US20130223935A1 - Methods and arrangements for carbon dioxide storage in subterranean geological formations - Google Patents

Methods and arrangements for carbon dioxide storage in subterranean geological formations Download PDF

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US20130223935A1
US20130223935A1 US13/814,169 US201113814169A US2013223935A1 US 20130223935 A1 US20130223935 A1 US 20130223935A1 US 201113814169 A US201113814169 A US 201113814169A US 2013223935 A1 US2013223935 A1 US 2013223935A1
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conduit
arrangement
geological formation
formation
distal portion
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Lars Høier
Bamshad Nazarian
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Equinor Energy AS
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Statoil Petroleum ASA
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Assigned to STATOIL PETROLEUM AS reassignment STATOIL PETROLEUM AS ASSIGNMENT OF ASSIGNORS INTEREST (SEE DOCUMENT FOR DETAILS). Assignors: BAMSHAD, NAZARIAN, HOIER, LARS
Publication of US20130223935A1 publication Critical patent/US20130223935A1/en
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    • 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
    • E21B41/00—Equipment or details not covered by groups E21B15/00 - E21B40/00
    • E21B41/005—Waste disposal systems
    • E21B41/0057—Disposal of a fluid by injection into a subterranean formation
    • E21B41/0064—Carbon dioxide sequestration
    • 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
    • E21B41/00—Equipment or details not covered by groups E21B15/00 - E21B40/00
    • E21B41/0035—Apparatus or methods for multilateral well technology, e.g. for the completion of or workover on wells with one or more lateral branches
    • 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
    • E21B43/12—Methods or apparatus for controlling the flow of the obtained fluid to or in wells
    • 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
    • E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
    • E21B43/162—Injecting fluid from longitudinally spaced locations in injection well
    • 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
    • E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
    • E21B43/164—Injecting CO2 or carbonated water
    • 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
    • E21B43/30—Specific pattern of wells, e.g. optimising the spacing of wells
    • E21B43/305—Specific pattern of wells, e.g. optimising the spacing of wells comprising at least one inclined or horizontal well
    • 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
    • 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
    • Y02P—CLIMATE CHANGE MITIGATION TECHNOLOGIES IN THE PRODUCTION OR PROCESSING OF GOODS
    • Y02P90/00—Enabling technologies with a potential contribution to greenhouse gas [GHG] emissions mitigation
    • Y02P90/70—Combining sequestration of CO2 and exploitation of hydrocarbons by injecting CO2 or carbonated water in oil wells

Definitions

  • the invention relates to methods and arrangements for carbon dioxide (CO 2 ) storage in subterranean geological formations.
  • the invention relates to arrangements and methods which maximize the amount of CO 2 storable in a particular formation, thus increasing the usable capacity of a respective reservoir.
  • CO 2 injection into a subterranean geological formation for Enhanced Oil Recovery (EOR) has been applied in the Rangely EOR project, Colorado, USA.
  • a sandstone oil reservoir has been flooded with CO 2 by a water-alternating-gas (WAG) process since 1986.
  • WAG water-alternating-gas
  • CO 2 in a supercritical state is used to extract additional amounts of oil from the otherwise exhausted oil fields in a tertiary oil recovery process.
  • 248 active injectors of which 160 are used for CO 2 injection and 348 active producers were in use in the Rangely field. Injection of CO 2 occurs through slots in multiple vertical wells. Vertical wells have a relatively low injection capacity; therefore a great number of such wells are needed. This technology is thus laborious and expensive.
  • the Sleipner Project operated by Statoil in the North Sea, is a commercial scale project for the storage of CO 2 in a subterranean aquifer.
  • CO 2 is stored in supercritical state 250 km off the Norwegian coast. About one million tons of CO 2 is removed from produced natural gas and subsequently injected underground, annually. CO 2 injection started in October 1996 and by 2008, more than ten million tons of CO 2 had been injected at a rate of approximately 2700 tons per day.
  • the formation into which the CO 2 is injected is a brine-saturated unconsolidated sandstone about 800-1000 m below the sea floor. A shallow long-reach well is used to take the CO 2 2.4 km away from the producing wells and platform area.
  • the injection site is placed beneath a local dome of the top Utsira formation. Since all CO 2 is injected at approximately the terminal end of the long reach well, the CO 2 is not efficiently distributed over large areas of the receiving Utsira Formation. Thus the capacity of the subterranean geological formation is not used to its full extent.
  • the In Salah CCS Project is an onshore project for the production of natural gas from a gas reservoir located in a subterranean aquifer.
  • the aquifer is located in the Sahara desert.
  • the reservoir is in a carboniferous sandstone formation, 2000 m deep. It is only 20 m thick, and of generally low permeability.
  • Natural gas containing up to 10% of CO 2 is produced. CO 2 is separated, and subsequently re-injected into the water-filled parts of the reservoir.
  • the project uses four production and three injection wells. Three long-reach horizontal wells with slotted intervals over 1 km are used to inject 1 MtCO 2 per year. The amount of CO 2 injected through the slotted intervals depends from the local permeability of the formation at the respective slotted intervals.
  • U.S. Pat. No. 5,503,226 mentions injection of fluid into geological formations. It discloses a process for recovering hydrocarbons from a subterranean formation having low permeability matrix blocks and high permeability matrix blocks.
  • Hot light gas in one embodiment, CO 2 gas
  • an injection/production well which comprises a vertical section and a horizontal section. The vertical section is cased, while the horizontal section is completed open hole.
  • CO 2 is injected into the horizontal open hole section through the terminal opening of a tubing string disposed within the well. No means for providing an even distribution of CO 2 injection into the formation over the longitudinal extent of the well is provided. Hence, an uneven distribution of (local) CO 2 injection results.
  • GB 2325949 discloses a method for obtaining equalized production from deviated production wells comprising a plurality of spaced apart flow control devices. Each control device includes a flow valve and control units to control inflow of oil into the production well. The fluid from various zones are drawn in a manner that depletes the reservoir uniformly along the entire length of the production well. GB 2325949, however, is not concerned with the injection of fluids, in particular CO 2 , into geological formations. The use of flow control devices for the injection of fluids into formations is not envisaged or suggested. Nor is there any indication that the disclosed flow control devices would be suitable for injection, in particular for CO 2 injection.
  • GB 2376488 discloses an apparatus and method for controlling fluid production in a deviated production well which comprises a plurality of inflow control valves.
  • the valves are self regulating or selectively controllable, and they maintain a substantially constant pressure drop between the exterior and the interior of the flow pipe.
  • Application of the controlling devices for CO 2 injection, or the suitability of the inflow control valves, is not shown or suggested.
  • U.S. Pat. No. 5,141,054 discloses a well completion method for steam stimulation of vertical and horizontal oil production wells. Steam is injected through multiple perforations of controlled size, and used for lowering the viscosity of the viscous hydrocarbonaceous fluids in the vicinity of the horizontal well. The method seeks to achieve a uniform heating along a desired length of the horizontal well. Storage of the injected fluid, let alone, increasing the storage capacity of the formation for such fluids, is not envisaged or taught.
  • U.S. Pat. No. 5,826,655 discloses a method and an apparatus for enhanced viscous oil recovery.
  • a horizontal well is drilled through a viscous oil formation, and a specially designed steam injection tube, with multiple holes, is used to evenly inject the steam into an outer lumen of the horizontal wellbore.
  • the multiple holes in the steam injection tube are each provided with a sacrificial impingement strap, in order to avoid direct impingement of steam on the slotted liner, and thus, to prevent early erosion of the slotted liner.
  • Steam enters the geological formation not through these multiple holes, but through the slots of the conventional slotted liner, provided around the injection tube. Since the steam can freely move in the annular lumen, laterally outward the injection tube and laterally inward the slotted liner, nothing prevents the steam to enter the geological formation preferentially in parts of the formation having high permeability for steam.
  • WO 2008/092241 discloses a method for enhanced oil recovery, in which method steam is distributed and injected through perforations into an annular space between an inner tubing and an outer slotted liner in a horizontal injection well. The steam is then injected from the annular space into the oil containing geological formation through slots in the conventional slotted liner.
  • the inner tubing string is provided with multiple ports having a selected distribution and geometry. This causes the steam to be injected into the annular space in a defined manner. Injection of steam into the geological formation is additionally controlled by varying the cross sectional area of the annular space between the inner tubing and slotted liner, such that the axial flow resistance in the annular space is controlled.
  • the perforated tubing is placed directly in an open hole well bore.
  • US2009008092 A1 discloses various inflow control devices for use in oil production.
  • the inflow control devices include a plurality of openings that each provide a flow path to the interior of the production tube. It is not disclosed that the disclosed devices can be used in the reversed flow directions, nor is it likely that they are suitable for controlling the flow of less viscous fluids, such as CO 2 .
  • WO 2009/088293 discloses a method for self-adjusting the flow of fluid through a valve or flow control device in injectors in oil production.
  • U.S. Pat. No. 5,435,393 A discloses a method for production of oil or gass from an oil or gas reservoir and a production pipe for injection of fluids into an oil or gas reservoir.
  • the present invention relates to a arrangement for injecting CO 2 in a supercritical state into a subterranean geological formation, said arrangement comprising a conduit having a proximal portion and a distal portion, at least part of said distal portion extending in a substantially horizontal direction; multiple openings being provided in said distal portion of said conduit for injection of CO 2 into said geological formation; wherein at least one, or all, of said multiple openings is/are provided with outflow limiting means for limiting the flow rate of CO 2 through the respective opening into said geological formation.
  • said multiple openings are provided in a lateral surface of said conduit.
  • the strength of the outflow limiting means in reducing the outflow between each two neighboring outflow limiting means is decreasing along the length of said conduit in the direction towards the distal end.
  • each two neighboring outflow limiting means is decreasing along the length of said conduit in the direction towards the distal end.
  • At least one said outflow limiting means is adjustable.
  • said conduit is a branched conduit comprising a primary branch and at least one secondary branch.
  • the at least one secondary branch preferably branches off said primary branch in a branch point, said branch point being provided with branch-flow controlling means for limiting the flow of CO 2 into the respective secondary branch.
  • branch-flow controlling means for limiting the flow of CO 2 into the respective secondary branch.
  • said at least one secondary conduit is substantially horizontal.
  • said secondary conduit that branches off said primary branch in a branch point near a distal end of the said main conduit can be left as open hole.
  • the conduit is closed at its distal ends.
  • a distal end portion of the conduit is left as open hole.
  • said arrangement comprises pressure producing means for producing a pressure in said conduit sufficient for injection of CO 2 in a supercritical state into said geological formation.
  • the arrangement may comprise a source of CO 2 .
  • the pressure producing means may be, e.g., a pump, a pressurized CO 2 container, or a pressurized CO 2 pipeline.
  • said outflow limiting means comprises at least one capillary fluidly connecting an inner lumen of said conduit with said geological formation.
  • said capillary opens at its proximal end towards an inner lumen of said conduit, and opens at its distal end into the geological formation.
  • said capillary is a helical capillary, coiled around, and laterally outward, an inner surface of said conduit.
  • said capillary has a circular, a triangular, a rectangular or a quadratic cross sectional area.
  • the capillary has preferably a cross sectional area of 10 mm 2 to 500 mm 2 .
  • the capillary has a length of from 10 cm to 500 m, from 10 cm to 200 m, or preferably from 1 m to 100 m.
  • the length of the capillary is more than 5 times, 10 times, 20 times, 100 times, or 1000 times larger than the largest diameter of the capillary.
  • the length of the capillary is more than 5 times, 10 times, 20 times, 100 times, or preferably 1000 times larger than the square root of the largest cross-sectional area of the capillary.
  • the geological formation is an aquifer, or a confined aquifer, or a closed aquifer.
  • said arrangement is for the permanent storage of CO 2 in said geological formation.
  • the present invention also relates to the use of arrangements of the invention for CO 2 injection into subterranean geological formations.
  • the present invention also relates to methods for storing CO 2 in subterranean geological formations using the arrangements described above.
  • the invention thus also relates to a method for storage of CO 2 in a subterranean geological formation, said method comprising: introducing CO 2 into a conduit having a proximal portion and a distal portion, at least part of said distal portion extending in a substantially horizontal direction; wherein multiple openings are provided in said distal portion of said conduit, each provided with flow limiting means for limiting the flow rate of CO 2 through each said multiple openings into said geological formation, and injecting said CO 2 in a supercritical state through said multiple openings into said geological formation.
  • FIG. 1 shows a first embodiment of the invention.
  • FIG. 2 shows a second embodiment of the invention.
  • FIG. 3 shows flow limiting means according to one aspect of the current invention.
  • the present invention relates to methods and arrangements for the permanent storage of CO 2 in subterranean geological formations.
  • An “aquifer”, within the context of the present invention shall be understood as being an underground layer of water-bearing permeable rock or unconsolidated materials (gravel, sand, silt, or clay).
  • An aquifer may be sealed by an aquitard or aquiclude at an upper or lower boundary. Such aquifers are hereinafter referred as “confined aquifers”.
  • An aquifer may also be sealed at both the upper and lower boundary.
  • Such aquifers are hereinafter referred to as “closed aquifers”.
  • Preferred aquifers, according to the invention are upwardly convex aquifers, or downwardly convex aquifers.
  • the “aquifer”, within the context of the present invention may also be referred to as the “reservoir”.
  • Flow limiting means in the context of the present invention, shall be understood as being any means that is suitable for limiting the mass flow of fluid through an opening or conduit, preferably in a defined manner.
  • Preferred flow limiting means comprise elongated conduits of a relatively small diameter, e.g., a capillary.
  • Preferred capillaries have a circular, elliptic, rectangular, or quadratic cross-sectional area.
  • a “capillary”, according to the present invention, shall be understood as being an elongated channel.
  • the use of the expression “capillary” is not to imply that the capillary confers its pressure reducing effect entirely by so-called “capillary forces”.
  • a pressure drop along the length of a capillary of the present invention preferably stems from the friction of fluids moving along the elongated channel of the capillary.
  • An “openhole”, or a “well completed open hole”, shall be understood to relate an uncased portion of a well, i.e., the well in a state when it is drilled, with no casing, liner, or similar, provided at its outer circumference.
  • Permeability of a formation is the property of the formation to transmit fluids in response to an imposed pressure difference. Permeability is typically measured in darcies or millidarcies. [Converted to SI units, 1 darcy is equivalent to 9.869233 ⁇ 10-13 m 2 or 0.9869233 ( ⁇ m) 2 . This conversion may be approximated as 1 ( ⁇ m) 2 .] Formations that transmit fluids readily, such as sandstones, are described as permeable and tend to have many large, well-connected pores.
  • Impermeable formations such as shales and siltstones, tend to be finer grained or of a mixed grain size, with smaller, fewer, or less interconnected pores.
  • “Substantially horizontal”, in the context of the present invention, shall mean at an angle of between 45°-135°, or 80°-100°, or 85°-95°, or 90° from the vertical. “Substantially vertical”, in the context of the present invention, shall mean at an angle of less than 45°, less than 20°, less than 10°, less than 5°, or 0° from the vertical.
  • the present invention is based on the unexpected finding that the available storage capacity of a geological formation for CO 2 can most effectively be used, if the CO 2 is injected from multiple injection points along the length of a long-reach horizontal well in such a way that the mass flow of CO 2 into the formation is approximately constant over the entire length of the horizontal well. While previously, a common wish in the art has been to inject large amounts of CO 2 in as short a time period as possible, the inventors of the present invention have taken a very different approach. By limiting the radial mass flow of CO 2 to a certain maximum value, the present invention produces a substantially even distribution of the radial mass flow over major parts of the horizontal extent of the injection well. This leads to a reduced radial mass flow [kg/s] into the formation, but this obstacle is more than outweighed by the fact that the total amount of CO 2 , which can be stored in a particular formation, is dramatically increased.
  • FIG. 1 generally shows an arrangement of the present invention.
  • Arrangement 1 is used to inject large amounts of CO 2 in the subterranean formation for permanent storage of CO 2 therein.
  • a conduit 3 which extends from a point above surface down into formation 2 in which the CO 2 is to be stored.
  • the geological formation can be, e.g., a depleted oil field, a depleted gas field, or an aquifer.
  • the aquifer is preferably a closed aquifer, or a confined aquifer.
  • the geological formation is preferably more than 500 m under ground.
  • the geological formation is preferably 5 to 1000 m, preferably 20 to 200 m thick.
  • Conduit 3 comprises a proximal end portion 4 and a distal end portion 5 .
  • the distal end portion 5 comprises a generally horizontal portion.
  • the horizontal (distal) portion is preferably provided in form of a long-reach horizontal well, and is preferably between 100 m and 2000 m long. This allows CO 2 to be injected into the formation at multiple injection points over the entire length of the conduit. CO 2 storage is thereby distributed over a large area/volume of the reservoir formation.
  • the arrangement comprises pressure producing means 10 , e.g., a pump, for injecting CO 2 into the geological formation.
  • the pressure producing means may be a pressurized CO 2 container, or a pressurized CO 2 pipeline.
  • the CO 2 when injected, is preferably in a supercritical state.
  • all components of the arrangement must be appropriately designed and constructed such as to be able to sustain the harsh conditions of its operation. Materials must be appropriately chosen to resist the very high pressures and the corrosion, in particular, when the CO 2 injected is not pure CO 2 , but contains, e.g., water and/or other corrosive contaminants, such as O 2 or SO 2 .
  • Pressure producing means preferably are able to produce pressures of more than 73, 100, 200, 500, or 1000 bar.
  • Conduit 3 comprises multiple openings 6 a - 6 z in a distal portion, through which openings CO 2 is injected into the formation. At least one, but preferably all openings are provided with outflow limiting means 7 a - 7 z .
  • the outflow limiting means 7 a - 7 z serve to reduce the radial mass flow of CO 2 through the individual openings 6 a - 6 z .
  • the radial mass flow is most efficiently reduced in areas of the formation having high permeability. This is due to the fact that the radial mass flow in these areas—without outflow limiting means—would be very large. In areas of the formation having a low permeability for CO 2 , the mass flow into the formation is low from the outset.
  • FIG. 2 shows a second embodiment of the invention.
  • conduit 3 is a branched conduit.
  • Secondary branch 9 branches off primary branch 8 in branch point 10 . Multiple secondary branches 9 may be provided.
  • conduit 3 further comprises tertiary branches, or even higher order branches, branching off the respective lower order branches.
  • branch-flow controlling means 13 may be provided.
  • Branch-flow controlling means 13 may be in form of a throttle or a valve, preferably a controllable valve.
  • Outflow limiting means 7 a - 7 z may be in form of an elongated capillary.
  • Preferred capillaries have a circular, elliptic, rectangular, or quadratic cross-sectional area. They preferably have a cross sectional area of from 10 mm 2 to 500 mm 2 , and independently, a preferred length of from 10 cm to 500 m, from 10 cm to 200 m, or from 1 m to 100 m.
  • Preferred capillaries of the invention are helically coiled.
  • Capillaries of the present invention are preferably designed such that, under operating conditions, they produce a pressure drop along the length of the capillary of from 0.5 bar to 5 bar.
  • the outflow limiting means 7 a - 7 z can be modified “inflow control devices” (ICDs), e.g., of the type disclosed in US2009008092 A1.
  • ICDs inflow control devices
  • those ICDs used for oil production are normally not suitable, and need significant modification in order to be useful in the context of the present invention. This is, i.a., due to the fact that the direction of fluid flow through the devices is reversed.
  • the viscosity of fluids in oil production is generally higher than the one of CO 2 , e.g., in a supercritical state.
  • the cross sectional area and/or length of conduits of the ICDs must be appropriately changed.
  • the applicable pressure regime is different in methods of the present inventions as compared to oil production. While in methods of the present invention, the pressure in interior of the injection well can be deliberately chosen, e.g., by the appropriate pressure producing means, in oil production the pressure driving the fluid transport is normally determined by the pressure naturally occurring in the reservoir.
  • Outflow limiting means 7 a - 7 z may be provided in form of an elongated channel or capillary 12 .
  • Flow limiting means 7 a - 7 z can be adjustable. Adjustment of the outflow limiting effect can be achieved by controlling (reducing or increasing) the cross-sectional area of the elongated channels or capillaries.
  • the flow through flow limiting means 7 a - 7 z can also be adjusted by, e.g., controlling the effective length of the elongated channels or capillaries.
  • the flow through flow limiting means 7 a - 7 z can be adjusted by changing the shape of the cross-sectional area in channels or capillaries of flow limiting means 7 a - 7 z.
  • the flow limiting means 7 are in form of a helical capillary 12 , wound around, and disposed radially outward, an inner surface of conduit 3 .
  • Capillary 12 opens at a first (proximal) end 19 into inner lumen 18 of conduit 3 .
  • a second (distal) end 20 of capillary 12 opens into formation 2 .
  • Second end 20 may also open into a sand screen or pervious liner (not shown) provided radially outward of conduit 3 .
  • Conduit 3 is thus preferably in close contact with the pervious liner.
  • the pervious liner is preferably in close contact with the formation.
  • Elongated channels or capillaries 12 of a certain length are able to effectively control the mass flow of fluid at relatively modest pressures. Therefore, pumps of lower performance and price can be used. Furthermore, operation under lower pressure also reduces erosion of the system's components, thus, the lifetime of the system is increased.
  • Outflow limiting means 7 a - 7 z generally produce a significant pressure drop between their respective first and second ends. For this reason, the pressure required in conduit 4 for inducing a sufficient radial mass flow is significantly higher than with conventional slotted wells.
  • a plug 17 is preferably provided in a distal end of the conduit.
  • the distal ends of conduit 3 are not provided with a plug. They may be open-hole wells. The latter embodiments may be suitable in situations where the formation has low permeability at the distal ends of conduit 3 , or where the horizontal portion 5 is very long.
  • conduit 3 may comprise multiple impervious segments 15 and multiple outflow segments 16 , wherein the multiple openings 6 a - 6 z provided only in the outflow segments 16 (i.e., not in impervious segments 15 ). There may be provided multiple openings 6 a - 6 z , or multiple helical capillaries 12 , per outflow segment 16 .
  • Outflow segments 16 and impervious segments 15 are preferably provided with a male fitting at one end and with female fitting at the other end. Impervious segments 15 can be fitted to each other, and to outflow segments 16 . Likewise, outflow segments 16 can be fitted to each other, and can be fitted to impervious segments 15 . A seal 14 is preferably provided between any two connected impervious segments 15 and/or outflow segments 16 . Conduit 3 may thus be of modular construction.
  • Outflow segments 16 are preferably in direct contact with the formation, i.e., there is preferably no annular gap or space between the outflow segment and the reservoir material. This is useful for avoiding significant axial flow of CO 2 radially outward conduit 3 .
  • the outer surface of outflow segment 16 (and preferably also the outer surface of impervious segment 15 ) contacts formation 2 .
  • radially outward conduit 3 e.g., radially outward of outflow segments 16 and/or impervious segments 15
  • a sand-screen or a pervious liner (not shown).
  • the sand-screen or pervious liner preferably contacts the conduit and the formation, such as to prevent significant axial mass flow of CO 2 .
  • the pervious liner is preferably of a material having a permeability in the radial direction (for CO 2 ) which is equal to, or greater than, its permeability for CO 2 in the axial direction.

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  • Environmental & Geological Engineering (AREA)
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US13/814,169 2010-08-04 2011-08-03 Methods and arrangements for carbon dioxide storage in subterranean geological formations Abandoned US20130223935A1 (en)

Applications Claiming Priority (3)

Application Number Priority Date Filing Date Title
NO20101106A NO338616B1 (no) 2010-08-04 2010-08-04 Anordning og fremgangsmåte for lagring av karbondioksid i underjordiske geologiske formasjoner
NO20101106 2010-08-04
PCT/EP2011/063370 WO2012017010A1 (en) 2010-08-04 2011-08-03 Methods and arrangements for carbon dioxide storage in subterranean geological formations

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EP (1) EP2601376A1 (no)
AU (1) AU2011287564A1 (no)
BR (1) BR112013003678A2 (no)
CA (1) CA2807194A1 (no)
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CA2807194A1 (en) 2012-02-09
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AU2011287564A1 (en) 2013-02-28
WO2012017010A1 (en) 2012-02-09
EP2601376A1 (en) 2013-06-12

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