Abstract: A method of plugging a well includes lowering a solid body into a wellbore by wireline; and filling the space around the solid body with a liquid plugging material. The solid body and the liquid plugging material together form a plug after the liquid plugging material is set.

Abstract: A joint-locking plug is deployed next to tubing joint connection gap. The actuation of the joint-locking plug allows expanding a gripping portion which includes a protrusion section. The contact between the protrusion section of the gripping portion with the inner surface of the tubing string allows to end the actuation. Due to the bi-stable slips, the pumping of an actuated plug will engage the protrusion section of the gripping portion inside the joint connection gap, and provide the locking of the gripping portion of the plug. By further applying a fluid pressure, the anchoring section of the gripping portion gets engaged and further set the plug in place, allowing to perform further operation with the plug.

Abstract: Reelable sensors arrays are independently fabricated separate from a downhole tubular. The sensor arrays are then reeled together onto a spool. At the well site, the sensor array is unreeled from the spool and attached to the tubular as it is deployed downhole, resulting in a fast and efficient method of sensor deployment.

Abstract: A well tool for use in completing a wellbore includes a tubular housing having a central bore and a housing port through a wall of the tubular housing, an inner mandrel disposed within the tubular housing and selectively movable between a first, closed position and a second, open position in response to a fluid pressure in the central bore, a sealing element circumscribing a portion of the tubular housing, and a setting sleeve. The inner mandrel is configured to open the housing port when the inner mandrel is in the second, open position. The setting sleeve is movable between a first, retracted position and a second, expanded position, where the setting sleeve is configured to activate the sealing element in the second, expanded position in response to movement of the inner mandrel to the second, open position.

Abstract: A substantially air-tight triple seal arrangement along a seam between first and second tool segments comprises inner, middle and outer seals forming first and second substantially air tight vacuum chambers.

Abstract: A method of soil stabilization includes mixing a geopolymer material with an alkaline activator and adding 5 to 30 percent by weight of the mixture to a soil.

Abstract: An apparatus for performing a downhole operation includes a carrier configured to be disposed in a borehole in an earth formation, and a deformable component configured to be disposed in the borehole. The deformable component includes an elastomeric material and a barrier coating disposed on a surface of the elastomeric material. The barrier coating has properties configured to resist permeation of downhole gases into the elastomeric material at downhole temperatures.

Abstract: A packing apparatus including at least one sealing surface formed from a degradable material. The degradable material may be a biodegradable polymer such as polyglocolic acid, polylactic acid, or their copolymers. The body of the packing apparatus may also be formed from a degradable material. The packing apparatus may be deployed in a subterranean well and disposed of without milling.

Abstract: The swelling rate of a swelling packer element or a conforming foam screen material is accelerated with heat. Ferromagnetic particles or electrically conductive resins or polymers are interspersed in the swelling material and heat is generated at the particles by an inductive heater. A dielectric mandrel or base pipe can be used to focus the heating effect on the ferromagnetic particles or the electrically conductive resins or polymers in the sealing element or swelling foam screen element to focus the heating there without heating the base pipe. The heat accelerates the swelling process.

Abstract: A system for treating a formation of a borehole having casing has a sleeve, a motor, and a packer. The sleeve is disposed on the casing in the borehole and has a port communicating out of the sleeve. An insert disposed in the sleeve is movable in the sleeve from closed to opened position relative to the port. The motor is deployed in the casing with coiled tubing and is operable to impart rotation. The packer is operatively coupled to the motor. In response to the rotation imparted by the motor, the packer sets in the insert of the sleeve and moves the insert to the opened condition.

Abstract: A downhole tool for use in a well. A pumpable plug is used to urge bottom hole assemblies to a desired location in a well. The pumpable plug has a diameter greater than the maximum outer diameter of the casing in which the bottom hole assembly is to be located.

Abstract: The annular space around a tubular string has a shape memory material that is in a low profile configuration for run in. After the desired position is obtained and the annulus has cement delivered to fill the annular space, the shape memory device is triggered to revert to an original shape that spans the annulus to seal the tubular and the wellbore sides of the annular space against gas migration through the cement. The structures can have varying run in shapes and can also have original shapes that when the material is triggered will act to displace cement to enhance its compaction on the tubular or the wellbore wall. Combinations of shape memory alloys and polymers are also contemplated to enhance the seal against gas migration.

Abstract: A downhole tool for use in a well. The tool has a packer assembly and a pumpable plug associated with the packer assembly. The pumpable plug has a diameter greater than the maximum outer diameter of the packer assembly. The pumpable plug may be pumped through a casing having a diameter larger than that for which the packer assembly is designed and will urge the packer assembly through the large diameter casing into a smaller diameter casing for which the packer assembly is designed.

Abstract: A swellable packer for use in a subterranean well can include a seal element with a swellable material which contracts in response to temperature decrease, and a temperature compensator which applies increased force to the seal element in response to temperature decrease. A method of compensating for thermal contraction of a swellable material in a subterranean well can include a temperature of the swellable material increasing in response to installing the swellable material in the well, and a temperature compensator applying an increased force in response to a temperature decrease occurring after the temperature increasing step. A well tool for use in a subterranean well can include a swellable material and a temperature compensator which applies an increased force when the swellable material contracts.

Abstract: An apparatus positionable along a downhole string. The apparatus includes a flexible structure retained on a surface of the string in a first condition. The flexible structure movable by a flow to substantially fill an annular space between the string and a radially positioned structure in a second condition. A method of diverting fracturing treatments in a wellbore is also included.

Abstract: A sliding sleeve has a sensor that detects plugs (darts, balls, etc.) passing through the sleeves. A first insert on the sleeve can be hydraulically activated by the fluid pressure in the surrounding annulus once a preset number of plugs have passed through the sleeve. Movement of this first insert activates a catch on a second insert. Once the next plug is deployed, the catch engages it so that fluid pressure applied against the seated plug through the tubing string can moves the second insert. Once moved, the insert reveals port in the housing communicating the sleeve's bore with the surrounding annulus so an adjacent wellbore interval can be stimulated. The first insert may also be hydraulically activated after a preset time after a plug has passed through the sleeve. Several sleeves can be used together in various arrangements to treat multiple intervals of a wellbore.

Abstract: A method of forming a downhole apparatus comprises the steps of providing a body having a longitudinal axis and forming an expanding portion on the body from multiple layers of a partially or substantially cured material around the longitudinal axis of the body. The material is selected to increase in volume on exposure to at least one predetermined fluid, such as a wellbore fluid. Apparatuses formed by the method include wellbore packers.

Abstract: An apparatus and assembly create a seal in a wellbore around a cable or line. The assembly includes a longitudinal body and a swellable portion which comprises a material selected to increase in volume on exposure to at least one triggering fluid. The swellable portion has a formation open to the longitudinal surface of the body which provides a pathway for a cable or line to extend through the swellable portion, and an insert of swellable material. The insert may partly or fully enclose or encapsulate the cable or line. a formation which is open to an outer longitudinal surface of the body.

Abstract: An apparatus for controlling fluid flow in a borehole in an earth formation includes: a carrier configured to be deployed in the borehole; and a sealing device including at least one deformable element disposed at the carrier, the deformable element configured to have a first position and a second position, the first position forming a void in the sealing device configured to retain a flowable sealing material therein, the second position causing the void to be in flowable communication with leak paths formed in at least one of the sealing device and the borehole.

Abstract: An actuatable wellbore isolation assembly comprising a housing generally defining an axial flowbore and comprising a mandrel portion, a first end portion, and a second end portion, a radially expandable isolating member positioned circumferentially about a portion of the housing, a sliding sleeve circumferentially positioned about a portion of the mandrel of the cylindrical housing, the sliding sleeve being movable from, a first position in which the sliding sleeve retains the expandable isolating member in a narrower non-expanded conformation to a second position in which the sliding sleeve does not retain the expandable isolating member in the narrower non-expanded conformation, and an actuator assemblage configured to selectively allow movement of the sliding sleeve from the first position to the second position.

Abstract: A sealing and/or anchoring element for use in pipelines. The sealing and/or anchoring element includes at least one helical element disposed around a string section, with the helical element being configured so as to be able to expand radially towards an inner wall of the pipeline as the circumferential diameter thereof is increased.

Abstract: A flow tool has a sensor that detects plugs (darts, balls, etc.) passing through the tool. An actuator moves an insert in the tool once a preset number of plugs have passed through the tool. Movement of this insert reveals a catch on a sleeve in the tool. Once the next plug is deployed, the catch engages the plug on the sleeve so that fluid pressure applied against the seated plug through the tubing string can move the sleeve. Once moved, the sleeve reveals ports in the tool communicating the tool's bore with the surrounding annulus so an adjacent wellbore interval can be stimulated. The actuator can use a sensor detecting passage of the plugs through the tool. A spring disposed in the tool can flex near the sensor when a plug passes through the tool, and a counter can count the number of plugs that have passed.

Abstract: A wellhead assembly comprises an outer tubular wellhead member with a bore having an axis and a concentric inner seal surface, an inner tubular wellhead member for receiving an annular seal landed within the outer tubular wellhead member defining a seal pocket between them, the inner tubular member having a concentric outer seal surface, and a plurality of circumferentially extending, parallel wickers formed in at least one of the seal surfaces of the outer tubular and on the outer surface of the inner tubular. A profile of at least one of the wickers differs from a profile of at least some of the other wicker.

Abstract: A swelling element on a packer has a trough formed on a longitudinal axis. The control line or cable or conduit that needs to run along the string where the packer is mounted is first wrapped in a preferably non-swelling underlayment that can be a loose scroll or have its seam sealed. A swelling cover is placed over the underlayment using a seam that can be longitudinal or spiral to allow rapid deployment. The covering assembly for the control line or conduit is placed in the slot of the swelling element of the packer. The line or cable continues out opposed ends and can be secured to the tubular string with clamps. The control line can be covered with a swelling material and forced into a groove that runs the length of the packer swelling element.

Abstract: A well system can include a drill string having a drill bit at an end thereof, and a swellable seal exposed to fluid in an annulus external to the drill string. The swellable seal can include a swellable material which swells in response to the fluid comprising a predetermined activating agent. A method of preventing undesired release of fluid from a wellbore can include displacing a drill string through the wellbore, thereby drilling the wellbore, and installing in the wellbore a swellable seal which, in response to the fluid comprising a predetermined activating agent, reduces flow through an annulus formed radially between the drill string and the wellbore. Another well system can include a swellable seal carried into a wellbore on a drill string, with the swellable seal including a swellable material which swells in response to a fluid in the wellbore comprising a predetermined activating agent.

Abstract: A wellhead system comprising an outer wellhead housing, an inner wellhead member, and an annulus therebetween. The inner wellhead member, such as a casing hanger, is adapted to land in the outer wellhead housing. The outer wellhead housing may comprise a wickers formed in a hardened metal inlay. Alternatively, or in addition to the wickers formed in the outer wellhead housing, wickers may be formed in a hardened metal inlay in the inner wellhead member. An annular metal seal may be disposed in the annulus and driven into the wickers to seal the annulus between the inner wellhead member and the outer wellhead housing and to axially restrain the seal within the annulus.

Abstract: A swelling element on a packer has a trough formed on a longitudinal axis. The control line or cable or conduit that needs to run along the string where the packer is mounted is first wrapped in a preferably non-swelling underlayment that can be a loose scroll or have its seam sealed. A swelling cover is placed over the underlayment using a seam that can be longitudinal or spiral to allow rapid deployment. The covering assembly for the control line or conduit is placed in the slot of the swelling element of the packer. The line or cable continues out opposed ends and can be secured to the tubular string with clamps. The control line can be covered with a swelling material and forced into a groove that runs the length of the packer swelling element.

Abstract: An apparatus and assembly create a seal in a wellbore around a cable or line. The assembly includes a longitudinal body and a swellable portion which comprises a material selected to increase in volume on exposure to at least one triggering fluid. The swellable portion has a formation open to the longitudinal surface of the body which provides a pathway for a cable or line to extend through the swellable portion, and an insert of swellable material. The insert may partly or fully enclose or encapsulate the cable or line. a formation which is open to an outer longitudinal surface of the body.

Abstract: A downhole sealing element includes, a malleable member having at least one closed wall cavity therein positionable downhole in a gap defined between downhole members, and a chemical disposed within the at least one closed wall cavity. The malleable member is deformable to fill variations in a dimension of the gap and the chemical is reactive to form a nonflowable element.

Abstract: A method of controlling pressure in a wellbore can include placing a barrier substance in the wellbore while a fluid is present in the wellbore, and flowing another fluid into the wellbore while the first fluid and the barrier substance are in the wellbore. The first and second fluids may have different densities. Another method can include circulating a fluid through a tubular string and an annulus formed between the tubular string and the wellbore, then partially withdrawing the tubular string from the wellbore, then placing a barrier substance in the wellbore, then partially withdrawing the tubular string from the wellbore and then flowing another fluid into the wellbore. A well system can include at least two fluids in a wellbore, the fluids having different densities, and a barrier substance separating the fluids.

Abstract: A swelling element on a packer has a trough formed on a longitudinal axis. The control line or cable or conduit that needs to run along the string where the packer is mounted is first wrapped in a preferably non-swelling underlayment that can be a loose scroll or have its seam sealed. A swelling cover is placed over the underlayment using a seam that can be longitudinal or spiral to allow rapid deployment. The covering assembly for the control line or conduit is placed in the slot of the swelling element of the packer. The line or cable continues out opposed ends and can be secured to the tubular string with clamps. The control line can also be covered with a swelling material and forced into a groove that runs the length of the packer swelling element.

Abstract: A wellhead system comprising an outer wellhead housing, an inner wellhead member, and an annulus therebetween. The inner wellhead member, such as a casing hanger, is adapted to land in the outer wellhead housing. The outer wellhead housing may comprise a wickers formed in a hardened metal inlay. Alternatively, or in addition to the wickers formed in the outer wellhead housing, wickers may be formed in a hardened metal inlay in the inner wellhead member. An annular metal seal may be disposed in the annulus and driven into the wickers to seal the annulus between the inner wellhead member and the outer wellhead housing and to axially restrain the seal within the annulus.

Abstract: A top drive apparatus for a well drilling head comprises a top drive structure, a seal body and a plurality of resilient members. The top drive structure is configured for being fixedly attached to an upper end portion of a bearing assembly and having a seal-carrying portion. The seal body has a mounting portion and a wiper portion extending from the mounting portion. The mounting portion is slideably disposed within a groove of the seal-carrying portion of the top drive structure. The plurality of resilient members are disposed within the groove between the mounting portion of the seal body and the top drive structure such that the entire seal body is resiliently displaceable with respect to the top drive structure.

Abstract: A composition, apparatus and method of use of the composition and apparatus are described. In one aspect, a composition may include a shape-conforming material and nanoparticles sufficient to provide an elastic modulus of the composition that is greater than the elastic modulus of the shape-conforming material. A method of deploying an apparatus using such a composition may include placing the apparatus at a suitable location in a wellbore and activating the composition to deploy the apparatus in the wellbore.

Abstract: A downhole seal comprises a seal body having a swellable material configured to swell upon exposure to a swelling activator to establish a seal within a wellbore, and at least one protection element configured to protect at least a portion of the seal body when the downhole seal is translated within a wellbore. The protection element defines a reaming element configured to ream a portion of the wellbore while the downhole seal is translated therethrough.

Abstract: A method of isolating a section of a drilled bore containing a problem zone comprises: providing a section of tubing; locating the tubing in the section of the bore; and expanding the tubing and forming at least an outer portion of the tubing to conform to irregularities in the bore wall, to isolate the problem zone. The tubing may feature a formable outer section, and the expansion of the tubing may be achieved using a compliant rotary expander.

Abstract: An apparatus and method for radially expanding and plastically deforming a tubular member. The apparatus includes a support member, an expansion device coupled to the support member and at least one of a cutting device coupled to the support member, an actuator coupled to the support member, a sealing assembly, or a packer assembly coupled to the support member. The apparatus may further include a gripping device for coupling the tubular member to the support member. The expansion device may be used for radially expanding and plastically deforming the tubular member which may be coupled to the support member. The cutting device may be used for cutting the tubular member. The actuator may be used for displacing the expansion device relative to the support member. The sealing assembly may be used for sealing an annulus defined between the support member and the tubular member.

Abstract: Sealing devices such as packers comprise a metal foam material disposed on a surface. The metal foam material comprises an initial position comprising a plurality of pockets each having an initial volume and a compressed position in which at least one of the initial volumes of at least one of the plurality of pockets is reduced by compression of the metal foam material, thereby forming a seal. The seal may be formed directly between the metal foam material and a sealing surface such as an inner wall surface of a wellbore to divide an annulus of the wellbore. Alternatively, the seal may be at least partially formed between a sealing material disposed within one or more of the plurality of pockets that is extruded from at least one of the plurality of pockets during compression of the metal foam material.

Abstract: A composition, apparatus and method for use in a wellbore is described. In one aspect, a composition may include a shape-conforming material and nanoparticles sufficient to absorb a selected form of energy to heat the shape-conforming material to near or above a glass transition temperature. A method of deploying an apparatus using such a composition may include placing the apparatus at a suitable location in a wellbore and exposing the composition to the selected energy to deploy the apparatus in the wellbore.

Abstract: An expandable downhole tool features a mandrel that is expanded from within by a swage or other technique. The expansion of the mandrel advances an exterior ring or comparable slidably mounted object against an exterior sleeve that can be impervious or porous. The ring engages a ratchet mechanism to hold its position with respect to the mandrel as the swage advances through the mandrel and expands the ring and the exterior sleeve. The locking of the ring to the mandrel keeps the exterior sleeve from springing back longitudinally as the expansion is concluded.

Abstract: A staging tool arrangement for gas well production assistance, comprising an elongated staging tool having an elongated upper portion and an elongated lower portion. The upper portion has a sliding relationship with the lower portion thereof. A displaceable annular seal is arranged about the lower portion. A displaceable enclosure is arranged on the elongated lower portion so as to slidably expose and to slidably enclose the annular seal.

Abstract: Apparatuses for restricting fluid flow through a well conduit comprise a housing having a longitudinal bore and a reusable seat disposed within the bore. The seat comprises a slidable element, a fixed element, a plug element support member, a seat inner diameter, and a return member to urge the slidable element toward the run-in position. The plug element support member has a retracted position when the seat is in the run-in position and an extended position when the seat is in the set position. A plug element adapted to be disposed into the bore and landed on the seat to restrict fluid flow through the bore and the well conduit is used to move the plug element support member from the retracted position to the extended position, thereby providing support to the plug element landed on the seat.

Abstract: An apparatus is provided for use as a downhole tool or a component thereof for insertion into a wellbore. According to one aspect, the apparatus has a body having a chamber, wherein at least a portion of the body is radially expandable; and a water-swellable material in the chamber, wherein the water-swellable material is dissolvable in water. According to another aspect, the apparatus has a body having a chamber, wherein at least a portion of the body is radially expandable, and wherein at least a portion of the body is made with a material that is deteriorable by hydrolysis; and a water-swellable material in the chamber. According to a further aspect, the water-swellable material is dissolvable in water.

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: Methods and devices for retaining a packer element in a set condition within a wellbore and for preventing or minimizing extrusion of the packer element after setting. A packer device includes a plurality of deformable packer elements which radially surround a packer mandrel. One or more of the packer elements is contained against axial extrusion using a packer containment system. The packer containment system includes a flexible metal backup ring, which partially encases the packer element by substantially covering at least one axial side and a portion of the exterior radial surface of the packer element. The packer containment system also includes a plurality of annular support rings, or “petal rings” which have petal-shaped radial protuberances with slots between them.

Abstract: A wellhead seal assembly forms a metal-to-metal seal between the inner and outer wellhead members. A metal seal ring has inner and outer conical walls separated by a tapered slot. An energizing ring has inner and outer annular members that are separated by an annular cavity. When the energizing ring is moved further into the slot, the cavity width decreases but remains to provide a preloaded radial force to the seal ring.

Abstract: A packer includes a seal element and a piston. The piston compresses the seal element to form an annular seal in the well. A pressure wave, such as a pressure wave that is caused by a chemical reaction or the detonation of an explosive, is generated in the packer to at least partially assist an operation (the setting of a slip, setting of the seal element, etc.) of the packer. In some implementations, the chemical reaction or explosive detonation occurs in response to a predetermined movement of the piston.

Abstract: A packer device and methods of use for a packer within uncased wellbore to form a complete fluid seal. The packer device includes a central mandrel body that retains a plurality of nested, telescopic expanding elements that are moveable outwardly from the mandrel body. The mandrel body and expanding elements are surrounded by a load-distributing structure as well as a sealing element, which is typically comprised of elastomer. The packer device is hydraulically actuated to urge the expansion members radially outwardly against the load-distributing structure and the sealing element. Because there are a number of discrete expansion elements, the packer device is better able to create a fluid seal within an uncased borehole with surface irregularities.

Abstract: A wellhead seal unit for sealing a subsea oil and/or gas well at the wellhead. The unit comprises a sleeve, sealingly engaged to the workstring and to which, blow out preventer rams can engage. The unit allows the workstring to be rotated and reciprocated within the wellbore without releasing the seal. Methods of cleaning the sealed well and performing an inflow test are described.

Abstract: A packer system ready for downhole use includes an elastomer member, wherein the elastomer member is swellable or inflatable; and a temporary containment enclosing the elastomer member, wherein the temporary containment comprises a degradable material A method for deploying a swellable packer includes running a packer system into a well to a predetermined location, wherein the packer system comprises a swellable packer or an inflatable packer that is enclosed by a temporary containment, wherein the temporary containment comprises a degradable material; and degrading the degradable material of the temporary containment to set the swellable packer.