Abstract: A cable duct device in a swellable packer (1) of the kind in which the packer (1) is adapted to be able of sealing an annulus (3), and in which the swellable packer (1) is provided with at least one opening (6) therethrough adapted to constitute a duct for a cable (12).

Abstract: The invention relates to a method of performing intelligent completion design for a reservoir within a field having at least one wellsite with a steam injection well penetrating a subterranean formation of the field for extracting fluid from the reservoir therein. The method involves obtaining measurement data of the subterranean formation associated with the steam injection well, generating, using a processor of a computer, a reservoir model based on the measurement data, determining, using the processor, a geological profile adjacent to the steam injection well using the reservoir model, identifying, using the processor, a location along the steam injection well based on the geological profile according to a pre-determined criteria, and defining and storing, using the processor, a steam injection configuration based on the location.

Abstract: The invention concerns a system or a method for maintaining zonal isolation in a wellbore. According to the invention, the system comprises, at a specific location along said wellbore, a sealing element, said sealing element being able to deform both during and after placement and is maintained after placement under compression through a pressurizing fluid or by confinement in a volume.

Abstract: A high temperature packer (10) force a tubular string in a well, and includes a packer mandrel (12) and an elastomeric packer body (14) positioned circumferentially about the mandrel. An upper packer head (16) and a lower packer head (18) are each positioned about the mandrel and secured to an end of the packer body. A connector (24) axially interconnects at least one of the upper packer head and lower packer head to the packer mandrel, and a temperature responsive member (30) maintains the connector in position to secure the packer head to the mandrel until the temperature in the well rises to a level such that the responsive member yields to allow the connector to release the packer head from the mandrel.

Abstract: The present invention relates to a sealing and/or anchoring element for use in pipelines (1). The invention is characterized in that the sealing and/or anchoring element includes at least one helical element (5a, 5b, 14a, 14b) disposed around a string section (10), with the helical element (5a, 5b, 14a, 14b) being configured so as to be able to expand radially towards an inner wall of the pipeline (1) as the circumferential diameter thereof is increased.

Abstract: Preformed ribs are held closely to the swelling element and then are allowed to assume an expanded position to capture the ends of the swelling element. Many variations are possible one of which is retaining the ribs in a run in position with a band that releases by interaction with well fluid. In another embodiment the ribs are of a shape memory material and go to the enlarged state after a time and exposure to well fluids. The swelling action of the element could urge the ribs to the expanded position. Alternatively, a retractable sleeve can be actuated after a delay using a piston and a sealed compartment where a material must dissolve or otherwise go away before the piston can stroke to remove a retainer from ribs that can then move out.

Abstract: A swelling packer is covered with a material that is preferably in a tubular form and slipped over the swelling element to be shrink fit with applied heat. The material is formulated to break down at temperatures slightly below the expected downhole temperatures so that ideally the packer has about 48 hours of swelling delay which is normally a time period long enough to allow it to be properly located without it swelling so much as to cause it to be damaged by running in. Various polymers can be used to make an imperious covering for run in that on the way starts to break down. Ideally the material for the cover disappears about the time of sealing or shortly thereafter.

Abstract: A swelling packer is covered with a material that is preferably in a tubular form and slipped over the swelling element to be shrink fit with applied heat. The material is formulated to break down at temperatures slightly below the expected downhole temperatures so that ideally the packer has about 48 hours of swelling delay which is normally a time period long enough to allow it to be properly located without it swelling so much as to cause it to be damaged by running in. Various polymers can be used to make an imperious covering for run in that on the way starts to break down. Ideally the material for the cover disappears about the time of sealing or shortly thereafter.

Abstract: The present invention relates to a seal element for a wellbore which includes a support member, a bag positioned on the support member and a eutectic material positionable in the bag. The bag may be axially compressed and axially extended along the support member thereby permitting sealing and unsealing of an annulus in a wellbore. The eutectic material may be a phase changing salt.

Abstract: A packer (80) for establishing sealing engagement with a surface disposed in a wellbore includes a packer mandrel (90) and a seal assembly (100, 102, 104) slidably disposed about the packer mandrel (90). The seal assembly (100, 102, 104) has a running position and a radially expanded sealing position. A piston (122) is slidably disposed about the packer mandrel (90) and operably associated with the seal assembly (100, 102, 104). A collet assembly 145 is disposed about the packer mandrel (90) and is releasably coupled to the piston (122) such that radially inwardly shifting at least portion of the collet assembly (145) decouples the collet assembly (145) from the piston (122) allowing the piston (122) to shift longitudinally relative to the packer mandrel (90) which operates the seal assembly (100, 102, 104) from the running position to the radially expanded sealing position, thereby setting the packer (80).

Abstract: Disclosed herein are apparatuses and methods for packing off or choking a radial flow port through a tubular. In some embodiments, the apparatuses and methods comprise a support element and a polymeric element surrounding the support element. The polymeric element closes or chokes the radial flow port when contacted with the tubular.

Abstract: An oilfield apparatus has a swellable elastomeric composition that includes a swellable elastomer and one or more nanosensors dispersed therein. An oilfield assembly for exploring for, drilling for, testing for, or producing hydrocarbons includes various oilfield elements such as tubing, jointed pipe, sucker rods, submersible pump motor protector bags, packer elements, blow out preventer elements, zonal isolation tool elements, etc; and one or more of the oilfield elements has a swellable elastomeric composition that includes a swellable elastomer and one or more nanosensors dispersed therein. A method of selecting one or more oilfield elements has a component of an elastomeric composition that includes a swellable elastomer and one or more nanosensors dispersed therein; and a method of using the one or more oilfield elements in an oilfield operation, thus exposing the oilfield element to an oilfield environment.

Abstract: Embodiments of the present invention generally relate to a method and/or apparatus for deploying wireline tools with a non-electric string. In one embodiment, a method of determining a free point of a tubular string stuck in a wellbore includes deploying a tool string in the stuck tubular with a non-electric string. The free point assembly includes a battery, a controller, and a free point tool. The method further includes activating the free point tool by the controller. The free point tool contacts an inner surface of the stuck tubular string. The method further includes applying a tensile force and/or torque to the stuck tubular string; and measuring a response of the tubular string with the free point tool.

Abstract: A well sealing system includes a tailipipe set in a wellbore casing, the annular space between the tailpipe and the casing being sealed by a packer comprising at least two annular seals, and the internal diameter of the tailpipe being sealed by at least two internal seals. Disclosed are also an apparatus and a method for providing a casing in a bore hole for a well an offshore location, comprising the steps of: a) fabricating a casing in a location remote from the offshore well location; b) floating the casing to the location; c) orienting the casing to a substantially vertical position; d) lowering in a drilling assembly; e) operating a drill bit included in the drilling assembly to drill a borehole; f) lowering the casing into the bore hole as required.

Abstract: A dual packer for at least partially defining a production zone in a wellbore, the dual packer including a packer body having an up-hole side and a down-hole side. A first through bore and a second through bore each extend through the packer body from the up-hole side to the down-hole side. A first piping extends from the down-hole side of the first through bore and includes a perforated sub adjacent the down-hole side of the packer body. A second piping extends from the down-hole side of the second through bore and is communicably connected to the first piping down-hole of the first perforated sub.

Abstract: A high circulation rate packer (50) for establishing a sealing and gripping engagement with a well casing (34) disposed in a wellbore (32). The packer (50) includes a packer mandrel (54), a seal assembly (72) slidably disposed about the packer mandrel (54) that has a running position and a radially expanded sealing position and a cover (74) that is slidably disposed relative to the packer mandrel (54). The cover (74) has a running position wherein the cover is disposed about the seal assembly (72) and a retracted position wherein the cover (74) is at least partially removed from about the seal assembly (72).

Abstract: A kit of parts which is assembled to form downhole apparatus comprises a swellable member, which expands upon contact with at least one predetermined fluid, and a connector. The swellable member has a first mating profile towards a first end and a second mating profile towards a second, opposing end. The connector has a mating profile configured to mate with each of the first and second mating profiles of the swellable member. The connector can therefore be connected to either the first and second ends of the swellable member. The connector may be an end connector, or may connect the swellable member to a second swellable member. In either case, the connector may define an arresting surface against which the swellable member abuts when expanding. The kit of parts can be adapted to and installed on any well tubular, and may form any of a variety of tools.

Abstract: Systems and methods for use of pressure actuated collapsing capsules suspended in a thermally expanding fluid in a subterranean containment space are herein disclosed. According to one embodiment, a system comprises a subterranean pressured fluid receiving containment space located in a wellbore of a subterranean well and a pressured operating fluid filling at least a portion of the containment space. The pressured operating fluid comprises a mixture of substantially incompressible liquid and pressure actuated collapsing capsules. At least a portion of the pressure actuated collapsing capsules implode as pressure in the containment space exceeds a predetermined limit.

Abstract: A downhole apparatus for location on a tubular, an assembly, and a method of use are described. The apparatus comprising a body with a throughbore configured to receive a tubular, and at least one swellable member that comprises a material selected to expand upon exposure to at least one predetermined fluid. The swellable member is arranged to provide a seal between the body and a tubular on which it is located during use, for example in a micro-annulus between the body and the tubular. Advantageously, the apparatus may be configured such that the body is moveable on the tubular before expansion, which may permit the apparatus to be slipped or slid onto the tubular into its desired location. The apparatus may be configured to rotate on a tubular, or slide on the tubular.

Abstract: An assembly for producing oil and/or gas through a well traversing stacked oil and/or gas bearing earth layers comprises a series of expandable packers and integrated perforating gun and sandscreen assemblies mounted on a production tubing such that each integrated perforating gun and sandscreen assembly is located adjacent an oil and/or gas bearing earth layer and at least one expandable packer is located between a pair of adjacent oil and/or gas bearing earth layers, and at least one inflow opening arranged in the wall of the production tubing adjacent to each sandscreen assembly. The integrated perforating gun and sandscreen assemblies are installed in a single run into the well such that uncontrolled fluid and/or sand influx into the well before installation of the sandscreens and expandable packers is avoided.

Abstract: A debris barrier for a retrievable mechanical set packer is held retracted for run in. It is held spaced apart from upper slips and uses a spring bias that acts on the slips to keep them energized to also energize the barrier to the extended position to keep debris out of the upper slips when the packer is set. The debris barrier is preferably a sleeve that is axially compressed by the setting procedure to increase in diameter and span the gap between the packer mandrel and the set upper slips. Retrieving the packer is enabled by a retraction of the debris barrier as the upper slips are undermined with rotation and pickup force on the packer mandrel. The lack of a debris barrier could prevent retrieval of the packer in well bores where debris is present and has a tendency to settle around and more critically under the upper slips.

Abstract: An example of a wellbore tool assembly includes a mandrel having an outer surface and a longitudinal bore; a tubular, swellable seal member having opposing ends and an inner surface defining a bore between the opposing ends, the seal member encircling a portion of the mandrel; an operable downhole element carried with the mandrel; and a control line connected to the operable downhole element, the control line extending from the downhole element between the outer surface of the mandrel and the inner surface of the seal member to the other side of the seal member from the downhole element.

Abstract: An inflatable features a swelling layer. The swelling layer can be made integral or attached to the element or it can be bonded or otherwise secured to the mandrel. Upon inflation with fluid, the element expands into sealing contact with a surrounding tubular or wellbore. The fluid is absorbed or otherwise interacts with the swelling layer so that, in a preferred embodiment, the total occupied volume of the swelling layer and fluid individually is retained after mixing with the swelling of the layer acting to hold the seal of the inflatable element even if a problem develops in the sealing element.

Abstract: A swell packer includes a base tubular; a seal member encircling the base tubular, the seal member swelling radially to a seal equilibrium swell upon contact with a particular fluid; and a disc positioned about the base tubular substantially abutting an end of the seal member but not physically connected to the seal member in a manner that limits the equilibrium swell of the seal member, the disc swelling radially to a first equilibrium swell upon contact with a particular fluid.

Abstract: A sealing member. The sealing member can include a support member having an inner bore and a plurality of apertures formed therethrough. An outer swellable element can be disposed about an outer diameter of the support member, and an inner swellable element can be disposed about an inner diameter of the support member. The swellable elements can be unitized with one another through each aperture. A retainer can be disposed at each end of the support member.

Abstract: The device is a sleeve that is radially expandable under the action of an inflation fluid so as to press the sleeve hermetically against a wall. The sleeve includes firstly a pair of cylindrical membranes having walls that are flexible and elastic, the membranes being engaged coaxially one inside the other, comprising an inner membrane for being subjected internally to the pressure of the inflation fluid, and an outer membrane for being pressed against the wall of the pipe or the well in order to provide sealing, and secondly, interposed between said membranes, at least one very dense annular fiber structure made up of a multitude of fine and long fibers having high mechanical strength that interconnect said end members and that are wound helically around the inner membrane, said winding being such that the density of the fibers diminishes from each end towards the central portion.

Abstract: A downwell packer assembly includes a tubular member and a packer element mounted on the tubular member. The packer element comprises a composition that includes a polymer. The packer element includes micropores (typically created via a blowing agent). When the packer element is exposed to a swelling fluid, such as water or hydrocarbon, the micropores can help to control and, in some instances, increase the rate of swelling. Such swelling enables the packer element to form a seal against the walls of the wellbore.

Abstract: A packer system for a wellbore includes a tubular member and a packer element having an inner layer that circumferentially overlies the tubular member and an outer layer that circumferentially overlies the inner layer. The inner layer includes an elastomer that swells upon contact with a swelling fluid. The outer layer includes a material that provides at least a partial barrier to the swelling fluid.

Abstract: A packer system for a wellbore includes: a tubular member; a packer element mounted on the tubular member and formed of a swellable polymeric material; and a securing unit that is configured to enable the position of the packer element to be adjusted relative to the tubular member when the securing unit is in an unsecured condition, but secures the packer element in place when the securing unit is in a secured condition.

Abstract: A swelling element rate regulation technique and product features an outer coating on a core of an element. The core is reactive to hydrocarbons or water depending on how it is configured. The surrounding coating is preferably formed of fine ground particles of a non-swelling polymer mixed in a solvent such as methyl-ethyl-ketone that is applied in a thin layer to the core exterior. This uncured outer layer is then contacted by a patterned surface. The patterned surface is pressed firmly against the uncured polymer/solvent mixture and transfers an inverse of the pattern to the surface of the coating. As pressure is applied, heat may also be applied to cure the coating. The resulting pattern is designed such that openings in the coating are created that regulate infiltration of water or other fluids through it and, as a result, the rate of swelling in the wellbore. Swell rate in governed in part by the ratio of the exposed area of the swelling compound to the total volume of the swelling compound.

Abstract: A gravel pack apparatus for use in a wellbore includes a screen assembly to filter particulates, at least one shunt conduit to carry gravel slurry, and a swellable element around a portion of the at least one shunt conduit. The swellable element swells in response to an input stimulus and expands radially outwardly to seal against the wellbore.

Abstract: A bridge plug comprises an axially compressible cylinder having plural expansion sleeves. A mandrel extends axially through the cylinder, and has a threaded portion engaged with the cylinder, such that rotation of the mandrel causes compression of the cylinder. A setting tool comprises a housing containing a motor and a drive shaft driven by the motor. The setting tool is configured to be removably coupled to a bridge plug with the drive shaft drivingly coupled to the bridge plug's mandrel, such that operation of the setting tool motor causes compression of the bridge plug. The setting tool is used to lower a bridge plug within a well casing, and to compress the bridge plug causing, outward protrusion of sealing members of the bridge plug to set the bridge plug in place. Cement may be applied above the set bridge plug to form an easily drillable seal.

Abstract: A packer that uses an element that swells to the set position is disclosed having a device that boosts the set force of the swollen element against the borehole. The force is axially applied at one end or two and preferably comprises a cone driven by a stored or applied force such that the cone is driven between the element and the mandrel that supports the element. Initiation of the boost force can be varied in its timing and the power behind the cone can come from a variety of sources such as a spring, hydrostatic pressure, or applied forces, to name a few. The movement of the cone is locked to prevent reversal of its motion when the packer is set. The swelling enhances the engagement of the element to the cone to minimize relative movement between them.

Abstract: A downhole packer or sealing device uses a swelling sealing element that is initially held in a compressed state. Exposure to well or other fluids occurs downhole as the initial restraint on the element is overcome. The element takes on well fluids as it resumes its relaxed position or swells. The element is preferably an open cell material such as foam and has another material in its passages. The material in the passages, when exposed to well fluids, itself grows in size and can get harder. It blocks or seals the passages in the foam so that the swollen foam becomes more like a closed cell material and can retain a seal against a greater range of operating conditions than had its passages remained open or unobstructed with another material.

Abstract: A system for monitoring a wellbore service treatment, comprising a downhole tool operable to perform the wellbore service treatment; a conveyance connected to the downhole tool for moving the downhole tool in the wellbore, and a plurality of sensors operable to provide one or more wellbore indications and attached to the downhole tool or a component thereof via one or more tethers. A method of monitoring a wellbore service treatment, comprising conveying into a wellbore a downhole tool operable to perform the wellbore service treatment and a plurality of sensors operable to provide one or more wellbore indications attached to the downhole tool or a component thereof via one or more tethers, deploying the downhole tool at a first position in the wellbore for service, treating the wellbore at the first position; and monitoring an at least one wellbore indication provided by the wellbore sensors at the first position.

Abstract: A system is provided for sealing a space in a wellbore formed in an earth formation. The system has a swelleable body arranged in the wellbore in a manner so as to seal the space upon swelling of the swelleable body, the swelleable body being susceptible of being in contact with formation water flowing into the wellbore, the swelleable body including a matrix material provided with a compound soluble in the formation water. The matrix material substantially prevents or restricts migration of the compound out of the swelleable body and allows migration of the formation water into the swelleable body by osmosis so as to induce swelling of the swelleable body upon migration of the formation water into the swelleable body.

Abstract: One embodiment includes an apparatus comprising a surface slip to support drill tubing and having a communications instrument.

Abstract: Methods and apparatus for subterranean well bore operations. An exemplary embodiment of a method is a method of activating a device in a subterranean well bore, the device having a baffle adapter configured to achieve sealing contact with a cementing plug, the cementing plug having an outer body and a detachable inner mandrel attached to the outer body, including the steps of: displacing the cementing plug into contact with the baffle adapter so that the outer body of the cementing plug achieves sealing contact with the baffle adapter; and applying a differential pressure across the cementing plug, thereby activating the device. An exemplary embodiment of an apparatus is a baffle adapter, having an inner bore designed to engage and seal against the outer body of a plug.

Abstract: A technique is provided for moving a downhole equipment assembly into engagement or out of engagement with a lower completion positioned in a wellbore. An upper communication line extends past the downhole equipment assembly, and a lower communication line is located with the lower completion. During engagement, the downhole equipment assembly is connected with the lower completion and the communication lines are coupled via a wet mate system.

Abstract: A packer device includes a central packer mandrel and a radially surrounding expansion mandrel. At least one slip mandrel carrying wickers surrounds the expansion mandrel and is secured in place upon the expansion mandrel by an annular retaining ring. The slip mandrel is secured to the retaining ring by screw connectors that pass through the slip mandrel and into retainer segments. The retaining ring is clamped between the slip mandrel and segments. Additionally, the packer device carries a fluid seal that is made up of a thermoplastic material with elastomeric energizing elements.

Abstract: A field assembled packer or plug features a sleeve of a swelling material, preferably rubber, which is slipped over the tubular. A pair of molds is assembled over the tubular. The molds can accommodate variation in the size and out of roundness of standard API tubulars. An epoxy mixture is formulated on site and pumped into the molds at opposed ends of the sealing element assembly and allowed to set up. The molds are removed and the assembly is ready to be run in the hole as a packer included in a tubular string. The element assembly can include a harder swelling material on opposed ends of the main sealing element to protect the main sealing element from damage during run in.

Abstract: Annular packer (2) arranged on the outside of a production tubing (4) said packer comprises a core (12) comprising elastic polymer swelling by absorption of hydrocarbons. The core (12) may be surrounded by an external mantle of rubber (10), which is permeable to hydrocarbons and may be equipped with a reinforcement (11). The core (12) swells by absorption of hydrocarbons and the packer (2) expands thus in order to seal the annular space (5) between the production tubing (4) and the well wall (6).

Abstract: The present invention relates to an arrangement for affixing an expandable packer 22, 32 in a hole 30, wherein the arrangement includes a piston-and-cylinder device 11, 12 with which the piston can be caused to move in the cylinder with the aid of a pressurized medium. Expansion of the packer is effected with the aid of the movement of the piston 11, by transferring the force generated by piston movement to an expandable part 24, 34 of the packer 22, 32 so that said part will expand. Expansion of the packer results in the packer being firmly affixed in the hole by means of friction. The arrangement also includes an elongate main body 1 that has a through-penetrating aperture extending in the longitudinal direction of the body. The main body 1 has a front end 3, which faces inwardly of the hole when fastening the packer and towards the packer.

Abstract: An integral polished bore assembly for use in a wellbore includes a barrel having a polished bore; at least one no-go member positioned within the barrel; an elongated locator member having a sealing head and an end, the end extending out of the barrel; and a radial port formed through the barrel.

Abstract: A method of controlling the pressure of a casing annulus in a subterranean well that includes injecting into the casing annulus a composition including a base fluid and a polymer coated colloidal solid material. The polymer coated colloidal solid material includes: a solid particle having an weight average particle diameter (d50) of less than two microns, and a polymeric dispersing agent coated onto the surface of the solid particle during the comminution (i.e. grinding) process utilized to make the colloidal particles. The polymeric dispersing agent may be a water soluble polymer having a molecular weight of at least 2000 Daltons. The solid particulate material may be selected from materials having of specific gravity of at least 2.68 and preferably the solid particulate material may be selected from barium sulfate (barite), calcium carbonate, dolomite, ilmenite, hematite, olivine, siderite, strontium sulfate, combinations and mixtures of these-and other similar solids.

Abstract: A sealing element that swells on exposure to well fluids present or added to the wellbore is assembled to the mandrel in a manner to induce circumferential stresses proximately to the inside diameter of the element so as to resist the tendency of the inside diameter of the element to grow during the swelling process. A vacuum and a pressure method are described. Leak paths between the mandrel and the sealing element are minimized or eliminated as a result.

Abstract: A measurement device is disclosed which includes a structure adapted to be removably coupled to a Christmas tree, a sleeve operatively coupled to the structure and a flowmeter positioned at least partially within the sleeve.

Abstract: The present disclosure addressed apparatus and methods for forming an annular isolator in a borehole after installation of production tubing. Annular seal means are carried in or on production tubing as it is run into a borehole. In conjunction with expansion of the tubing, the seal is deployed to form an annular isolator. An inflatable element carried on the tubing may be inflated with a fluid carried in the tubing and forced into the inflatable element during expansion of the tubing. Reactive chemicals may be carried in the tubing and injected into the annulus to react with each other and ambient fluids to increase in volume and harden into an annular seal. An elastomeric sleeve, ring or band carried on the tubing may be expanded into contact with a borehole wall and may have its radial dimension increased in conjunction with tubing expansion to form an annular isolator.

Abstract: A technique is provided to isolate regions of a wellbore. The technique utilizes a swellable material packer that comprises a layer of swellable material disposed about a tubular member of a completion. When the layer is exposed to a substance that induces swelling of the swellable material, the layer expands between the tubular and a surrounding wall to isolate a region of the wellbore annulus.

Abstract: A packer for downhole use features interacting elements of swelling material. Preferably the elements are in contact for relative movement from an initial diameter for run in. As the elements swell, they move with respect to each other to enlarge the diameter of the assembly so that a sealing contact is made. Each element exerts a residual force on the adjacent element to enhance the seal. Each element is preferably coated with a material that allows well fluids to reach the swelling material and then later to stiffen and become impervious from exposure to such fluids. The assembly can be covered for run in to delay the onset of expansion until the target depth is reached for the packer to be set.