the liquid at the bottom of the column after coming from the coalescer, so that the secondary gas and the liquid removed in the centrifugal separator do not require separate treatment.
  • openings are preferably provided in accordance with the invention at the top of the swirl tubes for discharging liquid to the space between the trays outside the swirl tubes. This has the advantage that less secondary gas is carried to the space between the trays.
  • a suitable, commercially available centrifugal separator is a Shell Swirltube deck.
  • the separation vessel comprises a second normally horizontal liquid coalescer above the centrifugal liquid separator and over the whole cross-section of the vessel.
  • the second coalescer is arranged to remove liquids from the secondary gas.
  • the second coalescer is a bed of one or more layers of gauze, especially metal or non-metal gauze, e.g. organic polymer gauze.
  • the second normally horizontal liquid coalescer is situated above the secondary gas outlets, for instance in the way as described in EP 83811, especially as depicted in Figure 4.
  • the contaminated gas stream may be any gas stream containing acidic contaminants.
  • the contaminated gas stream is a methane containing gas stream, for instance from natural sources as natural gas, associated gas or coal bed methane or from industrial sources as refinery streams or synthetic sources as Fischer-Tropsch streams or from biological sources as anaerobic waste or manure fermentation.
  • the amount of methane present may vary over a wide range, e.g. from 3 to 90 vol%, preferably 5 and 80 vol% methane, more preferably between 10 and 75 vol%.
  • the contaminated gas stream may also be a syngas stream comprising carbon dioxide, a flue gas stream or a gas stream obtained after combustion of coal.
  • Syngas is a mixture of carbon monoxide and hydrogen.
  • a syngas stream comprising carbon dioxide is generally obtained after converting part or most of the carbon monoxide to carbon dioxide in a so-called water gas shift reaction.
  • the acidic contaminants in the feedstream are especially carbon dioxide and hydrogen sulphide, although also carbonyl sulphide (COS), carbon disulphide (CS2), mercaptans, sulphides and aromatic sulphur compounds may be present.
  • Beside acidic contaminants, also inerts may be present, for instance nitrogen and noble gases as argon and helium.
  • the amount of acidic contaminants present in the feed gas may vary over a wide range.
  • the amount of carbon dioxide in the feed gas is suitably between 15 and 90 vol%, preferably between 20 and 75 vol%.
  • the amount of hydrogen sulphide in the feed gas is suitably between 5 and 55 vol%, preferably between 10 and 45 vol%.
  • the cooling of the feed gas may be done by methods known in the art. For instance, cooling may be done against an external cooling fluid. In the case that the pressure of the feed gas is sufficiently high, cooling may be obtained by expansion of the feed gas stream. Combinations may also be possible.
  • a suitable method to cool the feed gas stream is done by nearly isentropic expansion, especially by means of an expander, preferably a turbo expander or laval nozzle.
  • Another suitable method is to cool the feed gas stream by isenthalpic expansion, preferably isenthalpic expansion over an orifice or a valve, especially over one or more Joule-Thomson valves.
  • more than one expander is used, as this enables influencing the droplet size and/or droplet size distribution .
  • the feed gas stream is pre-cooled before expansion. This may be done against an external cooling loop or against a cold process stream, e.g. liquid acidic contaminant.
  • the gas stream is pre-cooled before expansion to a temperature between 15 and -35 0 C, preferably between -10 0 C and -20 0 C.
  • Pre- cooling may be done against internal process streams. Especially when the feed gas stream has been compressed, the temperature of the feed gas stream may be between 100 and 150 0 C. In that case air cooling may be used to decrease the temperature first, optionally followed by further cooling.
  • Another suitable cooling method is heat exchange against a cold fluidum, especially an external refrigerant, e.g. a propane cycle, an ethane/propane cascade or a mixed refrigerant cycle, optionally in combination with an internal process loop, suitably a carbon dioxide stream (liquid or slurry) , a cold contaminant depleted stream or washing fluid or in which the cooling is done by compression, cooling and expansion .
  • an external refrigerant e.g. a propane cycle, an ethane/propane cascade or a mixed refrigerant cycle
  • an internal process loop suitably a carbon dioxide stream (liquid or slurry) , a cold contaminant depleted stream or washing fluid or in which the cooling is done by compression, cooling and expansion .
  • the feed gas stream is cooled to a temperature between -30 and -80 0 C, especially between -40 and -60 0 C. At these temperatures liquids will be formed.
  • the raw feed gas stream may be pre-treated to partially or completely remove of water and optionally some heavy hydrocarbons. This can for instance be done by means of a pre-cooling cycle, against an external cooling loop or a cold internal process stream. Water may also be removed by means of pre-treatment with molecular sieves, e.g. zeolites, or silica gel or alumina oxide or other drying agents. Water may also be removed by means of washing with glycol, MEG, DEG or TEG, or glycerol. The amount of water in the gas feed stream is suitably less than 1 vol%, preferably less than 0.1 vol%, more preferably less than 0.01 vol%.
  • the feedstream for the process of the invention will suitably have a pressure between 10 and 120 bara, or even up till 160 bara. Especially, the feedstream has a pressure between 15 and 70 bara, preferably between 20 and 50 bara.
  • the feedstream, preferably pretreated suitably has a temperature between -30 and 150 0 C, suitably between -20 and 70 0 C, preferably between 0 and 50 0 C.
  • the contaminant depleted gaseous phase is further purified, e.g. by extraction of remaining acidic components with a chemical solvent, e.g. an aqueous amine solution, especially aqueous ethanolamines, such as DIPA, DMA, MDEA, etc., or with a physical solvent, e.g. cold methanol, DEPG, NMP, etc.
  • a chemical solvent e.g. an aqueous amine solution, especially aqueous ethanolamines, such as DIPA, DMA, MDEA, etc.
  • a physical solvent e.g. cold methanol, DEPG, NMP, etc.
  • the contaminated gas stream is continuously provided, continuously cooled and continuously separated.
  • FIG. 1 a device is shown for carrying out the process of the present invention.
  • a dry feed stream (water content 20 ppm, 60 bara) flows via pipe 1 to turbo-expander 2. In the expander the temperature drops to -45 0 C.
  • the feed gas comprises 40 vol% of carbon dioxide, 2 vol% of ethane and 58 vol% of methane.
  • the resulting gas/liquid mixture is introduced into vertical gas/liquid separator 3 via supply and distribution assembly 4. Most of the liquid will flow down to the lower end of the separator and leave the separator via liquid outlet 5.
  • the gaseous stream comprising larger and smaller droplets will flow upwards via liquid coalescer 6, centrifugal separator 7 and a second liquid coalescer 8 to the top of the separator vessel, and leave the separator vessel via gas outlet 9.

Abstract

The invention provides a process for removing one or more gaseous contaminants from a contaminated feed gas stream, the process comprising 1) providing the contaminated feed gas stream, 2) cooling the contaminated feed gas stream to a temperature at which liquid contaminant is formed as well as a contaminant depleted gaseous phase, and 3) separating the two phases by introducing them into a gas/liquid separator vessel, comprising a gas/liquid inlet at an intermediate level, a liquid outlet arranged below the gas/liquid inlet and a gas outlet arranged above the gas/liquid inlet, in which vessel a normally horizontal coalescer is present above the gas/liquid inlet and over the whole cross-section of the vessel and in which vessel a centrifugal liquid separator is arranged above the coalescer and over the whole cross-section of the vessel, the liquid separator comprising one or more swirl tubes. The contaminated gas stream can be a methane-containing gas stream, especially a natural gas stream, or a gas stream from a gasification or combustion process. The invention further provides a device for carrying out the process as well as the purified gas stream.

Description

PROCESS FOR REMOVING A GASEOUS CONTAMINANT FROM A CONTAMINATED GAS STREAM
The invention relates to a process for removing one or more gaseous contaminants, such as carbon dioxide or hydrogen sulphide, from a contaminated gas stream containing methane, especially a natural gas stream. The invention further relates to a device for carrying out the process and to the purified gas stream obtainable by the process.
The removal of acidic gaseous contaminants, especially carbon dioxide and/or hydrogen sulphide, from methane containing gas streams has been described in several publications.
In WO 2004/070297 a process for removing gaseous contaminants from a natural gas stream is described. In this process, water is removed from the feed gas stream by cooling, the cooling resulting in methane hydrate formation. This step is followed by separation of the hydrates and further cooling of the remaining gas stream, resulting in the formation of solid acidic contaminants. After separation of the solid acidic contaminants a cleaned natural gas stream is obtained. Heating is used to convert the solid contaminants into a slurry or liquid. The slurry or liquid is removed from the separation zone. Usually special measures are necessary to remove also the smallest solid particles from the gas stream.
In WO 2003/062725 a process is described for the removal of freezable species from a natural gas stream by cooling a natural gas stream to form a slurry of solid acidic contaminants in compressed liquefied natural gas. The solids are separated from the liquid by means of a cyclone. It will be clear that a complete separation of the liquid from the solids is not easily achieved. In WO 2007/030888 a process is described similar to the process described in WO 2004/070297, followed by washing the cleaned natural gas stream with methanol.
In US 4,533,372 a cryogenic process is described for the removal of carbon dioxide and/or hydrogen sulphide from natural gas by treating the feedstream in a distillation zone and a controlled freezing zone.
There is still a need for a further improved process to remove carbon dioxide and/or hydrogen sulphide from natural gas streams. It is especially desired to design a relatively simple process, not requiring any rotating equipment, not requiring cryogenic distillation processes, not requiring the handling of solid particles or liquid/solid slurries and only having a minimum plot space requirement (footprint) . The process according to the present invention comprises no more than two steps requiring relatively simple equipment only. In the first step the contaminated gas stream containing methane is cooled until liquid contaminants condense, followed by a simple gas/liquid separator, not needing any rotating equipment and not needing any energy for a distillation section.
Thus, the process provides a process for removing one or more gaseous contaminants from a contaminated feed gas stream, the process comprising 1) providing the contaminated feed gas stream, 2) cooling the contaminated feed gas stream to a temperature at which liquid contaminant is formed as well as a contaminant depleted gaseous phase, and 3) separating the two phases by introducing them into a gas/liquid separator vessel, comprising a gas/liquid inlet at an intermediate level, a liquid outlet arranged below the gas/liquid inlet and a gas outlet arranged above the gas/liquid inlet, in which vessel a normally horizontal coalescer is present above the gas/liquid inlet and over the whole cross-section of the vessel and in which vessel a centrifugal liquid separator is arranged above the coalescer and over the whole cross-section of the vessel, the liquid separator comprising one or more swirl tubes.
The process is a rather easy and uncomplicated process. It actually comprises only a cooling step, followed by a simple gas/liquid separation step, the separation step not involving any moving equipment and not comprising any energy consuming steps. When using a vertical gas/liquid separator vessel, the process can be performed in a device only needing a relatively small plot space.
According to a preferred embodiment, the gas/liquid inlet comprises an admittance with a supply and distribution assembly extending horizontally in the separator vessel. In its most simple form, the inlet is a simple pipe, having a closed end and a number of perforations evenly distributed over the length of the pipe. Optionally, the pipe may have a tapered or conical shape. One or more cross pipes may be present to create a grid system to distribute the gas-liquid mixture more evenly over the cross-section of the vessel. Preferably, the assembly includes a chamber, e.g. a longitudinal box- like structure, connected to the gas inlet and having at least one open vertical side with a grid of guide vanes disposed one behind each other, seen in the direction of the flow. By means of this supply and distribution assembly, the gas is evenly distributed by the guide vanes over the cross-section of the column, which brings about an additional improvement of the liquid separation in the coalescer/centrifugal separator combination. A further advantage is that the supply and distribution assembly separates from the gas any waves of liquid which may suddenly occur in the gas stream, the separation being effected by the liquid colliding with the guide vanes and falling down inside the column. Suitably, the box structure narrows down in the direction of the flow. After having been distributed by the vanes over the column cross-section, the gas flows up to the coalescer. In a preferred embodiment the longitudinal chamber has two open vertical sides with a grid of guide vanes. Suitable gas/liquid inlets are described in e.g.
GB 1,119,699, US 6,942,720, EP 195,464, US 6,386,520 and US 6,537,458. A suitable, commercially available gas/liquid inlet is a Schoepentoeter inlet device.
There are numerous horizontal coalescers available, especially for vertical columns. A well-known example of a coalescer is a wire mesh. All of these are relatively tenuous (large permeability) and have a relatively large specific (internal) plot space. Their operation is based on drop capture by collision of drops with internal surfaces, followed by drop growth on these surfaces, and finally by removal of the grown drop either by the gas or by gravity.
The horizontal coalescer can have many forms which are known per se and may, for example, consist of a bed of layers of gauze, especially metal or non-metal gauze, e.g. organic polymer gauze, or a layer of vanes or a layer of structured packing. Also unstructured packings can be used and also one or more trays may be present. All these sorts of coalescers have the advantage of being commercially available and operating efficiently in the column according to the invention. See also Perry's Chemical Engineers' Handbook, Sixth edition, especially Chapter 18. See also EP 195464.
The centrifugal liquid separator in one of its most simple forms may comprise a horizontal plate and one or more vertical swirl tubes extending downwardly from the plate, each swirl tube having one or more liquid outlets below the horizontal plate at the upper end of the swirl tube. In another form, the centrifugal liquid separator comprises one or more vertical swirl tubes extending upwardly from the plate, each swirl tube having one or more liquid outlets at the upper end. The plate is provided with a downcomer, preferably a downcomer that extends to the lower end of the separator vessel.
In a preferred embodiment, the centrifugal liquid separator comprises two horizontal trays between which vertical open-ended swirl tubes extend, each from an opening in the lower tray to some distance below a coaxial opening in the upper tray, means for the discharge of secondary gas and of liquid from the space between the trays outside the swirl tubes, and means provided in the lower part of the swirl tubes to impart to the gas/liquid a rotary movement around the vertical axis .
The liquid separator is also preferably provided with vertical tube pieces which project down from the coaxial openings in the upper tray into the swirl tubes and have a smaller diameter than these latter. This arrangement enhances the separation between primary gas on the one hand and secondary gas and liquid on the other hand, since these latter cannot get from the swirl tubes into the openings in the upper tray for primary gas .
According to a preferred embodiment, the means for discharging the secondary gas from the space between the trays consist of vertical tubelets through the upper tray, and the means for discharging liquid from the space between the trays consist of one or more vertical discharge pipes which extend from this space to the bottom of the column. This arrangement has the advantage that the secondary gas, after having been separated from liquid in the said space between the trays, is immediately returned to the primary gas, and the liquid is added to the liquid at the bottom of the column after coming from the coalescer, so that the secondary gas and the liquid removed in the centrifugal separator do not require separate treatment.
In order to improve even further the liquid separation in the centrifugal separator, openings are preferably provided in accordance with the invention at the top of the swirl tubes for discharging liquid to the space between the trays outside the swirl tubes. This has the advantage that less secondary gas is carried to the space between the trays. A suitable, commercially available centrifugal separator is a Shell Swirltube deck.
In a preferred embodiment, the separation vessel comprises a second normally horizontal liquid coalescer above the centrifugal liquid separator and over the whole cross-section of the vessel. The second coalescer is arranged to remove liquids from the secondary gas. This has the advantage that any droplets still present in the secondary gas are removed as described hereinabove. Preferably, the second coalescer is a bed of one or more layers of gauze, especially metal or non-metal gauze, e.g. organic polymer gauze. In another preferred embodiment, the second normally horizontal liquid coalescer is situated above the secondary gas outlets, for instance in the way as described in EP 83811, especially as depicted in Figure 4.
The contaminated gas stream may be any gas stream containing acidic contaminants.
Suitably, the contaminated gas stream is a methane containing gas stream, for instance from natural sources as natural gas, associated gas or coal bed methane or from industrial sources as refinery streams or synthetic sources as Fischer-Tropsch streams or from biological sources as anaerobic waste or manure fermentation. The amount of methane present may vary over a wide range, e.g. from 3 to 90 vol%, preferably 5 and 80 vol% methane, more preferably between 10 and 75 vol%.
The contaminated gas stream may also be a syngas stream comprising carbon dioxide, a flue gas stream or a gas stream obtained after combustion of coal. Syngas is a mixture of carbon monoxide and hydrogen. A syngas stream comprising carbon dioxide is generally obtained after converting part or most of the carbon monoxide to carbon dioxide in a so-called water gas shift reaction. The acidic contaminants in the feedstream are especially carbon dioxide and hydrogen sulphide, although also carbonyl sulphide (COS), carbon disulphide (CS2), mercaptans, sulphides and aromatic sulphur compounds may be present. Beside acidic contaminants, also inerts may be present, for instance nitrogen and noble gases as argon and helium. The amount of acidic contaminants present in the feed gas may vary over a wide range. The amount of carbon dioxide in the feed gas is suitably between 15 and 90 vol%, preferably between 20 and 75 vol%. The amount of hydrogen sulphide in the feed gas is suitably between 5 and 55 vol%, preferably between 10 and 45 vol%. The cooling of the feed gas may be done by methods known in the art. For instance, cooling may be done against an external cooling fluid. In the case that the pressure of the feed gas is sufficiently high, cooling may be obtained by expansion of the feed gas stream. Combinations may also be possible. A suitable method to cool the feed gas stream is done by nearly isentropic expansion, especially by means of an expander, preferably a turbo expander or laval nozzle. Another suitable method is to cool the feed gas stream by isenthalpic expansion, preferably isenthalpic expansion over an orifice or a valve, especially over one or more Joule-Thomson valves. Preferably, more than one expander is used, as this enables influencing the droplet size and/or droplet size distribution . In a preferred embodiment the feed gas stream is pre-cooled before expansion. This may be done against an external cooling loop or against a cold process stream, e.g. liquid acidic contaminant. Preferably the gas stream is pre-cooled before expansion to a temperature between 15 and -35 0C, preferably between -10 0C and -20 0C. Pre- cooling may be done against internal process streams. Especially when the feed gas stream has been compressed, the temperature of the feed gas stream may be between 100 and 150 0C. In that case air cooling may be used to decrease the temperature first, optionally followed by further cooling.
Another suitable cooling method is heat exchange against a cold fluidum, especially an external refrigerant, e.g. a propane cycle, an ethane/propane cascade or a mixed refrigerant cycle, optionally in combination with an internal process loop, suitably a carbon dioxide stream (liquid or slurry) , a cold contaminant depleted stream or washing fluid or in which the cooling is done by compression, cooling and expansion .
Suitably the feed gas stream is cooled to a temperature between -30 and -80 0C, especially between -40 and -60 0C. At these temperatures liquids will be formed.
The raw feed gas stream may be pre-treated to partially or completely remove of water and optionally some heavy hydrocarbons. This can for instance be done by means of a pre-cooling cycle, against an external cooling loop or a cold internal process stream. Water may also be removed by means of pre-treatment with molecular sieves, e.g. zeolites, or silica gel or alumina oxide or other drying agents. Water may also be removed by means of washing with glycol, MEG, DEG or TEG, or glycerol. The amount of water in the gas feed stream is suitably less than 1 vol%, preferably less than 0.1 vol%, more preferably less than 0.01 vol%.
The feedstream for the process of the invention, optionally pretreated as described above, will suitably have a pressure between 10 and 120 bara, or even up till 160 bara. Especially, the feedstream has a pressure between 15 and 70 bara, preferably between 20 and 50 bara. The feedstream, preferably pretreated, suitably has a temperature between -30 and 150 0C, suitably between -20 and 70 0C, preferably between 0 and 50 0C.
In a preferred embodiment of the invention, the contaminant depleted gaseous phase is further purified, e.g. by extraction of remaining acidic components with a chemical solvent, e.g. an aqueous amine solution, especially aqueous ethanolamines, such as DIPA, DMA, MDEA, etc., or with a physical solvent, e.g. cold methanol, DEPG, NMP, etc.
The contaminated gas stream is continuously provided, continuously cooled and continuously separated.
The invention is further explained by Figure 1. In Figure 1 a device is shown for carrying out the process of the present invention. A dry feed stream (water content 20 ppm, 60 bara) flows via pipe 1 to turbo-expander 2. In the expander the temperature drops to -45 0C. The feed gas comprises 40 vol% of carbon dioxide, 2 vol% of ethane and 58 vol% of methane. The resulting gas/liquid mixture is introduced into vertical gas/liquid separator 3 via supply and distribution assembly 4. Most of the liquid will flow down to the lower end of the separator and leave the separator via liquid outlet 5. The gaseous stream comprising larger and smaller droplets will flow upwards via liquid coalescer 6, centrifugal separator 7 and a second liquid coalescer 8 to the top of the separator vessel, and leave the separator vessel via gas outlet 9.

Claims

C L A I M S
1. A process for removing one or more gaseous contaminants from a contaminated feed gas stream, the process comprising 1) providing the contaminated feed gas stream, 2) cooling the contaminated feed gas stream to a temperature at which liquid contaminant is formed as well as a contaminant depleted gaseous phase, and 3) separating the two phases by introducing them into a gas/liquid separator vessel, comprising a gas/liquid inlet at an intermediate level, a liquid outlet arranged below the gas/liquid inlet and a gas outlet arranged above the gas/liquid inlet, in which vessel a normally horizontal coalescer is present above the gas/liquid inlet and over the whole cross-section of the vessel and in which vessel a centrifugal liquid separator is arranged above the coalescer and over the whole cross- section of the vessel, the liquid separator comprising one or more swirl tubes.
2. Process according to claim 1, in which the gas inlet comprises an admittance with a supply and distribution assembly extending horizontally in the separator vessel, the assembly consisting of a longitudinal box-like structure connected to the gas inlet and having at least one open vertical side with a grid of guide vanes disposed one behind each other, seen in the direction of the flow.
3. Process according to claim 1 or 2, in which the horizontal coalescer consists of one or more layers of gauze, especially metal or non-metal gauze, or combination thereof.
4. Process according to claim 1 or 2, in which the horizontal coalescer consists of a layer of vanes.
5. Process according to claim 1 or 2, in which the horizontal coalescer consists of a layer of structured packing.
6. Process according to any of claims 1 to 5, in which the centrifugal liquid separator comprises two horizontal trays between which vertical open-ended swirl tubes extend, each from an opening in the lower tray to some distance below a coaxial opening in the upper tray, means for the discharge of secondary gas and of liquid from the space between the trays outside the swirl tubes, and means provided in the lower part of the swirl tubes to impart to the gas/liquid a rotary movement around the vertical axis, preferably in which the liquid separator is provided with vertical tube pieces projecting down from the coaxial openings in the upper tray into the swirl tubes and having a smaller diameter than these latter, or in which the means for discharging secondary gas from the space between the trays consists of vertical tubelets through the upper tray and in which the means for the discharge of liquid from the space between the trays consists of one or more vertical discharge pipes extending from this space to the bottom of the column.
7. Process according to claim 6, in which in the separation vessel a second normally horizontal liquid coalescer is present above the centrifugal liquid separator and over the whole cross-section of the vessel, wherein the second coalescer is arranged to remove liquids from the secondary gas.
8. Process according to claim 7, in which the second coalescer is a bed of one or more layers of gauze, especially metal or non-metal gauze, or combinations thereof .
9. A process according to any preceding claim, in which the gaseous contaminants are acidic gaseous contaminants, especially carbon dioxide or hydrogen sulphide, preferably in which the natural gas stream comprises between 5 and 80 vol% of methane, preferably between 10 and 75 vol%, or in which the contaminated gas stream contains between 5 and 55 vol% of hydrogen sulphide, preferably between 10 and 45 vol%.
10. A process according to any of the preceding claims, in which the contaminated gas stream has a temperature between -20 and 150 0C, preferably between -10 and 70 0C, and a pressure between 10 and 150 bara, preferably between 15 and 70 bara.
11. A process according to any of claims 1 to 10, in which the cooling is done by isenthalpic expansion, preferably isenthalpic expansion over an orifice or a valve, especially a Joule-Thomson valve, or in which the cooling is done by nearly isentropic expansion, especially by means of one or more expanders, preferably turbo expanders or laval nozzles.
12. A process according to claim 11, in which the feed gas stream is pre-cooled to a temperature between 15 and -35 0C, preferably between 5 and -20 0C, before expansion .
13. A process according to any of claims 1 to 10, in which the cooling is done by heat exchange against a cold fluidum, especially an external refrigerant, e.g. a propane cycle, an ethane/propane cascade or a mixed refrigerant cycle, or an internal process loop, suitably a carbon dioxide or hydrogen sulphide stream or a cold methane stream or in which the cooling is done by compression, cooling and expansion.
14. A process according to any of the preceding claims, in which the contaminated gas stream is cooled to a temperature between -30 and -80 0C, preferably between -40 and -60 0C.
15. A device for carrying out the process according to any of the claims 1 to 14.
EP09793930A 2008-07-10 2009-07-03 Process for removing a gaseous contaminant from a contaminated gas stream Withdrawn EP2307530A1 (en)

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