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WO2002014647A1 - Procede et appareil de separation, dans le puits de forage, des hydrocarbures de contaminants a l'aide de membranes reutilisables contenant des elements de membranes recuperables - Google Patents

Procede et appareil de separation, dans le puits de forage, des hydrocarbures de contaminants a l'aide de membranes reutilisables contenant des elements de membranes recuperables Download PDF

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Publication number
WO2002014647A1
WO2002014647A1 PCT/US2001/025545 US0125545W WO0214647A1 WO 2002014647 A1 WO2002014647 A1 WO 2002014647A1 US 0125545 W US0125545 W US 0125545W WO 0214647 A1 WO0214647 A1 WO 0214647A1
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WIPO (PCT)
Prior art keywords
membrane
contaminants
wellbore
shear
units
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.)
Ceased
Application number
PCT/US2001/025545
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English (en)
Inventor
David R. Underdown
John R. Hampton
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.)
Chevron USA Inc
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Chevron USA Inc
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Filing date
Publication date
Application filed by Chevron USA Inc filed Critical Chevron USA Inc
Priority to AU2001286493A priority Critical patent/AU2001286493A1/en
Publication of WO2002014647A1 publication Critical patent/WO2002014647A1/fr
Anticipated expiration legal-status Critical
Ceased legal-status Critical Current

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Classifications

    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/02—Subsoil filtering
    • E21B43/08—Screens or liners
    • E21B43/082—Screens comprising porous materials, e.g. prepacked screens
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/34—Arrangements for separating materials produced by the well
    • E21B43/38—Arrangements for separating materials produced by the well in the well

Definitions

  • the invention relates to recovery of hydrocarbons from a wellbore, and more particularly, the invention relates to technology for separation of contaminants from hydrocarbons in a wellbore with reusable hardware containing retrievable membrane elements.
  • Hydrocarbon gases and liquids have been recovered from underground wellbores for over a hundred years.
  • the recovery technology generally involves drilling a wellbore into a hydrocarbon gas or liquid formation and withdrawing the materials under reservoir pressure or by artificial lifting.
  • the current recovery technology involves removing the hydrocarbons and any contaminants which are present from the wellbore together, and separating the contaminants from the hydrocarbons above ground. This above ground separation is costly. Disposal of the removed contaminants may also present environmental problems.
  • the contaminants which may be produced include gases, such as carbon dioxide, nitrogen, water vapor, hydrogen sulfide, helium, and other trace gases, and liquids such as water, and others.
  • U.S. Patent No. 6,015,011 describes a downhole hydrocarbon separator using membranes.
  • the separator includes a permeable filter attached to the bottom of a packer so that a filter outlet end is in fluid communication with an aperture in the packer.
  • the filter selectively passes fluids from beneath the packer to above the packer.
  • the present invention provides a quick and reliable solution to retrieval and replacement of downhole membranes.
  • the system includes a membrane system which is positioned within the production tubing or casing of a wellbore and can be removed from the wellbore independent of the production tubing.
  • a retrievable system for separating hydrocarbons and contaminants in a wellbore includes a plurality of membrane units configured to be positioned in the wellbore for separating contaminants from a hydrocarbon.
  • the membrane units each have a first end and a second end configured to be connected to the first end of another membrane unit.
  • a shear-out member has first and second ends configured to be connected to first and second ends of the membrane units for interconnecting membrane units.
  • the shear out member includes a shearing portion which shears at a predetermined load separating the first and second ends of the shear-out member.
  • a retrievable system for separating hydrocarbons and contaminants in a wellbore includes a production tubing configured to be positioned in a wellbore, and at least one membrane unit configured to be positioned in the production tubing for separating contaminants from hydrocarbon.
  • the membrane unit has a fishing neck located at one end to allow retrieval of the membrane unit from the production tubing with a retrieval tool.
  • a method of retrieving a system for separating hydrocarbons and contaminants in a wellbore includes the steps of providing a membrane separation system for separating hydrocarbons and contaminants in a wellbore, the membrane separation system including at least one membrane unit and at least one shear-out sub connected to the membrane unit; and removing the membrane units from a production tubing in the wellbore with a retrieval tool which grasps the membrane units.
  • a retrievable membrane unit having a replaceable membrane for separating hydrocarbons and contaminants in a wellbore includes a perforated tube configured to be positioned in the wellbore, a first end cap removably secured on a first end of the perforated tube, the first end cap including a coupling element for coupling the perforated tube to elements of the separation system, and at least one membrane removably secured in the perforated tube for separating contaminants from a hydrocarbon, wherein the membrane can be removed from the perforated tube by removing the first end cap.
  • a method of replacing a membrane in a downhole system for separating hydrocarbons and contaminants includes the steps of: providing a membrane separation system for separating hydrocarbons and contaminants in a wellbore, the membrane system including a membrane unit containing a membrane; removing the membrane unit from the wellbore with a retrieval tool; removing the membrane from the membrane unit; replacing the membrane; and reinserting the membrane unit into the wellbore.
  • FIG. 1 is a side cross sectional view of a downhole apparatus for separating hydrocarbons and contaminants according to the present invention
  • FIG. 2 is an exploded side cross sectional view of a portion of the downhole apparatus for separating hydrocarbons and contaminants of FIG. 1
  • FIG. 3 is an enlarged side cross sectional view of a shear-out sub of the apparatus of FIG. 1
  • FIG. 4 is an enlarged side cross sectional view of a fishing neck sub of the apparatus of FIG. 1 ;
  • FIG. 1 is a side cross sectional view of a downhole apparatus for separating hydrocarbons and contaminants according to the present invention
  • FIG. 2 is an exploded side cross sectional view of a portion of the downhole apparatus for separating hydrocarbons and contaminants of FIG. 1
  • FIG. 3 is an enlarged side cross sectional view of a shear-out sub of the apparatus of FIG. 1
  • FIG. 4 is an enlarged side cross sectional view of a fishing neck sub of the apparatus of FIG. 1
  • FIG. 5 is an enlarged side cross sectional view of a packoff assembly of the apparatus of FIG. 1 ;
  • FIG. 6 is an enlarged side cross sectional view of a latch-in seal assembly of the apparatus of FIG. 1 ;
  • FIG. 7 is an exploded side cross sectional view of the latch-in seal assembly of FIG. 6;
  • FIG. 8 is a side cross sectional view of a first end of a reusable membrane unit, which may be used in place of a membrane unit shown in FIG. 1 , containing a membrane for separating hydrocarbons and contaminants according to the present invention;
  • FIG. 9 is a side cross sectional view of a second end of the reusable membrane unit for separating hydrocarbons and contaminants according to the present invention;
  • FIG. 10 is a schematic side cross sectional view of two interconnected reusable membrane units positioned downhole; and
  • FIG. 11 is a perspective view of a membrane having end seals.
  • Downhole membrane separation systems are used for separating contaminants from hydrocarbon liquids and gases downhole.
  • the contaminants which are removed downhole may be reinjected into an underground disposal formation or removed to the surface for disposal. Over time, the membranes that are used downhole may become fouled due to accumulation of contaminants.
  • the production of a particular well may change over time requiring a change in the configuration of the membrane separation system which is used.
  • the present invention provides a system which allows membranes to be removed from a wellbore and replaced in an efficient manner.
  • Wells generally include a production tubing string or casing which is lowered into the well.
  • the production tubing string may include valves, packers, and other elements for controlling the production of the well.
  • the production tubing string may also include membranes for separation of hydrocarbons and contaminates.
  • the present invention provides a retrievable membrane separation system 10, shown in FIG. 1.
  • the membrane separation system 10 is placed inside the production tubing (not shown) of a well and can be easily deployed by a deployment tool and retrieved by a retrieval tool without the removal of the entire production string.
  • FIG. 1 illustrates a membrane separation system 10 for separating hydrocarbons from contaminants in a wellbore.
  • the system 10 includes a bottom sub 12, a seal assembly 14, one or more shear-out subs 30, one or more membrane units 20, a packoff assembly 16, and a fishing neck 60.
  • the system may also include outer tubular members including a perforated liner 18, a packoff bushing 19, and a tube 54 for delivery of the hydrocarbon to the surface.
  • the assembled separation system 10 is inserted inside the production tubing of a well and the bottom sub 12 is inserted into a packer 56 in the production tubing.
  • An optional upper packer 58 may be added for isolation of the separated contaminants if the contaminants are to be disposed of downhole.
  • FIG. 1 illustrates a single membrane unit 20 for purposes of illustration.
  • the membrane separation system 10 may include multiple membrane units 20 interconnected to one another and to one or more of the shear-out subs 30.
  • each of the membrane units 20 includes one or more membranes (not shown) positioned inside the membrane unit.
  • Each of the membranes separates one or more hydrocarbon and one or more contaminant.
  • the membranes are hollow tube membranes positioned inside each of the membrane units 20.
  • the membrane units 20 are connected to one another and to one or more of the shear-out subs 30 to form the separation string or system 10 which is inserted into the production tubing in the wellbore.
  • each include a hollow perforated tube having a first end 22 configured with interior threads and a second end 24 with exterior threads which is configured to mate with and engage a first end 22 of another membrane unit, a first end of a shear-out sub 30, or another sub.
  • the shear-out sub 30 also has a first end 32 with interior threads and a second end 34 with exterior threads.
  • the first end 32 of the shear-out sub 30 connects to the second end 24 of the membrane units 20, or another sub.
  • the second end 34 of the shear-out sub 30 is arranged for mating engagement with the first end 22 of a membrane unit 20, or another sub.
  • the first and second interconnecting ends of the membrane units 20 and the shear-out subs 30 allow the arrangement of the membrane units, shear-out subs, and other subs in a string as needed for a particular application.
  • the entire membrane unit string can be removed from the wellbore as one piece or in multiple parts with the membrane units 20 separated at the shear-out subs 30 as described below.
  • the shear-out sub 30 is provided for severing the tubing string between the membrane units or between other units when the tubing string is subjected to excessive loads. This prevents the membrane units 20 from breaking within the wellbore when a portion of the string becomes stuck in the wellbore. Broken membrane elements 20 or other broken units left in the wellbore can cause significant functional problems and downtime for the well.
  • FIG. 3 illustrates one example of a shear-out sub 30 including first and second telescoping members 42, 44.
  • the telescoping members 42, 44 are connected by a plurality of shear-out screws 46 or pins.
  • the first telescoping member 42 fits inside the second telescoping member 44 and includes one or more annular grooves containing sealing elements 48.
  • the sealing elements 48 may be O-rings, gaskets, or other known seals.
  • the second telescoping member 44 of the shear-out sub 30 includes a fishing neck 50 which is configured to be grasped by a wireline retrieval tool (not shown).
  • the shear-out sub 30 shears off at a predetermined tension load which is less than the load which would fracture the membrane units 20 or the other subs. In other words, a tensile strength of the shear-out subs 30 is less than a tensile strength of the membrane units 20 and the other subs in the separation string 10.
  • the membrane unit 20 as described above includes an outer rigid tube with perforations 26 and one or more membranes contained in the tube.
  • the membrane unit 20 may also be formed with the membranes providing a self-supporting tube. However, the membrane unit 20 including a rigid perforated outer shell helps prevent breakage of the membrane unit during removal.
  • One example of an alternative membrane unit 110 having a reusable perforated outer tube and replaceable membrane will be described below in more detail in conjunction with FIGS. 8-11.
  • the string of membrane units 20 is positioned within the production tube with the bottom sub 12 connected to the packer 56 in a known manner.
  • the bottom sub may be fixed in the packer 56 by a sealed connection including chevron seals, a snap latch connection, or other known connection.
  • the string is connected to production packers at both ends.
  • FIG. 4 illustrates a fishing neck sub 60 which is attached to an upper end of a membrane unit 20 for retrieval of the membrane string.
  • the fishing neck sub 60 includes a fishing neck 62 configured to be grasped by the retrieval tool.
  • the fishing neck configuration illustrated in FIG. 4 is only one example a fishing neck. Other fishing neck configurations are known to those skilled in the art.
  • the fishing neck sub 60 includes external threads 64 connectable to the internal threaded portion 22 of the membrane unit 20 or another sub. Although the fishing neck sub 60 has been described as a separate sub connectable to the membrane units 20, the fishing neck portion may also be incorporated in one or more of the membrane units 20 or other subs.
  • FIG. 5 illustrates a packoff assembly 16 for use in the separation string 10 according to the present invention.
  • FIGS. 6 and 7 illustrate one example of a latch-in seal assembly 14 for securing the inner members of the separation string to the outer tubular members of the separation string and for isolating the separated contaminant from the hydrocarbon passing through the separation string.
  • the latch-in seal assembly 14 includes an outer latch-in seal housing 70 which is connected at one end to the bottom sub 12 and at an opposite end to the perforated liner 18.
  • the latch-in seal assembly 14 also includes an inner assembly 72 positioned in the outer housing 70.
  • the inner assembly 72 is connected at one end to inner elements of the membrane string, such as the shear-out sub 30 or membrane units 20.
  • the inner assembly 72 ratchets into the outer housing 70 in the manner described below to latch the inner assembly 72 and connected inner units to the outer housing 70 and connected outer units.
  • the inner assembly 72 includes a top sub 74, a mandrel 76, a latch member 78, a packing assembly 80, and a shoe sub 82.
  • the latch member 78 includes a plurality of flexible threaded fingers 84 which allow the inner assembly 72 to be ratcheted into a latch-in thread 86 of the outer housing 70 to secure the inner assembly in the outer housing.
  • the inner assembly 72 is removable from the outer housing 70 by unscrewing.
  • the inner assembly 72 can also be uncoupled from the outer housing 70 by pulling the inner assembly 72 with so predetermined load which causes flexing of the fingers 84.
  • the latch member 78 having the fingers 84 is secured between the mandrel 76 and the top sub 74 which are threaded together.
  • the packing assembly 80 includes chevron seals or other seals for preventing fluid from passing between the inner and outer assemblies of the membrane string to isolate the removed contaminant from the hydrocarbon.
  • the packing assembly 80 is secured on the mandrel 76 by threading the shoe sub 82 onto the mandrel.
  • chevron seals are just one examples of the seals which may be used.
  • the separation string according to the present invention is assembled by screwing the membrane elements 20, shear-out subs 30, fishing neck sub 60, inner latch-in seal assembly 72, packoff assembly 16, and any other inner subs together in a configuration which is selected depending on the properties of a particular well.
  • the outer tubular members including the packoff bushing 19, perforated liner 18, tube 54, outer housing 70 of the seal assembly 14, and the bottom sub 12 are also threaded together.
  • the inner members are then inserted into the outer tubular members with the latch-in seal assembly 14 snapping or ratcheting the inner and outer members together.
  • FIGS. 8 and 9 illustrate the top (first) and bottom (second) ends of an alternative embodiment for a membrane unit 110 for separating hydrocarbons from contaminants in a wellbore.
  • Membrane unit 110 may be used in place of membrane unit 20 described above.
  • Membrane unit 110 includes an outer perforated tube 112, an inner perforated tube 114, and first and second end caps 116, 118.
  • a tubular membrane 130 is received and supported between the outer and inner perforated tubes 112, 114.
  • the first end cap 116 includes a connecting end with internal threads 132 for connection to other membrane elements, shear- out subs, production packers, or other elements of the separation system.
  • the first end cap 116 also includes a membrane end including a first set of internal threads 134 for threaded connection of the end cap to the outer tube 112 and a second set of internal threads for connecting the end cap to the inner tube 114.
  • the second end cap 118 as shown in FIG.
  • the second end cap 118 includes a connecting end with external threads 138 for connection to other elements in the separating string, such as membrane elements and shear-out subs.
  • the second end cap 118 also includes internal threads 140 for connection to the outer tube 112.
  • a sealing member 142 such as one or more O-rings or gaskets, is provided for sealing the inner tube 114 to the second end cap 118.
  • the positions of the sealing member 142 and internal threads 136 sealing between the end caps 116, 118 and the inner tube 114 may also be reversed.
  • the end caps 116, 118 of the membrane unit 110 allow the membrane 130 to be removed from the membrane unit and replaced when the membrane becomes fouled. For replacement of the membrane 130, one or both of the end caps 116, 118 may be removed.
  • the membrane unit 110 is illustrated with inner and outer perforated tubes 114, 112 for providing structural support for the membrane 130.
  • the membrane 130 is illustrated sandwiched between the inner and outer tubes 114, 112. However, either the inner or outer tube 114, 112 may be omitted if the membrane 130 is sufficiently self-supporting.
  • the outer tube 112 preferably has a tensile strength which is sufficient to carry a load provided by the elements in the separation string which are located below the membrane unit 110 and are interconnected to each other and to the membrane unit. When a shear-out sub is provided, the tensile strength of the outer tube 112 is greater than the tensile strength of the shear- out sub.
  • the outer tube 112 also provides protection of the membrane from wear as the membrane unit 110 is run into the well.
  • the inner tube 114 provides protection of the membrane 130 from wear which may occur when tools are passed through the center of the membrane.
  • the ends of the membrane 130 may be provided with sealing rings 150, 152 as shown in FIG. 11.
  • the sealing rings 150, 152 are formed of a malleable material, such as plastic.
  • the sealing rings 150, 152 are trapped between the inner tube 114 and the end caps 116, 118 with a press fit and provide a seal between the membrane 130 and the end caps. This prevents the flow of fluid around the ends of the membrane 130.
  • the sealing rings 150, 152 will prevent fluid which has passed out through the membrane 130 from flowing back into the hydrocarbon stream passing through the center of the membrane unit 110.
  • the membrane unit 110 has been illustrated with a single membrane 130, however, multiple membranes may also be positioned within one membrane unit.
  • the membrane units 110 may be connected to one another, as shown in FIG. 10, and to other elements of a separation system by the threaded connectors 132, 138 on the ends of the membrane units.
  • the membrane units 110 may be connected in series, parallel, or combinations thereof as needed for a particular application.
  • One or more membrane units 110 and other units together form a separation string which is inserted into the wellbore.
  • the assembled separation string according to the present invention is lowered into a wellbore and sealed in place.
  • the separation string may be positioned in a production tubing in the wellbore for easy retrieval without removing the entire production tubing.
  • the membrane units 110 have a tubular configuration and allow connection in a continuous string which has an open central passageway. This tubular configuration allows conventional oil field tools to be run through the membrane units.
  • the ability to run tools through the membrane units 110 provides the added advantage that the membrane units do not have to be removed for many processes to be performed. For example, gas lift valves, setting and pulling tools, impression blocks, chemical injection valves, tubing stops, packers, tubing plugs, memory logs, production logs, dump bailers, perforation guns, or the like can be run through the membrane units 110.
  • the membrane 130 is protected from wear as the tools are passed through the membrane unit 110 by the inner tube 114.
  • the hydrocarbon and contaminants enter the wellbore and pass upward through the inside of the membrane unit 110.
  • the hydrocarbon passes through the membrane unit 110, one or more contaminants permeate out through the membrane 130 and enter a surrounding containment collection zone.
  • the hydrocarbon plus any remaining contaminants that were not removed continue out the top of the membrane unit 110.
  • the hydrocarbon with reduced contaminants is passed to the surface or to another separation system.
  • the contaminants which have been collected in the collection zone may be disposed of by directing the contaminants to an underground disposal formation. Alternatively, the contaminants may be removed from the collection zone to the surface.
  • the membrane units 110 may be removable and replaceable by a retrieval tool using conventional retrieval technology such as wireline or coil tubing.
  • a wireline retrieval tool includes a grasping portion which grasps an end of the membrane unit 110 or a fishing neck which is attached to an end of the membrane unit.
  • a fishing neck functions as a receptacle for the grasping portion of the retrieval tool.
  • the operation of the present invention will be described with respect to a vertical well, however, it should be understood that the invention may be employed in horizontal wells and other non-vertical wells.
  • the hydrocarbon and contaminants enter the wellbore and pass upward through the inside of the separation string 10 and the membranes which are positioned in the membrane units 20.
  • the hydrocarbon passes through the membranes, one or more contaminants permeate out through the membranes and enter a surrounding containment collection zone.
  • the hydrocarbon plus any remaining contaminants that were not removed continue out the tops of the membrane tubes.
  • the hydrocarbon with reduced contaminants is passed to the surface or to another separation system.
  • the contaminants which have been collected in the collection zone may be disposed of by directing the contaminants to an underground disposal formation. Alternatively, the contaminants may be removed from the collection zone to the surface. When the membranes become fouled, an increase in the amount of contaminants produced may be observed indicating that the membranes should be replaced. Other detection methods may also be used to detect fouling of the membranes. In addition to replacement of membranes when they have become fouled, it may be desirable to remove the separation system for alterations, modifications, or updates when the production of the well changes or when improved technologies become available.
  • the membrane units 20, or 110 may be removable and replaceable by a retrieval tool using conventional retrieval technology such as wireline or coiled tubing.
  • a wireline retrieval tool includes a grasping portion which grasps the fishing neck sub 60 and pulls the separation string out of the production tubing.
  • the fishing neck sub 60 functions as a receptacle for the grasping portion of the wireline retrieval tool.
  • a coiled tubing retrieval system operates in a similar manner.
  • the wellbore and the production tubing in the wellbore may include curves and irregularities which can cause the separation string to become stuck during retrieval. If a portion of the separation string becomes stuck in the production tubing during removal, the shear-out sub 30 shears off at a predetermined tension load leaving the fishing neck 50 of the shear-out sub exposed.
  • the retrieval tool is then lowered into the production tubing to retrieve a remainder of the separation string by grasping the fishing neck 50 of the shear-out sub 30.
  • the removed membranes may be cleaned for reuse or discarded.
  • Some of the contaminants which may be removed are gases including carbon dioxide, nitrogen, water vapor, hydrogen sulfide, helium, and other trace gases, and liquids including water, and other liquids.
  • heavy hydrocarbons may be separated from hydrocarbon gases.
  • the hydrocarbon from which the contaminants are separated according to the present invention may be oil, methane, ethane, propane, or others.
  • Each one of the stacked membrane units 20 may be designed to permeate one or more of the contaminants which are present in the well.
  • one membrane unit 20 may be designed for removal of carbon dioxide, a second for removal of hydrogen sulfide, and a third for removal of water.
  • a hollow fiber or tubular shaped membrane formed of multiple membrane elements is illustrated, other membrane shapes may also be used. Some other membrane shapes includes spiral wound, pleated, flat sheet, or polygonal tubes. The use of multiple hollow fiber membrane tubes have been selected for their large fluid contact area. The contact area may be further increased by adding additional tubes or tube contours.
  • the membrane units 20 may be stacked in different arrangements to removed contaminants from the flow of hydrocarbon gas in different orders. For example, the bottom membrane units 20 may be those that remove water and heavy hydrocarbons which may damage some of the membrane materials.
  • the membrane units 20 may be arranged in series or parallel configurations or in combinations thereof depending on the particular application.
  • the separation system according to the present invention may be of a variable length depending on the particular application.
  • the stacked membrane units 20 may even extend along the entire length of the wellbore for maximum contaminant removal.
  • FIG. 1 illustrates an inside-out flow path where the hydrocarbon and contaminants flow into the inside of the membrane tube(s) and the contaminant permeates out through the tube.
  • an outside-in flow path may also be used where the hydrocarbon and contaminants flow around the outside of the tube(s) and the contaminants are permeated into the inner bore of the tube(s).
  • the membranes according to the present invention are selected to be durable, resistant to high temperatures, and resistant to exposure to liquids.
  • the materials may be coated or otherwise protected to help prevent fouling and improve durability.
  • suitable membrane materials for removal of contaminants from a hydrocarbon gas stream include cellulose acetate, polysulfones, polyimides, cellulose triacetate (CTA), carbon molecular sieve membranes, ceramic and other inorganic membranes, composites comprising any of the above membrane materials with another polymer, composite polymer and molecular sieve membranes including polymer zeolite composite membranes, polytrimethylsilene (PTMSP), and rubbery polymers.
  • polyimides are the asymmetric aromatic polyimides in hollow fiber or flat sheet form. Patents describing these include U.S. Patent No. 5,234,471 and U.S. Patent No 4,690,873.
  • carbon molecular sieve membranes are those prepared from the pyrolysis of asymmetric aromatic polyimide or cellulose hollow fibers.
  • Patents describing these include European Patent Application 0 459 623 and U.S. Patent No 4,685,940. These fibers may be coated with a separate polymer or post-treated after spinning to increase resistance to high humidity and impurities, such as in U.S. Patent No. 5,288,304 and U.S. Patent No. 4,728,345.
  • the number, type, and configuration of the membranes may vary depending on the particular well.
  • the separation system may be specifically designed for a particular well taking into account the type and amounts of hydrocarbon and contaminants present in the well, and the well configuration.
  • the present invention may be combined with existing downhole technologies for mechanical physical separation systems, such as cyclones or centrifugal separation systems.
  • the invention may also be used for partial removal of the contaminants to reduce the burden on surface removal facilities with the remaining contaminants removed by conventional surface technologies.
  • Some types of separated contaminants such as carbon dioxide can be reinjected into the productive horizon to maintain pressurization of the reservoir.

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  • Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Geology (AREA)
  • Mining & Mineral Resources (AREA)
  • Physics & Mathematics (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Chemical & Material Sciences (AREA)
  • Dispersion Chemistry (AREA)
  • Separation Using Semi-Permeable Membranes (AREA)

Abstract

L'invention concerne un système de séparation (10) récupérable qui permet de séparer les hydrocarbures des contaminants. Ce système, installé à l'intérieur d'un conduit ou d'un tubage (54) de production dans un puits de forage, peut être aisément récupéré au moyen d'un outil de récupération sans que cela nécessite l'enlèvement de l'ensemble de la colonne de production. Le système de séparation récupérable comporte notamment plusieurs membranes (20 ou 110) et des raccords de réduction (30) que l'on peut récupérer à l'aide de l'élément de préhension d'un outil de récupération. La membrane (20) peut comporter un matériel (112, 114, 116 et 118) réutilisable permettant de loger une membrane de rechange (130). On peut utiliser de nouvelles membranes pour remplacer les membranes usées, la membrane (20) étant réinstallée dans le puits de forage en vue d'une séparation ultérieure des hydrocarbures et des contaminants.
PCT/US2001/025545 2000-08-17 2001-08-14 Procede et appareil de separation, dans le puits de forage, des hydrocarbures de contaminants a l'aide de membranes reutilisables contenant des elements de membranes recuperables Ceased WO2002014647A1 (fr)

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Application Number Priority Date Filing Date Title
AU2001286493A AU2001286493A1 (en) 2000-08-17 2001-08-14 Method and apparatus for wellbore separation of hydrocarbons from contaminants with reusable membrane units containing retrievable membrane elements

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US64062300A 2000-08-17 2000-08-17
US64057300A 2000-08-17 2000-08-17
US09/640,623 2000-08-17
US09/640,573 2000-08-17

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Cited By (26)

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US7370701B2 (en) 2004-06-30 2008-05-13 Halliburton Energy Services, Inc. Wellbore completion design to naturally separate water and solids from oil and gas
US7429332B2 (en) 2004-06-30 2008-09-30 Halliburton Energy Services, Inc. Separating constituents of a fluid mixture
US7462274B2 (en) 2004-07-01 2008-12-09 Halliburton Energy Services, Inc. Fluid separator with smart surface
US7823635B2 (en) 2004-08-23 2010-11-02 Halliburton Energy Services, Inc. Downhole oil and water separator and method
US8235128B2 (en) 2009-08-18 2012-08-07 Halliburton Energy Services, Inc. Flow path control based on fluid characteristics to thereby variably resist flow in a subterranean well
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US8276669B2 (en) 2010-06-02 2012-10-02 Halliburton Energy Services, Inc. Variable flow resistance system with circulation inducing structure therein to variably resist flow in a subterranean well
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US8418725B2 (en) 2010-12-31 2013-04-16 Halliburton Energy Services, Inc. Fluidic oscillators for use with a subterranean well
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US8646483B2 (en) 2010-12-31 2014-02-11 Halliburton Energy Services, Inc. Cross-flow fluidic oscillators for use with a subterranean well
US8678035B2 (en) 2011-04-11 2014-03-25 Halliburton Energy Services, Inc. Selectively variable flow restrictor for use in a subterranean well
US8684094B2 (en) 2011-11-14 2014-04-01 Halliburton Energy Services, Inc. Preventing flow of undesired fluid through a variable flow resistance system in a well
US8733401B2 (en) 2010-12-31 2014-05-27 Halliburton Energy Services, Inc. Cone and plate fluidic oscillator inserts for use with a subterranean well
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US8449750B2 (en) 2004-07-01 2013-05-28 Halliburton Energy Services, Inc. Fluid separator with smart surface
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US8905144B2 (en) 2009-08-18 2014-12-09 Halliburton Energy Services, Inc. Variable flow resistance system with circulation inducing structure therein to variably resist flow in a subterranean well
US8327885B2 (en) 2009-08-18 2012-12-11 Halliburton Energy Services, Inc. Flow path control based on fluid characteristics to thereby variably resist flow in a subterranean well
US9394759B2 (en) 2009-08-18 2016-07-19 Halliburton Energy Services, Inc. Alternating flow resistance increases and decreases for propagating pressure pulses in a subterranean well
US8235128B2 (en) 2009-08-18 2012-08-07 Halliburton Energy Services, Inc. Flow path control based on fluid characteristics to thereby variably resist flow in a subterranean well
US8479831B2 (en) 2009-08-18 2013-07-09 Halliburton Energy Services, Inc. Flow path control based on fluid characteristics to thereby variably resist flow in a subterranean well
US8893804B2 (en) 2009-08-18 2014-11-25 Halliburton Energy Services, Inc. Alternating flow resistance increases and decreases for propagating pressure pulses in a subterranean well
US8291976B2 (en) 2009-12-10 2012-10-23 Halliburton Energy Services, Inc. Fluid flow control device
US8261839B2 (en) 2010-06-02 2012-09-11 Halliburton Energy Services, Inc. Variable flow resistance system for use in a subterranean well
US8276669B2 (en) 2010-06-02 2012-10-02 Halliburton Energy Services, Inc. Variable flow resistance system with circulation inducing structure therein to variably resist flow in a subterranean well
US8356668B2 (en) 2010-08-27 2013-01-22 Halliburton Energy Services, Inc. Variable flow restrictor for use in a subterranean well
US8376047B2 (en) 2010-08-27 2013-02-19 Halliburton Energy Services, Inc. Variable flow restrictor for use in a subterranean well
US8464759B2 (en) 2010-09-10 2013-06-18 Halliburton Energy Services, Inc. Series configured variable flow restrictors for use in a subterranean well
US8950502B2 (en) 2010-09-10 2015-02-10 Halliburton Energy Services, Inc. Series configured variable flow restrictors for use in a subterranean well
US8430130B2 (en) 2010-09-10 2013-04-30 Halliburton Energy Services, Inc. Series configured variable flow restrictors for use in a subterranean well
US8851180B2 (en) 2010-09-14 2014-10-07 Halliburton Energy Services, Inc. Self-releasing plug for use in a subterranean well
US8646483B2 (en) 2010-12-31 2014-02-11 Halliburton Energy Services, Inc. Cross-flow fluidic oscillators for use with a subterranean well
US8733401B2 (en) 2010-12-31 2014-05-27 Halliburton Energy Services, Inc. Cone and plate fluidic oscillator inserts for use with a subterranean well
US8418725B2 (en) 2010-12-31 2013-04-16 Halliburton Energy Services, Inc. Fluidic oscillators for use with a subterranean well
US8678035B2 (en) 2011-04-11 2014-03-25 Halliburton Energy Services, Inc. Selectively variable flow restrictor for use in a subterranean well
US8844651B2 (en) 2011-07-21 2014-09-30 Halliburton Energy Services, Inc. Three dimensional fluidic jet control
US8863835B2 (en) 2011-08-23 2014-10-21 Halliburton Energy Services, Inc. Variable frequency fluid oscillators for use with a subterranean well
US8955585B2 (en) 2011-09-27 2015-02-17 Halliburton Energy Services, Inc. Forming inclusions in selected azimuthal orientations from a casing section
US10119356B2 (en) 2011-09-27 2018-11-06 Halliburton Energy Services, Inc. Forming inclusions in selected azimuthal orientations from a casing section
US8967267B2 (en) 2011-11-07 2015-03-03 Halliburton Energy Services, Inc. Fluid discrimination for use with a subterranean well
US8739880B2 (en) 2011-11-07 2014-06-03 Halliburton Energy Services, P.C. Fluid discrimination for use with a subterranean well
US9506320B2 (en) 2011-11-07 2016-11-29 Halliburton Energy Services, Inc. Variable flow resistance for use with a subterranean well
US8684094B2 (en) 2011-11-14 2014-04-01 Halliburton Energy Services, Inc. Preventing flow of undesired fluid through a variable flow resistance system in a well
US9598930B2 (en) 2011-11-14 2017-03-21 Halliburton Energy Services, Inc. Preventing flow of undesired fluid through a variable flow resistance system in a well
US9127526B2 (en) 2012-12-03 2015-09-08 Halliburton Energy Services, Inc. Fast pressure protection system and method
US9695654B2 (en) 2012-12-03 2017-07-04 Halliburton Energy Services, Inc. Wellhead flowback control system and method

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