US20090101344A1 - Water Dissolvable Released Material Used as Inflow Control Device - Google Patents
Water Dissolvable Released Material Used as Inflow Control Device Download PDFInfo
- Publication number
- US20090101344A1 US20090101344A1 US11/875,499 US87549907A US2009101344A1 US 20090101344 A1 US20090101344 A1 US 20090101344A1 US 87549907 A US87549907 A US 87549907A US 2009101344 A1 US2009101344 A1 US 2009101344A1
- Authority
- US
- United States
- Prior art keywords
- fluid
- flow
- medium
- flow path
- control device
- 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.)
- Abandoned
Links
Images
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B34/00—Valve arrangements for boreholes or wells
- E21B34/06—Valve arrangements for boreholes or wells in wells
- E21B34/08—Valve arrangements for boreholes or wells in wells responsive to flow or pressure of the fluid obtained
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP 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
Definitions
- the invention relates generally to systems and methods for selective control of fluid flow into a wellbore.
- Hydrocarbons such as oil and gas are recovered from a subterranean formation using a wellbore drilled into the formation.
- Such wells are typically completed by placing a casing along the wellbore length and perforating the casing adjacent each such production zone to extract the formation fluids (such as hydrocarbons) into the wellbore.
- These production zones are sometimes separated from each other by installing a packer between the production zones. Fluid from each production zone entering the wellbore is drawn into a tubing that runs to the surface. It is desirable to have substantially even drainage along the production zone. Uneven drainage may result in undesirable conditions such as an invasive gas cone or water cone. In the instance of an oil-producing well, for example, a gas cone may cause an inflow of gas into the wellbore that could significantly reduce oil production.
- a water cone may cause an inflow of water into the oil production flow that reduces the amount and quality of the produced oil. Accordingly, it is desired to provide even drainage across a production zone and/or the ability to selectively close off or reduce inflow within production zones experiencing an undesirable influx of water and/or gas.
- the present disclosure provides an apparatus for controlling flow of a fluid into a wellbore tubular.
- the apparatus may include an in-flow control device controlling the flow of the fluid, an element co-acting with the in-flow control device, and a disintegrating medium at least partially surrounding the element.
- the medium may be configured to release the element upon disintegration of the medium.
- the disintegrating medium may be configured to disintegrate when exposed to a selected fluid.
- the element or elements, when released, may at least partially restrict flow across a flow path that conveys the fluid from the formation to a flow bore of the wellbore tubular.
- the element may be positioned along the flow path or elsewhere.
- the element may be: a liquid, a solid, a particle and/or particles.
- the selected fluid may be water, a hydrocarbon, an engineered fluid, and/or a naturally occurring fluid.
- the present disclosure provides a method for controlling a flow of fluid from a subterranean formation.
- the method may include suspending an element in a medium that disintegrates when exposed to a selected fluid; positioning the element in a wellbore; and restricting a fluid flow across a flow path by releasing the element.
- the method may include releasing the element into the flow path when the medium disintegrates.
- the present disclosure provides a system for controlling flow of a fluid in a well.
- the system may include a wellbore tubular positioned in the well; an in-flow control device positioned along the wellbore tubular; an element co-acting with the in-flow control device; and a disintegrating medium at least partially surrounding the element, the disintegrating medium being calibrated to disintegrate when exposed to a selected fluid.
- FIG. 1 is a schematic elevation view of an exemplary multi-zonal wellbore and production assembly which incorporates an inflow control system in accordance with one embodiment of the present disclosure
- FIG. 2 is a schematic elevation view of an exemplary open hole production assembly which incorporates an inflow control system in accordance with one embodiment of the present disclosure
- FIG. 3 is a schematic cross-sectional view of an exemplary production control device made in accordance with one embodiment of the present disclosure
- FIGS. 4A-4B schematically illustrate a material suspended in a medium in accordance with one embodiment of the present disclosure that may be released to actuate a flow restriction element
- FIGS. 5A-5B schematically illustrate a material suspended in a medium that is made in accordance with one embodiment of the present disclosure that may be released to restrict fluid flow;
- FIGS. 6A-6B schematically illustrate occlusion elements suspended in a medium that is made in accordance with one embodiment of the present disclosure that may be released to restrict fluid flow.
- the present disclosure relates to devices and methods for controlling production of a hydrocarbon producing well.
- the present disclosure is susceptible to embodiments of different forms. There are shown in the drawings, and herein will be described in detail, specific embodiments of the present disclosure with the understanding that the present disclosure is to be considered an exemplification of the principles of the disclosure, and is not intended to limit the disclosure to that illustrated and described herein. Further, while embodiments may be described as having one or more features or a combination of two or more features, such a feature or a combination of features should not be construed as essential unless expressly stated as essential.
- FIG. 1 there is shown an exemplary wellbore 10 that has been drilled through the earth 12 and into a pair of formations 14 , 16 from which it is desired to produce hydrocarbons.
- the wellbore 10 is cased by metal casing, as is known in the art, and a number of perforations 18 penetrate and extend into the formations 14 , 16 so that production fluids may flow from the formations 14 , 16 into the wellbore 10 .
- the wellbore 10 has a deviated, or substantially horizontal leg 19 .
- the wellbore 10 has a late-stage production assembly, generally indicated at 20 , disposed therein by a tubing string 22 that extends downwardly from a wellhead 24 at the surface 26 of the wellbore 10 .
- the production assembly 20 defines an internal axial flowbore 28 along its length.
- An annulus 30 is defined between the production assembly 20 and the wellbore casing.
- the production assembly 20 has a deviated, generally horizontal portion 32 that extends along the deviated leg 19 of the wellbore 10 .
- Production devices 34 are positioned at selected points along the production assembly 20 .
- each production device 34 is isolated within the wellbore 10 by a pair of packer devices 36 . Although only two production devices 34 are shown in FIG. 1 , there may, in fact, be a large number of such production devices arranged in serial fashion along the horizontal portion 32 .
- Each production device 34 features a production control device 38 that is used to govern one or more aspects of a flow of one or more fluids into the production assembly 20 .
- the term “fluid” or “fluids” includes liquids, gases, hydrocarbons, multi-phase fluids, mixtures of two of more fluids, water, brine, engineered fluids such as drilling mud, fluids injected from the surface such as water, and naturally occurring fluids such as oil and gas. Additionally, references to water should be construed to also include water-based fluids; e.g., brine or salt water.
- the production control device 38 may have a number of alternative constructions that ensure selective operation and controlled fluid flow therethrough.
- FIG. 2 illustrates an exemplary open hole wellbore arrangement 11 wherein the production devices of the present disclosure may be used.
- Construction and operation of the open hole wellbore 11 is similar in most respects to the wellbore 10 described previously.
- the wellbore arrangement 11 has an uncased borehole that is directly open to the formations 14 , 16 .
- Production fluids therefore, flow directly from the formations 14 , 16 , and into the annulus 30 that is defined between the production assembly 21 and the wall of the wellbore 11 .
- There are no perforations, and open hole packers 36 may be used to isolate the production control devices 38 .
- the nature of the production control device is such that the fluid flow is directed from the formation 16 directly to the nearest production device 34 , hence resulting in a balanced flow. In some instances, packers maybe omitted from the open hole completion.
- a production control device 100 for controlling the flow of fluids from a reservoir into a production string via one or more passages 122 .
- This flow control can be a function of one or more characteristics or parameters of the formation fluid, including water content, fluid velocity, gas content, etc.
- the control devices 100 can be distributed along a section of a production well to provide fluid control at multiple locations. This can be advantageous, for example, to equalize production flow of oil in situations wherein a greater flow rate is expected at a “heel” of a horizontal well than at the “toe” of the horizontal well.
- a well owner can increase the likelihood that an oil bearing reservoir will drain efficiently. Exemplary production control devices are discussed herein below.
- the production control device 100 includes a particulate control device 110 for reducing the amount and size of particulates entrained in the fluids, a flow control device 120 that controls overall drainage rate from the formation, and an in-flow control device 130 that controls in-flow area based upon the composition of a fluid in the vicinity of the in-flow control device 130 .
- the particulate control device 110 can include known devices such as sand screens and associated gravel packs and the flow control device 120 can utilize devices employing tortuous fluid paths designed to control inflow rate by created pressure drops.
- An exemplary in-flow control device 130 may be configured to control fluid flow into a flow bore 102 based upon one or more characteristics (e.g., water content) of the in-flowing fluid.
- the in-flow control device 130 is actuated by one or more element 132 that is partially or completed suspended in a medium 134 that disintegrates upon exposure to one or more specified fluids in the vicinity of the in-flow control device 130 .
- the elements 132 may, depending on the application, be a solid, a liquid, a slurry, a particle, particles or an engineered component.
- the medium 134 is a body of one or more materials that have a relatively fast rate of disintegration.
- Exemplary types of disintegration include, but are not limited to, oxidizing, dissolving, melting, fracturing, and other such mechanisms that cause a structure to lose integrity and fail or collapse.
- the medium 134 may be formed of a material, such as aluminum, that oxidizes, or corrodes, when exposed to water.
- the elements 132 may be calibrated to disintegrate. By calibrate or calibrated, it is meant that one or more characteristics relating to the capacity of the element to disintegrate is intentionally tune or adjusted to occur in a predetermined manner or in response to a predetermined condition or set of conditions.
- the “elements” as used herein are not intended to limit the present disclosure as requiring a plurality of discrete elements. Rather, the term “elements” is used merely for the sake of convenience. Embodiments of the present disclosure may utilize one or more “elements” as described herein.
- the elements 132 suspended in the medium 134 may be used in numerous arrangements to partially or complete restrict flow through the in-flow control device 130 .
- the medium 134 may dissolve or otherwise disintegrate when a threshold value of water concentration, or water cut, in the fluid flowing across the in-flow control device 130 exceeds a preset value. Once the disintegration sufficiently degrades the medium 134 , the elements 132 are released to perform any number of functions. Illustrative functions for the elements 132 are described below.
- the in-flow control device 150 may include a housing 152 and a flow restriction element 154 that is positioned on a wellbore “low side.”
- the flow restriction element 154 may move between an open position ( FIG. 4A ) and a closed position ( FIG. 4B ). In the open position as shown, fluid flows from an annular passage 103 into the flow bore 102 . In the closed position, the flow restriction element 154 partially or completely blocks the passages (not shown) to thereby restrict flow into the flow bore 102 .
- the flow restriction element 154 may be formed to have an overall density greater than that of oil and of water. Thus, the flow restriction element 154 “sinks” to the open position due to gravity when immersed in either water or oil.
- the flow restriction element 154 may rotate, as shown, between the open and closed positions but may also utilize other modes of movement, e.g., translation.
- a relatively dense material 160 may be suspended in a medium 162 that disintegrates when exposed to a predetermined amount of water in a fluid in the in-flow control device 150 .
- the relatively dense material 160 may be positioned in the housing 152 or elsewhere upstream of the flow restriction element 154 .
- the relatively dense material 160 may be a fluid or slurry that has a density greater than the overall density of the flow restriction element 154 .
- the fluid flowing through the in-flow control device 150 may initially not have sufficient water content to degrade the medium 162 .
- the fluid flowing through the in-flow control device 150 may be mostly oil. Because the overall density of the flow restriction element 154 is greater than that of oil, the flow restriction element 154 “sinks” to an open position to allow the fluid to enter the flow bore 102 . Moreover, the relatively dense material 160 remains suspended in the medium 162 . If the in-flow control device 150 encounters an increase in water concentration in the flowing fluid sufficient to disintegrate the medium 162 , then the relatively dense material 152 will be released into the housing 152 and collect around the flow restriction element 154 .
- the effective density of the flow restriction element 154 is less than the density of the relatively dense material 160 .
- the relatively dense material 152 collects around the flow restriction element 154 , the flow restriction element 154 will “float” to the closed position and fluid flow into the flow bore 102 will be restricted.
- the in-flow control device 170 may include a housing 174 and a permeable element 176 that is positioned along the flow path 172 .
- the permeable element 176 includes openings and/or passages (not shown) that do not substantially restrict the flow of fluid along the flow path 172 .
- the permeable element 176 may be a filter-type element, a membrane, or a screen. As shown by the arrows 178 , fluid passes through the permeable element 176 with little obstruction.
- a quantity of particles 180 may be entrained in a medium 182 that disintegrates when exposed to a predetermined amount of water in a fluid in the in-flow control device 170 .
- the particles 180 may be positioned in the housing 174 or elsewhere upstream of the permeable element 176 .
- the particles 180 may be a proppant, a powder, particulates, granular matter, pellets or other material having a shape or size that prevents the material from passing through the openings and/or passages of the permeable element 176 .
- Suitable materials for the particles include, but are not limited to, metals, plastics, composites, ceramics, polymers, gels, etc.
- the fluid flowing through the in-flow control device 170 may initially not have sufficient water content to degrade the medium 182 .
- the fluid flowing through the in-flow control device 170 may be mostly oil.
- the oil flows substantially freely through the permeable element 176 .
- the particles 180 remain suspended in the medium 182 . If the in-flow control device 170 encounters an increase in water concentration in the flowing fluid sufficient to disintegrate the medium 182 , then the particles 180 will be released into the housing 174 along the flow path 172 .
- the shape and/or size of the particles 180 cannot pass through the permeable element 176 .
- the particles form a layer on the permeable element 176 that at least partially occludes the passages and/or openings in the permeable element 176 . As shown by the arrows 184 , less fluid passes through the permeable element 176 and through the flow path 172 .
- the in-flow control device 190 may include a housing 194 and orifices 196 that communicate with a flow bore 102 .
- plugging members 200 may be fixed in a medium 202 that disintegrates when exposed to a predetermined amount of water in a fluid in the in-flow control device 190 .
- the plugging members 200 may be positioned in the housing 194 or elsewhere upstream of the orifices 196 .
- the plugging members 200 may balls members, pellets, granular elements other members have a shape or size that prevents the members from passing through the orifices 196 .
- Suitable materials for the particles include, but are not limited to, metals, plastics, composites, ceramics, polymers.
- the fluid flowing through the in-flow control device 190 may initially not have sufficient water content to degrade the medium 192 .
- the fluid flowing through the in-flow control device 190 may be mostly oil.
- the oil flows substantially freely through the orifices 196 .
- the plugging members 200 remain suspended in the medium 192 . If the in-flow control device 190 encounters an increase in water concentration in the flowing fluid sufficient to disintegrate the medium 192 , then the plugging members 200 will be released into the housing 194 .
- the plugging members 200 cannot pass through the orifices 196 .
- a plugging member 200 occludes or substantially block fluid flow across the orifice 196 within which it is seated.
- the permeable element 176 is shown positioned along a flow path upstream of orifices 122 ( FIG. 3 ).
- the permeable membrane 176 may be positioned in the same manner as the orifices 196 of FIGS. 6A-B ; e.g., at the orifices 122 .
- the released particles 180 may form a horizontal bed that blocks flow instead of the vertical layer shown in FIG. 5B .
- the above-described elements may be positioned at other locations, such as the particulate control device 110 ( FIG. 3 ) or the flow control device 120 ( FIG. 3 ) or even external to the production control device 100 ( FIG. 3 ).
- the elements suspended within the disintegrating medium may be formed of material that disintegrates when exposed to oil.
- an oil-soluble plugging element may be encapsulated in a water soluble media.
- the oil-soluble element may disintegrate to restore flow through that orifice.
- a fluid supplied from the surface may be used to displace or disintegrate an element plugging an orifice, permeable membrane or actuating a flow restriction element.
Abstract
Methods and devices for controlling fluid flow into a wellbore tubular includes an in-flow control device, an element co-acting with the in-flow control device, and a disintegrating medium at least partially surrounding the element. The medium may be configured to release the element upon disintegration of the medium. The disintegrating medium may be configured to disintegrate when exposed to a selected fluid. The element may be configured to at least partially restrict flow across a flow path associated with the in-flow control device when released. The flow path may convey the fluid from the formation to a flow bore of the wellbore tubular and the element may be positioned along the flow path. The element may be: a liquid, a solid, a particle and/or particles. The selected fluid may be water, a hydrocarbon, an engineered fluid, and/or a naturally occurring fluid.
Description
- 1. Field of the Invention
- The invention relates generally to systems and methods for selective control of fluid flow into a wellbore.
- 2. Description of the Related Art
- Hydrocarbons such as oil and gas are recovered from a subterranean formation using a wellbore drilled into the formation. Such wells are typically completed by placing a casing along the wellbore length and perforating the casing adjacent each such production zone to extract the formation fluids (such as hydrocarbons) into the wellbore. These production zones are sometimes separated from each other by installing a packer between the production zones. Fluid from each production zone entering the wellbore is drawn into a tubing that runs to the surface. It is desirable to have substantially even drainage along the production zone. Uneven drainage may result in undesirable conditions such as an invasive gas cone or water cone. In the instance of an oil-producing well, for example, a gas cone may cause an inflow of gas into the wellbore that could significantly reduce oil production. In like fashion, a water cone may cause an inflow of water into the oil production flow that reduces the amount and quality of the produced oil. Accordingly, it is desired to provide even drainage across a production zone and/or the ability to selectively close off or reduce inflow within production zones experiencing an undesirable influx of water and/or gas.
- The present disclosure addresses these and other needs of the prior art.
- In aspects, the present disclosure provides an apparatus for controlling flow of a fluid into a wellbore tubular. The apparatus may include an in-flow control device controlling the flow of the fluid, an element co-acting with the in-flow control device, and a disintegrating medium at least partially surrounding the element. In arrangements, the medium may be configured to release the element upon disintegration of the medium. The disintegrating medium may be configured to disintegrate when exposed to a selected fluid. The element or elements, when released, may at least partially restrict flow across a flow path that conveys the fluid from the formation to a flow bore of the wellbore tubular. The element may be positioned along the flow path or elsewhere. In embodiments, the element may be: a liquid, a solid, a particle and/or particles. In embodiments, the selected fluid may be water, a hydrocarbon, an engineered fluid, and/or a naturally occurring fluid.
- In aspects, the present disclosure provides a method for controlling a flow of fluid from a subterranean formation. In embodiments, the method may include suspending an element in a medium that disintegrates when exposed to a selected fluid; positioning the element in a wellbore; and restricting a fluid flow across a flow path by releasing the element. The method may include releasing the element into the flow path when the medium disintegrates.
- In aspects, the present disclosure provides a system for controlling flow of a fluid in a well. The system may include a wellbore tubular positioned in the well; an in-flow control device positioned along the wellbore tubular; an element co-acting with the in-flow control device; and a disintegrating medium at least partially surrounding the element, the disintegrating medium being calibrated to disintegrate when exposed to a selected fluid.
- It should be understood that examples of the more important features of the disclosure have been summarized rather broadly in order that detailed description thereof that follows may be better understood, and in order that the contributions to the art may be appreciated. There are, of course, additional features of the disclosure that will be described hereinafter and which will form the subject of the claims appended hereto.
- The advantages and further aspects of the disclosure will be readily appreciated by those of ordinary skill in the art as the same becomes better understood by reference to the following detailed description when considered in conjunction with the accompanying drawings in which like reference characters designate like or similar elements throughout the several figures of the drawing and wherein:
-
FIG. 1 is a schematic elevation view of an exemplary multi-zonal wellbore and production assembly which incorporates an inflow control system in accordance with one embodiment of the present disclosure; -
FIG. 2 is a schematic elevation view of an exemplary open hole production assembly which incorporates an inflow control system in accordance with one embodiment of the present disclosure; -
FIG. 3 is a schematic cross-sectional view of an exemplary production control device made in accordance with one embodiment of the present disclosure; -
FIGS. 4A-4B schematically illustrate a material suspended in a medium in accordance with one embodiment of the present disclosure that may be released to actuate a flow restriction element; -
FIGS. 5A-5B schematically illustrate a material suspended in a medium that is made in accordance with one embodiment of the present disclosure that may be released to restrict fluid flow; and -
FIGS. 6A-6B schematically illustrate occlusion elements suspended in a medium that is made in accordance with one embodiment of the present disclosure that may be released to restrict fluid flow. - The present disclosure relates to devices and methods for controlling production of a hydrocarbon producing well. The present disclosure is susceptible to embodiments of different forms. There are shown in the drawings, and herein will be described in detail, specific embodiments of the present disclosure with the understanding that the present disclosure is to be considered an exemplification of the principles of the disclosure, and is not intended to limit the disclosure to that illustrated and described herein. Further, while embodiments may be described as having one or more features or a combination of two or more features, such a feature or a combination of features should not be construed as essential unless expressly stated as essential.
- Referring initially to
FIG. 1 , there is shown anexemplary wellbore 10 that has been drilled through theearth 12 and into a pair offormations wellbore 10 is cased by metal casing, as is known in the art, and a number ofperforations 18 penetrate and extend into theformations formations wellbore 10. Thewellbore 10 has a deviated, or substantiallyhorizontal leg 19. Thewellbore 10 has a late-stage production assembly, generally indicated at 20, disposed therein by atubing string 22 that extends downwardly from awellhead 24 at thesurface 26 of thewellbore 10. Theproduction assembly 20 defines an internalaxial flowbore 28 along its length. Anannulus 30 is defined between theproduction assembly 20 and the wellbore casing. Theproduction assembly 20 has a deviated, generallyhorizontal portion 32 that extends along the deviatedleg 19 of thewellbore 10.Production devices 34 are positioned at selected points along theproduction assembly 20. Optionally, eachproduction device 34 is isolated within thewellbore 10 by a pair ofpacker devices 36. Although only twoproduction devices 34 are shown inFIG. 1 , there may, in fact, be a large number of such production devices arranged in serial fashion along thehorizontal portion 32. - Each
production device 34 features aproduction control device 38 that is used to govern one or more aspects of a flow of one or more fluids into theproduction assembly 20. As used herein, the term “fluid” or “fluids” includes liquids, gases, hydrocarbons, multi-phase fluids, mixtures of two of more fluids, water, brine, engineered fluids such as drilling mud, fluids injected from the surface such as water, and naturally occurring fluids such as oil and gas. Additionally, references to water should be construed to also include water-based fluids; e.g., brine or salt water. In accordance with embodiments of the present disclosure, theproduction control device 38 may have a number of alternative constructions that ensure selective operation and controlled fluid flow therethrough. -
FIG. 2 illustrates an exemplary open holewellbore arrangement 11 wherein the production devices of the present disclosure may be used. Construction and operation of theopen hole wellbore 11 is similar in most respects to thewellbore 10 described previously. However, thewellbore arrangement 11 has an uncased borehole that is directly open to theformations formations annulus 30 that is defined between theproduction assembly 21 and the wall of thewellbore 11. There are no perforations, andopen hole packers 36 may be used to isolate theproduction control devices 38. The nature of the production control device is such that the fluid flow is directed from theformation 16 directly to thenearest production device 34, hence resulting in a balanced flow. In some instances, packers maybe omitted from the open hole completion. - Referring now to
FIG. 3 , there is shown one embodiment of aproduction control device 100 for controlling the flow of fluids from a reservoir into a production string via one ormore passages 122. This flow control can be a function of one or more characteristics or parameters of the formation fluid, including water content, fluid velocity, gas content, etc. Furthermore, thecontrol devices 100 can be distributed along a section of a production well to provide fluid control at multiple locations. This can be advantageous, for example, to equalize production flow of oil in situations wherein a greater flow rate is expected at a “heel” of a horizontal well than at the “toe” of the horizontal well. By appropriately configuring theproduction control devices 100, such as by pressure equalization or by restricting inflow of gas or water, a well owner can increase the likelihood that an oil bearing reservoir will drain efficiently. Exemplary production control devices are discussed herein below. - In one embodiment, the
production control device 100 includes aparticulate control device 110 for reducing the amount and size of particulates entrained in the fluids, aflow control device 120 that controls overall drainage rate from the formation, and an in-flow control device 130 that controls in-flow area based upon the composition of a fluid in the vicinity of the in-flow control device 130. Theparticulate control device 110 can include known devices such as sand screens and associated gravel packs and theflow control device 120 can utilize devices employing tortuous fluid paths designed to control inflow rate by created pressure drops. - An exemplary in-
flow control device 130 may be configured to control fluid flow into aflow bore 102 based upon one or more characteristics (e.g., water content) of the in-flowing fluid. In embodiments, the in-flow control device 130 is actuated by one ormore element 132 that is partially or completed suspended in a medium 134 that disintegrates upon exposure to one or more specified fluids in the vicinity of the in-flow control device 130. Theelements 132 may, depending on the application, be a solid, a liquid, a slurry, a particle, particles or an engineered component. The medium 134 is a body of one or more materials that have a relatively fast rate of disintegration. Exemplary types of disintegration include, but are not limited to, oxidizing, dissolving, melting, fracturing, and other such mechanisms that cause a structure to lose integrity and fail or collapse. The medium 134 may be formed of a material, such as aluminum, that oxidizes, or corrodes, when exposed to water. In embodiments, theelements 132 may be calibrated to disintegrate. By calibrate or calibrated, it is meant that one or more characteristics relating to the capacity of the element to disintegrate is intentionally tune or adjusted to occur in a predetermined manner or in response to a predetermined condition or set of conditions. For convenience, the “elements” as used herein are not intended to limit the present disclosure as requiring a plurality of discrete elements. Rather, the term “elements” is used merely for the sake of convenience. Embodiments of the present disclosure may utilize one or more “elements” as described herein. - As will be appreciated, the
elements 132 suspended in the medium 134 may be used in numerous arrangements to partially or complete restrict flow through the in-flow control device 130. In embodiments, the medium 134 may dissolve or otherwise disintegrate when a threshold value of water concentration, or water cut, in the fluid flowing across the in-flow control device 130 exceeds a preset value. Once the disintegration sufficiently degrades the medium 134, theelements 132 are released to perform any number of functions. Illustrative functions for theelements 132 are described below. - Referring now to
FIGS. 4A-B , there is schematically shown an in-flow control device 150 that restricts fluid flow into aflow bore 102 when the amount of water in the fluid exceeds a predetermined value. The in-flow control device 150 may include ahousing 152 and aflow restriction element 154 that is positioned on a wellbore “low side.” Theflow restriction element 154 may move between an open position (FIG. 4A ) and a closed position (FIG. 4B ). In the open position as shown, fluid flows from anannular passage 103 into the flow bore 102. In the closed position, theflow restriction element 154 partially or completely blocks the passages (not shown) to thereby restrict flow into the flow bore 102. Theflow restriction element 154 may be formed to have an overall density greater than that of oil and of water. Thus, theflow restriction element 154 “sinks” to the open position due to gravity when immersed in either water or oil. Theflow restriction element 154 may rotate, as shown, between the open and closed positions but may also utilize other modes of movement, e.g., translation. To move theflow restriction element 154 to a closed position, a relativelydense material 160 may be suspended in a medium 162 that disintegrates when exposed to a predetermined amount of water in a fluid in the in-flow control device 150. The relativelydense material 160 may be positioned in thehousing 152 or elsewhere upstream of theflow restriction element 154. In one arrangement, the relativelydense material 160 may be a fluid or slurry that has a density greater than the overall density of theflow restriction element 154. - Referring now to
FIG. 4B , in an illustrative deployment, the fluid flowing through the in-flow control device 150 may initially not have sufficient water content to degrade the medium 162. For instance, the fluid flowing through the in-flow control device 150 may be mostly oil. Because the overall density of theflow restriction element 154 is greater than that of oil, theflow restriction element 154 “sinks” to an open position to allow the fluid to enter the flow bore 102. Moreover, the relativelydense material 160 remains suspended in the medium 162. If the in-flow control device 150 encounters an increase in water concentration in the flowing fluid sufficient to disintegrate the medium 162, then the relativelydense material 152 will be released into thehousing 152 and collect around theflow restriction element 154. As noted above, the effective density of theflow restriction element 154 is less than the density of the relativelydense material 160. Thus, as the relativelydense material 152 collects around theflow restriction element 154, theflow restriction element 154 will “float” to the closed position and fluid flow into the flow bore 102 will be restricted. - Referring now to
FIGS. 5A-B , there is schematically shown an in-flow control device 170 that selectively restricts fluid flow along aflow path 172 when the amount of water in the fluid exceeds a predetermined value. The in-flow control device 170 may include ahousing 174 and apermeable element 176 that is positioned along theflow path 172. Thepermeable element 176 includes openings and/or passages (not shown) that do not substantially restrict the flow of fluid along theflow path 172. In embodiments, thepermeable element 176 may be a filter-type element, a membrane, or a screen. As shown by thearrows 178, fluid passes through thepermeable element 176 with little obstruction. To restrict flow in theflow path 172, a quantity ofparticles 180 may be entrained in a medium 182 that disintegrates when exposed to a predetermined amount of water in a fluid in the in-flow control device 170. Theparticles 180 may be positioned in thehousing 174 or elsewhere upstream of thepermeable element 176. In embodiments, theparticles 180 may be a proppant, a powder, particulates, granular matter, pellets or other material having a shape or size that prevents the material from passing through the openings and/or passages of thepermeable element 176. Suitable materials for the particles include, but are not limited to, metals, plastics, composites, ceramics, polymers, gels, etc. - Referring now to
FIG. 5B , in an illustrative deployment, the fluid flowing through the in-flow control device 170 may initially not have sufficient water content to degrade the medium 182. For instance, the fluid flowing through the in-flow control device 170 may be mostly oil. Thus, the oil flows substantially freely through thepermeable element 176. Moreover, theparticles 180 remain suspended in the medium 182. If the in-flow control device 170 encounters an increase in water concentration in the flowing fluid sufficient to disintegrate the medium 182, then theparticles 180 will be released into thehousing 174 along theflow path 172. As noted above, the shape and/or size of theparticles 180 cannot pass through thepermeable element 176. Thus, the particles form a layer on thepermeable element 176 that at least partially occludes the passages and/or openings in thepermeable element 176. As shown by thearrows 184, less fluid passes through thepermeable element 176 and through theflow path 172. - Referring now to
FIGS. 6A-B , there is schematically shown an in-flow control device 190 that selectively restricts fluid flow along aflow path 192 when the amount of water in the fluid exceeds a predetermined value. The in-flow control device 190 may include ahousing 194 andorifices 196 that communicate with aflow bore 102. To restrict flow into the flow bore 102, pluggingmembers 200 may be fixed in a medium 202 that disintegrates when exposed to a predetermined amount of water in a fluid in the in-flow control device 190. The pluggingmembers 200 may be positioned in thehousing 194 or elsewhere upstream of theorifices 196. In embodiments, the pluggingmembers 200 may balls members, pellets, granular elements other members have a shape or size that prevents the members from passing through theorifices 196. Suitable materials for the particles include, but are not limited to, metals, plastics, composites, ceramics, polymers. In embodiments, there may be numericallymore orifices 196 than pluggingmembers 200 to ensure that some amount of flow may still occur through the in-flow control device 190 even after the pluggingmembers 200 are released; e.g., eight pluggingmembers 200 and tenorifices 196. - Referring now to
FIG. 6B , in an illustrative deployment, the fluid flowing through the in-flow control device 190 may initially not have sufficient water content to degrade the medium 192. For instance, the fluid flowing through the in-flow control device 190 may be mostly oil. Thus, the oil flows substantially freely through theorifices 196. Moreover, the pluggingmembers 200 remain suspended in the medium 192. If the in-flow control device 190 encounters an increase in water concentration in the flowing fluid sufficient to disintegrate the medium 192, then the pluggingmembers 200 will be released into thehousing 194. As noted above, due to their shape and/or size, the pluggingmembers 200 cannot pass through theorifices 196. Thus, a pluggingmember 200 occludes or substantially block fluid flow across theorifice 196 within which it is seated. - It should be understood that the above-described embodiments are merely illustrative of the arrangements wherein an element suspended in a media may be released to restrict flow from a formation into a production flow bore. For instance, in
FIG. 5A , thepermeable element 176 is shown positioned along a flow path upstream of orifices 122 (FIG. 3 ). In other embodiments, thepermeable membrane 176 may be positioned in the same manner as theorifices 196 ofFIGS. 6A-B ; e.g., at theorifices 122. Thus, the releasedparticles 180 may form a horizontal bed that blocks flow instead of the vertical layer shown inFIG. 5B . In other variants, the above-described elements may be positioned at other locations, such as the particulate control device 110 (FIG. 3 ) or the flow control device 120 (FIG. 3 ) or even external to the production control device 100 (FIG. 3 ). - Additionally, in certain embodiments, the elements suspended within the disintegrating medium may be formed of material that disintegrates when exposed to oil. Thus, for instance, an oil-soluble plugging element may be encapsulated in a water soluble media. In such an arrangement, if the flowing fluid were to return to substantially oil flow after the oil-plugging element has seated into an orifice, then the oil-soluble element may disintegrate to restore flow through that orifice. It should be appreciated that such an arrangement provides a reversible in-flow control mechanism. In other embodiments, a fluid supplied from the surface may be used to displace or disintegrate an element plugging an orifice, permeable membrane or actuating a flow restriction element.
- For the sake of clarity and brevity, descriptions of most threaded connections between tubular elements, elastomeric seals, such as o-rings, and other well-understood techniques are omitted in the above description. The foregoing description is directed to particular embodiments of the present disclosure for the purpose of illustration and explanation. It will be apparent, however, to one skilled in the art that many modifications and changes to the embodiment set forth above are possible without departing from the scope of the disclosure.
Claims (22)
1. A method for controlling a flow of fluid from a subterranean formation, comprising:
positioning a housing in a wellbore, the housing having a flow path formed therein;
suspending an element in a medium that disintegrates when exposed to a selected fluid;
positioning the element in housing; and
restricting a fluid flow across the flow path by releasing the element.
2. The method according to claim 1 wherein the selected fluid is water.
3. The method according to claim 1 further comprising releasing the element into the flow path when the medium disintegrates.
4. The method according to claim 1 further comprising configuring the flow path to convey fluid from the formation into a bore of a wellbore tubular; forming a passage in the housing and that communicates with the bore of the wellbore tubular; and at least partially blocking the passage with the element by releasing the element.
5. The method according to claim 1 further comprising forming the flow path to convey the fluid from the formation to a flow bore of a wellbore tubular; and reducing an amount of particles in the fluid entering the flow path by using a particulate control device.
6. The method according to claim 1 further comprising positioning the element along the flow path and maintaining the element substantially stationary in the flow path while the element is suspended in the medium.
7. The method according to claim 1 wherein the element is one of: (i) a liquid, (ii) a solid, (iii) a particle, and (iv) particles.
8. The method according to claim 1 wherein the selected fluid is one of: (i) water, (ii) a hydrocarbon, (iii) an engineered fluid, and (iv) a naturally occurring fluid.
9. An apparatus for controlling flow of a fluid into a wellbore tubular, comprising:
an in-flow control device having a housing;
an element positioned in the housing; and
a disintegrating medium at least partially surrounding the element, the disintegrating medium being configured to disintegrate when exposed to a selected fluid.
10. The apparatus according to claim 9 wherein the disintegrating medium disintegrates upon exposure to water in the fluid.
11. The apparatus according to claim 9 wherein the element is configured to at least partially restrict flow across a flow path associated with the in-flow control device.
12. The apparatus according to claim 9 wherein the medium is configured to release the element after the medium at least partially disintegrates.
13. The apparatus according to claim 9 further comprising a flow path to convey the fluid from the formation to a flow bore of the wellbore tubular.
14. The apparatus according to claim 13 wherein the element is positioned along the flow path.
15. The apparatus according to claim 9 wherein the element is one of: (i) a liquid, (ii) a solid, (iii) a particle, and (iv) particles.
16. The apparatus according to claim 9 wherein the selected fluid is one of: (i) water, (ii) a hydrocarbon, (iii) an engineered fluid, and (iv) a naturally occurring fluid.
17. A system for controlling flow of a fluid in a well, comprising:
a wellbore tubular positioned in the well;
an in-flow control device having a housing and positioned along the wellbore tubular;
an element positioned in the housing; and
a disintegrating medium at least partially surrounding the element, the disintegrating medium being calibrated to disintegrate when exposed to a selected fluid.
18. The system according to claim 17 wherein the disintegrating medium disintegrates upon exposure to water in the fluid.
19. The system according to claim 17 wherein the element is configured to at least partially restrict flow across a flow path associated with the in-flow control device.
20. The system according to claim 17 wherein the medium is configured to release the element upon disintegration of the medium.
21. A method for controlling a flow of fluid from a subterranean formation, comprising:
flowing a fluid from an annulus of a wellbore into a flow bore of a wellbore tubular;
reducing one of (i) a size and (ii) an amount of particles in the fluid flowing into the flow bore;
suspending in a flow path of the fluid an element in a medium that disintegrates when exposed to a selected fluid; and
restricting a fluid flow across the flow path by releasing the element when the flowing fluid includes the selected fluid.
22. The method according to claim 21 further comprising:
forming a passage along the flow path, the passage communicating with the flow bore of the wellbore tubular; and
at least partially blocking the passage with the released element.
Priority Applications (2)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US11/875,499 US20090101344A1 (en) | 2007-10-22 | 2007-10-22 | Water Dissolvable Released Material Used as Inflow Control Device |
PCT/US2008/080579 WO2009055354A2 (en) | 2007-10-22 | 2008-10-21 | Water dissolvable released material used as inflow control device |
Applications Claiming Priority (1)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US11/875,499 US20090101344A1 (en) | 2007-10-22 | 2007-10-22 | Water Dissolvable Released Material Used as Inflow Control Device |
Publications (1)
Publication Number | Publication Date |
---|---|
US20090101344A1 true US20090101344A1 (en) | 2009-04-23 |
Family
ID=40562291
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
US11/875,499 Abandoned US20090101344A1 (en) | 2007-10-22 | 2007-10-22 | Water Dissolvable Released Material Used as Inflow Control Device |
Country Status (2)
Country | Link |
---|---|
US (1) | US20090101344A1 (en) |
WO (1) | WO2009055354A2 (en) |
Cited By (17)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US20100300684A1 (en) * | 2009-05-29 | 2010-12-02 | Schlumberger Technology Corporation | Continuous downhole scale monitoring and inhibition system |
US20110198097A1 (en) * | 2010-02-12 | 2011-08-18 | Schlumberger Technology Corporation | Autonomous inflow control device and methods for using same |
EP2383430A3 (en) * | 2010-04-29 | 2013-02-20 | Halliburton Energy Services, Inc. | Method and apparatus for controlling fluid flow using moveable flow diverter assembly |
US8657017B2 (en) | 2009-08-18 | 2014-02-25 | Halliburton Energy Services, Inc. | Method and apparatus for autonomous downhole fluid selection with pathway dependent resistance system |
US8991506B2 (en) | 2011-10-31 | 2015-03-31 | Halliburton Energy Services, Inc. | Autonomous fluid control device having a movable valve plate for downhole fluid selection |
US9051819B2 (en) | 2011-08-22 | 2015-06-09 | Baker Hughes Incorporated | Method and apparatus for selectively controlling fluid flow |
US9127526B2 (en) | 2012-12-03 | 2015-09-08 | Halliburton Energy Services, Inc. | Fast pressure protection system and method |
US9200502B2 (en) | 2011-06-22 | 2015-12-01 | Schlumberger Technology Corporation | Well-based fluid communication control assembly |
EP2697473A4 (en) * | 2011-04-11 | 2015-12-16 | Halliburton Energy Services Inc | Selectively variable flow restrictor for use in a subterranean well |
US9260952B2 (en) | 2009-08-18 | 2016-02-16 | Halliburton Energy Services, Inc. | Method and apparatus for controlling fluid flow in an autonomous valve using a sticky switch |
US9291032B2 (en) | 2011-10-31 | 2016-03-22 | Halliburton Energy Services, Inc. | Autonomous fluid control device having a reciprocating valve for downhole fluid selection |
US9404349B2 (en) | 2012-10-22 | 2016-08-02 | Halliburton Energy Services, Inc. | Autonomous fluid control system having a fluid diode |
WO2016133846A1 (en) * | 2015-02-16 | 2016-08-25 | Baker Hughes Incorporated | Disintegrating plugs to delay production through inflow control devices |
US9695654B2 (en) | 2012-12-03 | 2017-07-04 | Halliburton Energy Services, Inc. | Wellhead flowback control system and method |
WO2018135950A1 (en) * | 2017-01-17 | 2018-07-26 | Scale Protection As | Autonomous water flow shutoff device |
US10890067B2 (en) * | 2019-04-11 | 2021-01-12 | Saudi Arabian Oil Company | Method to use a buoyant body to measure two-phase flow in horizontal wells |
CN114458284A (en) * | 2020-10-30 | 2022-05-10 | 中国石油天然气股份有限公司 | Release device, screen pipe column and production section testing method |
Families Citing this family (9)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
WO2015127177A1 (en) | 2014-02-21 | 2015-08-27 | Terves, Inc. | Manufacture of controlled rate dissolving materials |
US10689740B2 (en) | 2014-04-18 | 2020-06-23 | Terves, LLCq | Galvanically-active in situ formed particles for controlled rate dissolving tools |
US11167343B2 (en) | 2014-02-21 | 2021-11-09 | Terves, Llc | Galvanically-active in situ formed particles for controlled rate dissolving tools |
US20170268088A1 (en) | 2014-02-21 | 2017-09-21 | Terves Inc. | High Conductivity Magnesium Alloy |
US10150713B2 (en) | 2014-02-21 | 2018-12-11 | Terves, Inc. | Fluid activated disintegrating metal system |
US10865465B2 (en) | 2017-07-27 | 2020-12-15 | Terves, Llc | Degradable metal matrix composite |
WO2015161171A1 (en) | 2014-04-18 | 2015-10-22 | Terves Inc. | Galvanically-active in situ formed particles for controlled rate dissolving tools |
BR112017000770B1 (en) | 2014-08-28 | 2022-09-06 | Halliburton Energy Services, Inc | BOTTOM TOOL, METHOD, AND SYSTEM FOR USE OF A BOTTOM TOOL |
RO133624A2 (en) | 2016-02-02 | 2019-09-30 | Halliburton Energy Services Inc. | Galvanically degradable downhole tools containing doped aluminium alloys |
Citations (95)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US1915867A (en) * | 1931-05-01 | 1933-06-27 | Edward R Penick | Choker |
US2119563A (en) * | 1937-03-02 | 1938-06-07 | George M Wells | Method of and means for flowing oil wells |
US2942668A (en) * | 1957-11-19 | 1960-06-28 | Union Oil Co | Well plugging, packing, and/or testing tool |
US2945541A (en) * | 1955-10-17 | 1960-07-19 | Union Oil Co | Well packer |
US3326291A (en) * | 1964-11-12 | 1967-06-20 | Zandmer Solis Myron | Duct-forming devices |
US3876471A (en) * | 1973-09-12 | 1975-04-08 | Sun Oil Co Delaware | Borehole electrolytic power supply |
US3975651A (en) * | 1975-03-27 | 1976-08-17 | Norman David Griffiths | Method and means of generating electrical energy |
US4153757A (en) * | 1976-03-01 | 1979-05-08 | Clark Iii William T | Method and apparatus for generating electricity |
US4186100A (en) * | 1976-12-13 | 1980-01-29 | Mott Lambert H | Inertial filter of the porous metal type |
US4187909A (en) * | 1977-11-16 | 1980-02-12 | Exxon Production Research Company | Method and apparatus for placing buoyant ball sealers |
US4248302A (en) * | 1979-04-26 | 1981-02-03 | Otis Engineering Corporation | Method and apparatus for recovering viscous petroleum from tar sand |
US4250907A (en) * | 1978-10-09 | 1981-02-17 | Struckman Edmund E | Float valve assembly |
US4257650A (en) * | 1978-09-07 | 1981-03-24 | Barber Heavy Oil Process, Inc. | Method for recovering subsurface earth substances |
US4294313A (en) * | 1973-08-01 | 1981-10-13 | Otis Engineering Corporation | Kickover tool |
US4434849A (en) * | 1978-09-07 | 1984-03-06 | Heavy Oil Process, Inc. | Method and apparatus for recovering high viscosity oils |
US4564996A (en) * | 1981-02-03 | 1986-01-21 | Thomas Weresch | Apparatus for working on leads of electronic components |
US4572295A (en) * | 1984-08-13 | 1986-02-25 | Exotek, Inc. | Method of selective reduction of the water permeability of subterranean formations |
US4614303A (en) * | 1984-06-28 | 1986-09-30 | Moseley Jr Charles D | Water saving shower head |
US4821800A (en) * | 1986-12-10 | 1989-04-18 | Sherritt Gordon Mines Limited | Filtering media for controlling the flow of sand during oil well operations |
US4856590A (en) * | 1986-11-28 | 1989-08-15 | Mike Caillier | Process for washing through filter media in a production zone with a pre-packed screen and coil tubing |
US4917183A (en) * | 1988-10-05 | 1990-04-17 | Baker Hughes Incorporated | Gravel pack screen having retention mesh support and fluid permeable particulate solids |
US4944349A (en) * | 1989-02-27 | 1990-07-31 | Von Gonten Jr William D | Combination downhole tubing circulating valve and fluid unloader and method |
US5004049A (en) * | 1990-01-25 | 1991-04-02 | Otis Engineering Corporation | Low profile dual screen prepack |
US5016710A (en) * | 1986-06-26 | 1991-05-21 | Institut Francais Du Petrole | Method of assisted production of an effluent to be produced contained in a geological formation |
US5132903A (en) * | 1990-06-19 | 1992-07-21 | Halliburton Logging Services, Inc. | Dielectric measuring apparatus for determining oil and water mixtures in a well borehole |
US5156811A (en) * | 1990-11-07 | 1992-10-20 | Continental Laboratory Products, Inc. | Pipette device |
US5339895A (en) * | 1993-03-22 | 1994-08-23 | Halliburton Company | Sintered spherical plastic bead prepack screen aggregate |
US5377750A (en) * | 1992-07-29 | 1995-01-03 | Halliburton Company | Sand screen completion |
US5381864A (en) * | 1993-11-12 | 1995-01-17 | Halliburton Company | Well treating methods using particulate blends |
US5431346A (en) * | 1993-07-20 | 1995-07-11 | Sinaisky; Nickoli | Nozzle including a venturi tube creating external cavitation collapse for atomization |
US5439966A (en) * | 1984-07-12 | 1995-08-08 | National Research Development Corporation | Polyethylene oxide temperature - or fluid-sensitive shape memory device |
US5551513A (en) * | 1995-05-12 | 1996-09-03 | Texaco Inc. | Prepacked screen |
US5896928A (en) * | 1996-07-01 | 1999-04-27 | Baker Hughes Incorporated | Flow restriction device for use in producing wells |
US6098020A (en) * | 1997-04-09 | 2000-08-01 | Shell Oil Company | Downhole monitoring method and device |
US6119780A (en) * | 1997-12-11 | 2000-09-19 | Camco International, Inc. | Wellbore fluid recovery system and method |
US6228812B1 (en) * | 1998-12-10 | 2001-05-08 | Bj Services Company | Compositions and methods for selective modification of subterranean formation permeability |
US6253847B1 (en) * | 1998-08-13 | 2001-07-03 | Schlumberger Technology Corporation | Downhole power generation |
US6338363B1 (en) * | 1997-11-24 | 2002-01-15 | Dayco Products, Inc. | Energy attenuation device for a conduit conveying liquid under pressure, system incorporating same, and method of attenuating energy in a conduit |
US6372678B1 (en) * | 2000-09-28 | 2002-04-16 | Fairmount Minerals, Ltd | Proppant composition for gas and oil well fracturing |
US6419021B1 (en) * | 1997-09-05 | 2002-07-16 | Schlumberger Technology Corporation | Deviated borehole drilling assembly |
US6581681B1 (en) * | 2000-06-21 | 2003-06-24 | Weatherford/Lamb, Inc. | Bridge plug for use in a wellbore |
US6581682B1 (en) * | 1999-09-30 | 2003-06-24 | Solinst Canada Limited | Expandable borehole packer |
US6632527B1 (en) * | 1998-07-22 | 2003-10-14 | Borden Chemical, Inc. | Composite proppant, composite filtration media and methods for making and using same |
US6635732B2 (en) * | 1999-04-12 | 2003-10-21 | Surgidev Corporation | Water plasticized high refractive index polymer for ophthalmic applications |
US6672385B2 (en) * | 2000-07-21 | 2004-01-06 | Sinvent As | Combined liner and matrix system |
US6692766B1 (en) * | 1994-06-15 | 2004-02-17 | Yissum Research Development Company Of The Hebrew University Of Jerusalem | Controlled release oral drug delivery system |
US20040035578A1 (en) * | 2002-08-26 | 2004-02-26 | Ross Colby M. | Fluid flow control device and method for use of same |
US6699611B2 (en) * | 2001-05-29 | 2004-03-02 | Motorola, Inc. | Fuel cell having a thermo-responsive polymer incorporated therein |
US6699503B1 (en) * | 1992-09-18 | 2004-03-02 | Yamanuchi Pharmaceutical Co., Ltd. | Hydrogel-forming sustained-release preparation |
US20040052689A1 (en) * | 1999-08-17 | 2004-03-18 | Porex Technologies Corporation | Self-sealing materials and devices comprising same |
US20040194971A1 (en) * | 2001-01-26 | 2004-10-07 | Neil Thomson | Device and method to seal boreholes |
US6840321B2 (en) * | 2002-09-24 | 2005-01-11 | Halliburton Energy Services, Inc. | Multilateral injection/production/storage completion system |
US6857476B2 (en) * | 2003-01-15 | 2005-02-22 | Halliburton Energy Services, Inc. | Sand control screen assembly having an internal seal element and treatment method using the same |
US6863126B2 (en) * | 2002-09-24 | 2005-03-08 | Halliburton Energy Services, Inc. | Alternate path multilayer production/injection |
US20050126776A1 (en) * | 2003-12-10 | 2005-06-16 | Russell Thane G. | Wellbore screen |
US20050171248A1 (en) * | 2004-02-02 | 2005-08-04 | Yanmei Li | Hydrogel for use in downhole seal applications |
US20050178705A1 (en) * | 2004-02-13 | 2005-08-18 | Broyles Norman S. | Water treatment cartridge shutoff |
US6938698B2 (en) * | 2002-11-18 | 2005-09-06 | Baker Hughes Incorporated | Shear activated inflation fluid system for inflatable packers |
US20050199298A1 (en) * | 2004-03-10 | 2005-09-15 | Fisher Controls International, Llc | Contiguously formed valve cage with a multidirectional fluid path |
US20050207279A1 (en) * | 2003-06-13 | 2005-09-22 | Baker Hughes Incorporated | Apparatus and methods for self-powered communication and sensor network |
US6951252B2 (en) * | 2002-09-24 | 2005-10-04 | Halliburton Energy Services, Inc. | Surface controlled subsurface lateral branch safety valve |
US20060042798A1 (en) * | 2004-08-30 | 2006-03-02 | Badalamenti Anthony M | Casing shoes and methods of reverse-circulation cementing of casing |
US20060048942A1 (en) * | 2002-08-26 | 2006-03-09 | Terje Moen | Flow control device for an injection pipe string |
US20060048936A1 (en) * | 2004-09-07 | 2006-03-09 | Fripp Michael L | Shape memory alloy for erosion control of downhole tools |
US7011076B1 (en) * | 2004-09-24 | 2006-03-14 | Siemens Vdo Automotive Inc. | Bipolar valve having permanent magnet |
US20060076150A1 (en) * | 2004-07-30 | 2006-04-13 | Baker Hughes Incorporated | Inflow control device with passive shut-off feature |
US20060086498A1 (en) * | 2004-10-21 | 2006-04-27 | Schlumberger Technology Corporation | Harvesting Vibration for Downhole Power Generation |
US20060108114A1 (en) * | 2001-12-18 | 2006-05-25 | Johnson Michael H | Drilling method for maintaining productivity while eliminating perforating and gravel packing |
US20060118296A1 (en) * | 2001-03-20 | 2006-06-08 | Arthur Dybevik | Well device for throttle regulation of inflowing fluids |
US7084094B2 (en) * | 1999-12-29 | 2006-08-01 | Tr Oil Services Limited | Process for altering the relative permeability if a hydrocarbon-bearing formation |
US20060175065A1 (en) * | 2004-12-21 | 2006-08-10 | Schlumberger Technology Corporation | Water shut off method and apparatus |
US20060185849A1 (en) * | 2005-02-23 | 2006-08-24 | Schlumberger Technology Corporation | Flow Control |
US7159556B2 (en) * | 2004-09-09 | 2007-01-09 | Toyota Jidosha Kabushiki Kaisha | Control apparatus and method for internal combustion engine |
US20070012444A1 (en) * | 2005-07-12 | 2007-01-18 | John Horgan | Apparatus and method for reducing water production from a hydrocarbon producing well |
US20070039741A1 (en) * | 2005-08-22 | 2007-02-22 | Hailey Travis T Jr | Sand control screen assembly enhanced with disappearing sleeve and burst disc |
US20070044962A1 (en) * | 2005-08-26 | 2007-03-01 | Schlumberger Technology Corporation | System and Method for Isolating Flow In A Shunt Tube |
US7185706B2 (en) * | 2001-05-08 | 2007-03-06 | Halliburton Energy Services, Inc. | Arrangement for and method of restricting the inflow of formation water to a well |
US20070131434A1 (en) * | 2004-12-21 | 2007-06-14 | Macdougall Thomas D | Flow control device with a permeable membrane |
US20070246210A1 (en) * | 2006-04-24 | 2007-10-25 | William Mark Richards | Inflow Control Devices for Sand Control Screens |
US20070246225A1 (en) * | 2006-04-20 | 2007-10-25 | Hailey Travis T Jr | Well tools with actuators utilizing swellable materials |
US20070246213A1 (en) * | 2006-04-20 | 2007-10-25 | Hailey Travis T Jr | Gravel packing screen with inflow control device and bypass |
US7318472B2 (en) * | 2005-02-02 | 2008-01-15 | Total Separation Solutions, Llc | In situ filter construction |
US7325616B2 (en) * | 2004-12-14 | 2008-02-05 | Schlumberger Technology Corporation | System and method for completing multiple well intervals |
US20080035350A1 (en) * | 2004-07-30 | 2008-02-14 | Baker Hughes Incorporated | Downhole Inflow Control Device with Shut-Off Feature |
US20080053662A1 (en) * | 2006-08-31 | 2008-03-06 | Williamson Jimmie R | Electrically operated well tools |
US20080135249A1 (en) * | 2006-12-07 | 2008-06-12 | Fripp Michael L | Well system having galvanic time release plug |
US20080149351A1 (en) * | 2006-12-20 | 2008-06-26 | Schlumberger Technology Corporation | Temporary containments for swellable and inflatable packer elements |
US20080149323A1 (en) * | 2006-12-20 | 2008-06-26 | O'malley Edward J | Material sensitive downhole flow control device |
US7395858B2 (en) * | 2005-08-04 | 2008-07-08 | Petroleo Brasiliero S.A. — Petrobras | Process for the selective controlled reduction of the relative water permeability in high permeability oil-bearing subterranean formations |
US7413022B2 (en) * | 2005-06-01 | 2008-08-19 | Baker Hughes Incorporated | Expandable flow control device |
US20090056816A1 (en) * | 2007-08-30 | 2009-03-05 | Gennady Arov | Check valve and shut-off reset device for liquid delivery systems |
US20090133874A1 (en) * | 2005-09-30 | 2009-05-28 | Dale Bruce A | Wellbore Apparatus and Method for Completion, Production and Injection |
US20090133869A1 (en) * | 2007-11-27 | 2009-05-28 | Baker Hughes Incorporated | Water Sensitive Adaptive Inflow Control Using Couette Flow To Actuate A Valve |
US20090139727A1 (en) * | 2007-11-02 | 2009-06-04 | Chevron U.S.A. Inc. | Shape Memory Alloy Actuation |
US20090205834A1 (en) * | 2007-10-19 | 2009-08-20 | Baker Hughes Incorporated | Adjustable Flow Control Devices For Use In Hydrocarbon Production |
Family Cites Families (2)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US6220350B1 (en) * | 1998-12-01 | 2001-04-24 | Halliburton Energy Services, Inc. | High strength water soluble plug |
US7640990B2 (en) * | 2005-07-18 | 2010-01-05 | Schlumberger Technology Corporation | Flow control valve for injection systems |
-
2007
- 2007-10-22 US US11/875,499 patent/US20090101344A1/en not_active Abandoned
-
2008
- 2008-10-21 WO PCT/US2008/080579 patent/WO2009055354A2/en active Application Filing
Patent Citations (99)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US1915867A (en) * | 1931-05-01 | 1933-06-27 | Edward R Penick | Choker |
US2119563A (en) * | 1937-03-02 | 1938-06-07 | George M Wells | Method of and means for flowing oil wells |
US2945541A (en) * | 1955-10-17 | 1960-07-19 | Union Oil Co | Well packer |
US2942668A (en) * | 1957-11-19 | 1960-06-28 | Union Oil Co | Well plugging, packing, and/or testing tool |
US3326291A (en) * | 1964-11-12 | 1967-06-20 | Zandmer Solis Myron | Duct-forming devices |
US4294313A (en) * | 1973-08-01 | 1981-10-13 | Otis Engineering Corporation | Kickover tool |
US3876471A (en) * | 1973-09-12 | 1975-04-08 | Sun Oil Co Delaware | Borehole electrolytic power supply |
US3975651A (en) * | 1975-03-27 | 1976-08-17 | Norman David Griffiths | Method and means of generating electrical energy |
US4153757A (en) * | 1976-03-01 | 1979-05-08 | Clark Iii William T | Method and apparatus for generating electricity |
US4186100A (en) * | 1976-12-13 | 1980-01-29 | Mott Lambert H | Inertial filter of the porous metal type |
US4187909A (en) * | 1977-11-16 | 1980-02-12 | Exxon Production Research Company | Method and apparatus for placing buoyant ball sealers |
US4257650A (en) * | 1978-09-07 | 1981-03-24 | Barber Heavy Oil Process, Inc. | Method for recovering subsurface earth substances |
US4434849A (en) * | 1978-09-07 | 1984-03-06 | Heavy Oil Process, Inc. | Method and apparatus for recovering high viscosity oils |
US4250907A (en) * | 1978-10-09 | 1981-02-17 | Struckman Edmund E | Float valve assembly |
US4248302A (en) * | 1979-04-26 | 1981-02-03 | Otis Engineering Corporation | Method and apparatus for recovering viscous petroleum from tar sand |
US4564996A (en) * | 1981-02-03 | 1986-01-21 | Thomas Weresch | Apparatus for working on leads of electronic components |
US4614303A (en) * | 1984-06-28 | 1986-09-30 | Moseley Jr Charles D | Water saving shower head |
US5439966A (en) * | 1984-07-12 | 1995-08-08 | National Research Development Corporation | Polyethylene oxide temperature - or fluid-sensitive shape memory device |
US4572295A (en) * | 1984-08-13 | 1986-02-25 | Exotek, Inc. | Method of selective reduction of the water permeability of subterranean formations |
US5016710A (en) * | 1986-06-26 | 1991-05-21 | Institut Francais Du Petrole | Method of assisted production of an effluent to be produced contained in a geological formation |
US4856590A (en) * | 1986-11-28 | 1989-08-15 | Mike Caillier | Process for washing through filter media in a production zone with a pre-packed screen and coil tubing |
US4821800A (en) * | 1986-12-10 | 1989-04-18 | Sherritt Gordon Mines Limited | Filtering media for controlling the flow of sand during oil well operations |
US4917183A (en) * | 1988-10-05 | 1990-04-17 | Baker Hughes Incorporated | Gravel pack screen having retention mesh support and fluid permeable particulate solids |
US4944349A (en) * | 1989-02-27 | 1990-07-31 | Von Gonten Jr William D | Combination downhole tubing circulating valve and fluid unloader and method |
US5004049A (en) * | 1990-01-25 | 1991-04-02 | Otis Engineering Corporation | Low profile dual screen prepack |
US5132903A (en) * | 1990-06-19 | 1992-07-21 | Halliburton Logging Services, Inc. | Dielectric measuring apparatus for determining oil and water mixtures in a well borehole |
US5156811A (en) * | 1990-11-07 | 1992-10-20 | Continental Laboratory Products, Inc. | Pipette device |
US5377750A (en) * | 1992-07-29 | 1995-01-03 | Halliburton Company | Sand screen completion |
US6699503B1 (en) * | 1992-09-18 | 2004-03-02 | Yamanuchi Pharmaceutical Co., Ltd. | Hydrogel-forming sustained-release preparation |
US5339895A (en) * | 1993-03-22 | 1994-08-23 | Halliburton Company | Sintered spherical plastic bead prepack screen aggregate |
US5431346A (en) * | 1993-07-20 | 1995-07-11 | Sinaisky; Nickoli | Nozzle including a venturi tube creating external cavitation collapse for atomization |
US5381864A (en) * | 1993-11-12 | 1995-01-17 | Halliburton Company | Well treating methods using particulate blends |
US6692766B1 (en) * | 1994-06-15 | 2004-02-17 | Yissum Research Development Company Of The Hebrew University Of Jerusalem | Controlled release oral drug delivery system |
US5551513A (en) * | 1995-05-12 | 1996-09-03 | Texaco Inc. | Prepacked screen |
US5896928A (en) * | 1996-07-01 | 1999-04-27 | Baker Hughes Incorporated | Flow restriction device for use in producing wells |
US6098020A (en) * | 1997-04-09 | 2000-08-01 | Shell Oil Company | Downhole monitoring method and device |
US6419021B1 (en) * | 1997-09-05 | 2002-07-16 | Schlumberger Technology Corporation | Deviated borehole drilling assembly |
US6338363B1 (en) * | 1997-11-24 | 2002-01-15 | Dayco Products, Inc. | Energy attenuation device for a conduit conveying liquid under pressure, system incorporating same, and method of attenuating energy in a conduit |
US6119780A (en) * | 1997-12-11 | 2000-09-19 | Camco International, Inc. | Wellbore fluid recovery system and method |
US6632527B1 (en) * | 1998-07-22 | 2003-10-14 | Borden Chemical, Inc. | Composite proppant, composite filtration media and methods for making and using same |
US6253847B1 (en) * | 1998-08-13 | 2001-07-03 | Schlumberger Technology Corporation | Downhole power generation |
US6228812B1 (en) * | 1998-12-10 | 2001-05-08 | Bj Services Company | Compositions and methods for selective modification of subterranean formation permeability |
US6635732B2 (en) * | 1999-04-12 | 2003-10-21 | Surgidev Corporation | Water plasticized high refractive index polymer for ophthalmic applications |
US20040052689A1 (en) * | 1999-08-17 | 2004-03-18 | Porex Technologies Corporation | Self-sealing materials and devices comprising same |
US6581682B1 (en) * | 1999-09-30 | 2003-06-24 | Solinst Canada Limited | Expandable borehole packer |
US7084094B2 (en) * | 1999-12-29 | 2006-08-01 | Tr Oil Services Limited | Process for altering the relative permeability if a hydrocarbon-bearing formation |
US6581681B1 (en) * | 2000-06-21 | 2003-06-24 | Weatherford/Lamb, Inc. | Bridge plug for use in a wellbore |
US6672385B2 (en) * | 2000-07-21 | 2004-01-06 | Sinvent As | Combined liner and matrix system |
US6372678B1 (en) * | 2000-09-28 | 2002-04-16 | Fairmount Minerals, Ltd | Proppant composition for gas and oil well fracturing |
US20040194971A1 (en) * | 2001-01-26 | 2004-10-07 | Neil Thomson | Device and method to seal boreholes |
US7419002B2 (en) * | 2001-03-20 | 2008-09-02 | Reslink G.S. | Flow control device for choking inflowing fluids in a well |
US20060118296A1 (en) * | 2001-03-20 | 2006-06-08 | Arthur Dybevik | Well device for throttle regulation of inflowing fluids |
US7185706B2 (en) * | 2001-05-08 | 2007-03-06 | Halliburton Energy Services, Inc. | Arrangement for and method of restricting the inflow of formation water to a well |
US6699611B2 (en) * | 2001-05-29 | 2004-03-02 | Motorola, Inc. | Fuel cell having a thermo-responsive polymer incorporated therein |
US20060108114A1 (en) * | 2001-12-18 | 2006-05-25 | Johnson Michael H | Drilling method for maintaining productivity while eliminating perforating and gravel packing |
US20060048942A1 (en) * | 2002-08-26 | 2006-03-09 | Terje Moen | Flow control device for an injection pipe string |
US20040035578A1 (en) * | 2002-08-26 | 2004-02-26 | Ross Colby M. | Fluid flow control device and method for use of same |
US6863126B2 (en) * | 2002-09-24 | 2005-03-08 | Halliburton Energy Services, Inc. | Alternate path multilayer production/injection |
US6951252B2 (en) * | 2002-09-24 | 2005-10-04 | Halliburton Energy Services, Inc. | Surface controlled subsurface lateral branch safety valve |
US6840321B2 (en) * | 2002-09-24 | 2005-01-11 | Halliburton Energy Services, Inc. | Multilateral injection/production/storage completion system |
US6938698B2 (en) * | 2002-11-18 | 2005-09-06 | Baker Hughes Incorporated | Shear activated inflation fluid system for inflatable packers |
US6857476B2 (en) * | 2003-01-15 | 2005-02-22 | Halliburton Energy Services, Inc. | Sand control screen assembly having an internal seal element and treatment method using the same |
US20050207279A1 (en) * | 2003-06-13 | 2005-09-22 | Baker Hughes Incorporated | Apparatus and methods for self-powered communication and sensor network |
US20050126776A1 (en) * | 2003-12-10 | 2005-06-16 | Russell Thane G. | Wellbore screen |
US20050171248A1 (en) * | 2004-02-02 | 2005-08-04 | Yanmei Li | Hydrogel for use in downhole seal applications |
US20050178705A1 (en) * | 2004-02-13 | 2005-08-18 | Broyles Norman S. | Water treatment cartridge shutoff |
US20050199298A1 (en) * | 2004-03-10 | 2005-09-15 | Fisher Controls International, Llc | Contiguously formed valve cage with a multidirectional fluid path |
US20080035350A1 (en) * | 2004-07-30 | 2008-02-14 | Baker Hughes Incorporated | Downhole Inflow Control Device with Shut-Off Feature |
US20060076150A1 (en) * | 2004-07-30 | 2006-04-13 | Baker Hughes Incorporated | Inflow control device with passive shut-off feature |
US7409999B2 (en) * | 2004-07-30 | 2008-08-12 | Baker Hughes Incorporated | Downhole inflow control device with shut-off feature |
US7322412B2 (en) * | 2004-08-30 | 2008-01-29 | Halliburton Energy Services, Inc. | Casing shoes and methods of reverse-circulation cementing of casing |
US20060042798A1 (en) * | 2004-08-30 | 2006-03-02 | Badalamenti Anthony M | Casing shoes and methods of reverse-circulation cementing of casing |
US20060048936A1 (en) * | 2004-09-07 | 2006-03-09 | Fripp Michael L | Shape memory alloy for erosion control of downhole tools |
US7159556B2 (en) * | 2004-09-09 | 2007-01-09 | Toyota Jidosha Kabushiki Kaisha | Control apparatus and method for internal combustion engine |
US7011076B1 (en) * | 2004-09-24 | 2006-03-14 | Siemens Vdo Automotive Inc. | Bipolar valve having permanent magnet |
US20060086498A1 (en) * | 2004-10-21 | 2006-04-27 | Schlumberger Technology Corporation | Harvesting Vibration for Downhole Power Generation |
US7325616B2 (en) * | 2004-12-14 | 2008-02-05 | Schlumberger Technology Corporation | System and method for completing multiple well intervals |
US20060175065A1 (en) * | 2004-12-21 | 2006-08-10 | Schlumberger Technology Corporation | Water shut off method and apparatus |
US20070131434A1 (en) * | 2004-12-21 | 2007-06-14 | Macdougall Thomas D | Flow control device with a permeable membrane |
US7493947B2 (en) * | 2004-12-21 | 2009-02-24 | Schlumberger Technology Corporation | Water shut off method and apparatus |
US7318472B2 (en) * | 2005-02-02 | 2008-01-15 | Total Separation Solutions, Llc | In situ filter construction |
US20060185849A1 (en) * | 2005-02-23 | 2006-08-24 | Schlumberger Technology Corporation | Flow Control |
US7413022B2 (en) * | 2005-06-01 | 2008-08-19 | Baker Hughes Incorporated | Expandable flow control device |
US20070012444A1 (en) * | 2005-07-12 | 2007-01-18 | John Horgan | Apparatus and method for reducing water production from a hydrocarbon producing well |
US7395858B2 (en) * | 2005-08-04 | 2008-07-08 | Petroleo Brasiliero S.A. — Petrobras | Process for the selective controlled reduction of the relative water permeability in high permeability oil-bearing subterranean formations |
US20070039741A1 (en) * | 2005-08-22 | 2007-02-22 | Hailey Travis T Jr | Sand control screen assembly enhanced with disappearing sleeve and burst disc |
US20070044962A1 (en) * | 2005-08-26 | 2007-03-01 | Schlumberger Technology Corporation | System and Method for Isolating Flow In A Shunt Tube |
US20090133874A1 (en) * | 2005-09-30 | 2009-05-28 | Dale Bruce A | Wellbore Apparatus and Method for Completion, Production and Injection |
US20070246213A1 (en) * | 2006-04-20 | 2007-10-25 | Hailey Travis T Jr | Gravel packing screen with inflow control device and bypass |
US20070246225A1 (en) * | 2006-04-20 | 2007-10-25 | Hailey Travis T Jr | Well tools with actuators utilizing swellable materials |
US20070246210A1 (en) * | 2006-04-24 | 2007-10-25 | William Mark Richards | Inflow Control Devices for Sand Control Screens |
US20080053662A1 (en) * | 2006-08-31 | 2008-03-06 | Williamson Jimmie R | Electrically operated well tools |
US20080135249A1 (en) * | 2006-12-07 | 2008-06-12 | Fripp Michael L | Well system having galvanic time release plug |
US20080149323A1 (en) * | 2006-12-20 | 2008-06-26 | O'malley Edward J | Material sensitive downhole flow control device |
US20080149351A1 (en) * | 2006-12-20 | 2008-06-26 | Schlumberger Technology Corporation | Temporary containments for swellable and inflatable packer elements |
US20090056816A1 (en) * | 2007-08-30 | 2009-03-05 | Gennady Arov | Check valve and shut-off reset device for liquid delivery systems |
US20090205834A1 (en) * | 2007-10-19 | 2009-08-20 | Baker Hughes Incorporated | Adjustable Flow Control Devices For Use In Hydrocarbon Production |
US20090139727A1 (en) * | 2007-11-02 | 2009-06-04 | Chevron U.S.A. Inc. | Shape Memory Alloy Actuation |
US20090133869A1 (en) * | 2007-11-27 | 2009-05-28 | Baker Hughes Incorporated | Water Sensitive Adaptive Inflow Control Using Couette Flow To Actuate A Valve |
Cited By (31)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US8430162B2 (en) | 2009-05-29 | 2013-04-30 | Schlumberger Technology Corporation | Continuous downhole scale monitoring and inhibition system |
US20100300684A1 (en) * | 2009-05-29 | 2010-12-02 | Schlumberger Technology Corporation | Continuous downhole scale monitoring and inhibition system |
US8931566B2 (en) | 2009-08-18 | 2015-01-13 | Halliburton Energy Services, Inc. | Method and apparatus for autonomous downhole fluid selection with pathway dependent resistance system |
US9109423B2 (en) | 2009-08-18 | 2015-08-18 | Halliburton Energy Services, Inc. | Apparatus for autonomous downhole fluid selection with pathway dependent resistance system |
US9080410B2 (en) | 2009-08-18 | 2015-07-14 | Halliburton Energy Services, Inc. | Method and apparatus for autonomous downhole fluid selection with pathway dependent resistance system |
US8657017B2 (en) | 2009-08-18 | 2014-02-25 | Halliburton Energy Services, Inc. | Method and apparatus for autonomous downhole fluid selection with pathway dependent resistance system |
US8714266B2 (en) | 2009-08-18 | 2014-05-06 | Halliburton Energy Services, Inc. | Method and apparatus for autonomous downhole fluid selection with pathway dependent resistance system |
US9260952B2 (en) | 2009-08-18 | 2016-02-16 | Halliburton Energy Services, Inc. | Method and apparatus for controlling fluid flow in an autonomous valve using a sticky switch |
US9133685B2 (en) | 2010-02-04 | 2015-09-15 | Halliburton Energy Services, Inc. | Method and apparatus for autonomous downhole fluid selection with pathway dependent resistance system |
US20110198097A1 (en) * | 2010-02-12 | 2011-08-18 | Schlumberger Technology Corporation | Autonomous inflow control device and methods for using same |
US8752629B2 (en) | 2010-02-12 | 2014-06-17 | Schlumberger Technology Corporation | Autonomous inflow control device and methods for using same |
US8616290B2 (en) | 2010-04-29 | 2013-12-31 | Halliburton Energy Services, Inc. | Method and apparatus for controlling fluid flow using movable flow diverter assembly |
US8985222B2 (en) | 2010-04-29 | 2015-03-24 | Halliburton Energy Services, Inc. | Method and apparatus for controlling fluid flow using movable flow diverter assembly |
US8757266B2 (en) | 2010-04-29 | 2014-06-24 | Halliburton Energy Services, Inc. | Method and apparatus for controlling fluid flow using movable flow diverter assembly |
US8708050B2 (en) | 2010-04-29 | 2014-04-29 | Halliburton Energy Services, Inc. | Method and apparatus for controlling fluid flow using movable flow diverter assembly |
US8622136B2 (en) | 2010-04-29 | 2014-01-07 | Halliburton Energy Services, Inc. | Method and apparatus for controlling fluid flow using movable flow diverter assembly |
EP2383430A3 (en) * | 2010-04-29 | 2013-02-20 | Halliburton Energy Services, Inc. | Method and apparatus for controlling fluid flow using moveable flow diverter assembly |
AU2011201843B2 (en) * | 2010-04-29 | 2015-11-26 | Halliburton Energy Services, Inc. | Method and apparatus for controlling fluid flow using movable flow diverter assembly |
EP2697473A4 (en) * | 2011-04-11 | 2015-12-16 | Halliburton Energy Services Inc | Selectively variable flow restrictor for use in a subterranean well |
US9200502B2 (en) | 2011-06-22 | 2015-12-01 | Schlumberger Technology Corporation | Well-based fluid communication control assembly |
US9051819B2 (en) | 2011-08-22 | 2015-06-09 | Baker Hughes Incorporated | Method and apparatus for selectively controlling fluid flow |
US8991506B2 (en) | 2011-10-31 | 2015-03-31 | Halliburton Energy Services, Inc. | Autonomous fluid control device having a movable valve plate for downhole fluid selection |
US9291032B2 (en) | 2011-10-31 | 2016-03-22 | Halliburton Energy Services, Inc. | Autonomous fluid control device having a reciprocating valve for downhole fluid selection |
US9404349B2 (en) | 2012-10-22 | 2016-08-02 | Halliburton Energy Services, Inc. | Autonomous fluid control system having a fluid diode |
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 |
WO2016133846A1 (en) * | 2015-02-16 | 2016-08-25 | Baker Hughes Incorporated | Disintegrating plugs to delay production through inflow control devices |
US9920601B2 (en) | 2015-02-16 | 2018-03-20 | Baker Hughes, A Ge Company, Llc | Disintegrating plugs to delay production through inflow control devices |
WO2018135950A1 (en) * | 2017-01-17 | 2018-07-26 | Scale Protection As | Autonomous water flow shutoff device |
US10890067B2 (en) * | 2019-04-11 | 2021-01-12 | Saudi Arabian Oil Company | Method to use a buoyant body to measure two-phase flow in horizontal wells |
CN114458284A (en) * | 2020-10-30 | 2022-05-10 | 中国石油天然气股份有限公司 | Release device, screen pipe column and production section testing method |
Also Published As
Publication number | Publication date |
---|---|
WO2009055354A2 (en) | 2009-04-30 |
WO2009055354A3 (en) | 2009-07-09 |
Similar Documents
Publication | Publication Date | Title |
---|---|---|
US20090101344A1 (en) | Water Dissolvable Released Material Used as Inflow Control Device | |
US7913765B2 (en) | Water absorbing or dissolving materials used as an in-flow control device and method of use | |
US7918272B2 (en) | Permeable medium flow control devices for use in hydrocarbon production | |
US7762341B2 (en) | Flow control device utilizing a reactive media | |
US8544548B2 (en) | Water dissolvable materials for activating inflow control devices that control flow of subsurface fluids | |
US8069921B2 (en) | Adjustable flow control devices for use in hydrocarbon production | |
US7451815B2 (en) | Sand control screen assembly enhanced with disappearing sleeve and burst disc | |
US8245778B2 (en) | Fluid control apparatus and methods for production and injection wells | |
US20090101354A1 (en) | Water Sensing Devices and Methods Utilizing Same to Control Flow of Subsurface Fluids | |
US8893809B2 (en) | Flow control device with one or more retrievable elements and related methods | |
US8839849B2 (en) | Water sensitive variable counterweight device driven by osmosis | |
US8424609B2 (en) | Apparatus and method for controlling fluid flow between formations and wellbores | |
US20090301726A1 (en) | Apparatus and Method for Controlling Water In-Flow Into Wellbores | |
CA2976660C (en) | Disintegrating plugs to delay production through inflow control devices | |
WO2008143784A2 (en) | Apparatus for autonomously controlling the inflow of production fluids from a subterranean well | |
US8550166B2 (en) | Self-adjusting in-flow control device | |
US11466538B2 (en) | Inflow control device and method for completing a wellbore | |
US10145219B2 (en) | Completion system for gravel packing with zonal isolation | |
US20120061093A1 (en) | Multiple in-flow control devices and methods for using same | |
Gomez et al. | Novel Multi-Stage Fracturing Sand Control Technology to Improve Completion Efficiency, Early Production and Reduce Well Cost |
Legal Events
Date | Code | Title | Description |
---|---|---|---|
AS | Assignment |
Owner name: BAKER HUGHES INCORPORATED, TEXAS Free format text: ASSIGNMENT OF ASSIGNORS INTEREST;ASSIGNORS:CROW, STEPHEN L.;CORONADO, MARTIN P.;JOHNSON, MICHAEL H.;REEL/FRAME:020511/0431;SIGNING DATES FROM 20080201 TO 20080211 |
|
STCB | Information on status: application discontinuation |
Free format text: ABANDONED -- FAILURE TO RESPOND TO AN OFFICE ACTION |