Abstract: A composite particle that incorporates a material and is designed to undergo a reaction and/or mechanical or chemical change with the environment to increase in volume. The composite particle can be combined with a constraining matrix to create an expandable particle upon reaction. These particles can be used in stimulating wells, including oil and gas reservoirs.

Abstract: A downhole tool deployable within a wellbore for controlling the supply of treatment to fluid to a reservoir is disclosed. The downhole tool includes a housing defining a passage and a port extending through the housing. The housing includes a seat that is configured for displacement into a plug-receiving position for receiving a plug that is deployed through the passage. A key profile for effecting actuation of the seat to the plug-receiving position in response to registration of the key profile with a matching key on the plug being deployed through the passage is provided. The downhole tool further includes a flow control member configured for displacement relative to the port in response to application of a sufficient net force effected by a fluid pressure differential that is created by supplying pressurized fluid to the passage while the plug is deployed on the seat.

Abstract: A seal system for downhole use in a surrounding tubular includes a seal support including a frusto-conical surface, and a seal member positioned about the seal support. The seal member includes a seal support member including first side having a recess, a second, opposing side, and a seal element coupled to the second, opposing side. The seal element is engageable with the surrounding tubular. An expansion limiter is arranged between the seal support and the seal member. The expansion limiter is positioned in the recess of the seal support member to limit axial movement of the seal member relative to the frusto-conical surface.

Abstract: The invention is directed to the interventionless activation of wellbore devices using dissolving and/or degrading and/or expanding structural materials. Engineered response materials, such as those that dissolve and/or degrade or expand upon exposure to specific environment, can be used to centralize a device in a wellbore.

Abstract: A downhole tool includes a sealing element configured to expand radially outwards to form a seal with a surrounding tubular, a cone defining a tapered surface, and a slips assembly comprising a plurality of slips. The slips assembly is receivable at least partially around the cone, such that moving the cone in an axial direction with respect to the slips assembly causes the plurality of slips to separate circumferentially apart. The tool also includes a backup member positionable at least partially around the tapered surface of the cone and positioned adjacent to the slips assembly. The backup member is configured to break as the cone is moved toward the plurality of slips, to prevent the sealing element from extruding between circumferentially-adjacent slips of the plurality of slips.

Abstract: A packer assembly includes an elongate body, at least one sealing element disposed about the elongate body, and a shoulder disposed about the elongate body and positioned axially adjacent the at least one sealing element. A cover sleeve is coupled to an outer surface of the shoulder. An annular support shoe has a jogged leg, a lever arm, and a fulcrum section that extends between and connects the jogged leg to the lever arm. The jogged leg is received within a gap defined between the cover sleeve and the shoulder, and the lever arm extends axially over a portion of the sealing element.

Abstract: A wellbore self-retrievable tool for conveying and releasing a load in a well, such as for wellbore abandonment, wherein the load is a resin for producing a set resin plug. The tool comprises: a floatation device; a load carrier, such as a payload tube; and a load release mechanism, the floatation device being configured to render the tool buoyant in a wellbore liquid.

Abstract: A wellbore isolation device includes an elongate body and a packer assembly disposed about the elongate body and including upper and lower sealing elements positioned axially between an upper shoulder and a lower shoulder, a spacer interposing the upper and lower sealing elements and having an annular body that provides an upper end, a lower end, and a recessed portion extending between the upper and lower ends. An upper cover sleeve is coupled to the upper shoulder, and a lower cover sleeve is coupled to the lower shoulder. An upper support shoe has a lever arm extending over the upper sealing element and a jogged leg received within a gap defined between the upper cover sleeve and shoulder. A lower support shoe has a lever arm extending over the lower sealing element and a jogged leg received within a gap defined between the lower cover sleeve and shoulder.

Abstract: A system includes a hanger running tool that has a first lock ring configured to secure the hanger running tool to a hanger when a first axial force is applied to the hanger running tool and a tool body configured to direct a push ring of the hanger in an axial direction when a second axial force is applied to the hanger running tool, where the push ring is configured to direct a second lock ring of the hanger radially outward toward a tubular, and where the hanger running tool is configured to secure the hanger to the tubular without rotating the hanger running tool.

Abstract: A tool management system includes a plurality of individual tool retention units that are in electronic communication with a central webserver. Each tool retention unit is designed to independently monitor a designated toolset and transmit tool use data to the webserver. The data compiled by the webserver can be routinely evaluated to ensure proper accountability of all tools within a particular workspace. Due to the autonomous nature of each unit, subsets of tools within a larger monitored collection can be added, removed or replaced without disruption of monitoring amongst the remainder of tools. In one embodiment, a tool retention unit is constructed as a chest comprising a plurality of individual, swappable drawers housed within a common frame. In use, each drawer is provided with a controller that is configured to monitor its designated toolset and transmit any tool-related data to a main controller in communication with the webserver.

Abstract: Frangible components like shear pins, rupture disks, retainer rings, and shear rings of downhole tools (e.g., frac plugs, sliding sleeves, darts, packers, expansion joints, valves, and tool-conveyance coupling apparatuses) may be composed of a degradable material that degrades in a wellbore environment at a desired time during the performance of a subterranean formation operation. For example, a tool string may include a conveyance or top adapter sub threadably coupled to a first end of a stinger; a wellbore tool coupled to the stinger via a coupling at a second end opposing the first end of the stinger, wherein the coupling comprises a frangible, degradable shear pin and a frangible, degradable shear ring, wherein the frangible, degradable shear pin and the frangible, degradable shear ring independently comprise a degradable metal alloy selected from the group consisting of a magnesium alloy, an aluminum alloy, and any combination thereof.

Abstract: A well system for recovering hydrocarbons such as heavy crude oil from subsurface reservoirs is provided. The well system includes a single continuous wellbore extending from a surface entry opening to a surface exit opening. A substantially horizontal section of the wellbore is formed within the subsurface reservoir. In one embodiment, a plurality of heater-lifter units are movably disposed within the substantially horizontal wellbore section. The heater-lifter units are configured to apply heat to subsurface reservoir surrounding the substantially horizontal wellbore section to mobilize the hydrocarbons. A lifting mechanism is configured to move the heater-lifter units in bidirectional manner within the continuous wellbore so that the produced low viscosity hydrocarbons are mechanically lifted to the surface.

Abstract: A packing system comprising an anti-extrusion plugging system is described. The system includes a plugging tool and an elastomeric packing element carried by the plugging tool. Both the tool and the packing element are independently coupled to different anti-extrusion assemblies that work together to prevent the elastomeric material from extruding.

Abstract: A method is provided for multistage isolation and fluid treatment of a borehole, in which a first frac valve tool and a second frac valve tool are provided, a first packer is mounted downstream from the first frac valve tool, a second packer is mounted between the first frac valve tool and the second frac valve tool, a third packer is mounted upstream from the second frac valve tool, at least one of the first, second and third packers being a hydraulic set packer having a single packing element, the first frac valve tool being moveable between a closed and an open position, the second frac valve tool moveable between a closed and an open position; running the liner into a wellbore; hydraulically setting the single element packers; conveying means for moving the first frac valve tool to the open position; and forcing stimulation fluid out through the first frac sleeve tool.

Abstract: Provided are systems and methods for thru-tubing completion including a sub-surface completion unit (SCU) system including a SCU wireless transceiver for communicating with a surface control system of a well by way of wireless communication with a down-hole wireless transceiver disposed in a wellbore of the well, one or more SCU anchoring seals having an un-deployed position (enabling the SCU to pass through production tubing disposed in the wellbore of the well) and a deployed position (to seal against a wall of the target zone of the open-hole portion of the wellbore to provide zonal isolation between adjacent regions in the wellbore) and one or more SCU centralizers having an un-deployed position (enabling the SCU to pass through the production tubing disposed in the wellbore of the well) and a deployed position (to position the SCU in the target zone of the open-hole portion of the wellbore).

Abstract: Provided are systems and methods for thru-tubing completion including a sub-surface completion unit (SCU) system including a SCU wireless transceiver for communicating with a surface control system of a well by way of wireless communication with a down-hole wireless transceiver disposed in a wellbore of the well, one or more SCU anchoring seals having an un-deployed position (enabling the SCU to pass through production tubing disposed in the wellbore of the well) and a deployed position (to seal against a wall of the target zone of the open-hole portion of the wellbore to provide zonal isolation between adjacent regions in the wellbore) and one or more SCU centralizers having an un-deployed position (enabling the SCU to pass through the production tubing disposed in the wellbore of the well) and a deployed position (to position the SCU in the target zone of the open-hole portion of the wellbore).

Abstract: A system including a downhole device coupled to a pressure balanced setting tool. The setting tool may be pressure balanced to lock a setting piston in place as the system is deployed into a well. That is, in spite of downhole well pressures, no substantial differential may emerge between the setting piston and the annular space of the well adjacent the system. Thus, the setting piston may remain locked in place until triggered for setting. This may include breaching a rupture disc of another piston to disrupt hydraulic communication between the setting piston and the annular space. This allows subsequent triggering, for example through another breach of a rupture disc defining a volumetric chamber, to take place in a manner that allows stroking of the setting piston. In this way, the setting tool may be utilized to achieve setting of the downhole device.

Abstract: Methods of sealing a hydrocarbon well containing a control line. The hydrocarbon well includes a casing string extending within a wellbore and defining a casing conduit, production tubing extending within the casing conduit and defining a tubing conduit, and at least one control line extending within an annular space. The methods include fluidly isolating a downhole region of the tubing conduit from an uphole region of the tubing conduit and actuating a shape charge device. The actuating includes forming a plurality of openings within the production tubing and severing the at least one control line. The methods also include positioning a diversion structure within the uphole region of the tubing conduit, pumping a sealing material into the annular space at the sealing material injection region, and curing the sealing material to form a fluid seal that extends within the annular space and the uphole region of the tubing conduit.

Abstract: A method includes providing a retrievable plug assembly at a surface of an oil or gas well, the plug assembly having a seal element that has an original outer diameter. The method also includes stretching the seal element so that the outer diameter is less than the original outer diameter and then placing the plug assembly between first and second zones formed within the tubing string. The method also includes removing any tensile axial load on the seal element so that it shrinks back towards its original outer diameter while positioned between the first and second zones. The method also includes compressing the seal element so that the seal element sealingly engages an inner surface of the tubing string to isolate the first zone from the second zone.

Abstract: A technique facilitates control over at least one flow control assembly position to control fluid with respect to a tubing string. The flow control assembly is disposed along the tubing string and comprises a flow control valve and a motor to control the operational position of the flow control valve. The flow control valve may comprise a plunger and a seal system to provide a seal between the plunger and a surrounding structure. Additionally, the flow control valve comprises a pressure balanced system. The pressure balanced system serves to balance pressure acting on the plunger such that the motor is able to move the plunger by simply overcoming friction of the seal system without overcoming a pressure differential otherwise acting on the plunger.

Abstract: A bottom hole assembly having a packing element, a lower cone disposed below the packing element, and a lower slip disposed below the packing element. The bottom hole assembly also includes a setting tool removably attached to the plug, the setting tool having a mandrel and a setting sleeve connected to the mandrel. Also, a method for sealing a well including disposing a bottom hole assembly having a plug and a removable setting tool in a well. The method further includes applying pressure to a setting sleeve, contacting an inner diameter of the well with a lower slip, locking the lower slip against an inner diameter of the well, shearing a shear mechanism, disconnecting the removable setting tool from the well, dropping a ball into the well, contacting the ball with the packing element, and separating the well into at least two sections.

Abstract: A millable bridge plug system includes a mandrel having an upper portion and a lower portion with an interlock, a shearing member attached at the upper portion, a sealing member, ring members, cone assemblies, slip devices, and an interlocking drill member at a lower portion of the mandrel. The interlock of the mandrel and the interlocking drill member are modular so that one bridge plug interchangeably connects to another bridge plug. The interlocks are compatible with interlocking drill members of other bridge plugs and vice versa. The interlocking drill member has rotatable cutting blades to drill through sand and other debris between the interlocking drill member and the next bridge plug to be removed. A milling unit can drive rotation of the interlocking drill member to reach the next bridge plug for removal, until the interlocking drill member engages the adjacent interlock of the next bridge plug to be removed.

Abstract: A downhole tool and a tool assembly, of which the downhole tool includes an expandable sleeve defining a bore extending axially therethrough, a first swage positioned at least partially within the bore and including a valve seat configured to receive an obstructing member, such that the obstructing member and the first swage substantially prevent fluid communication through the bore when the obstructing member is seated in the valve seat, and a second swage positioned at least partially within the bore. The first and second swages are configured to move toward one another in the bore, such that the first and second swages deform end portions of the expandable sleeve radially outwards and into engagement with a surrounding tubular, and the expandable sleeve, in an expanded configuration in which the end portions engage the surrounding tubular, defines an unexpanded portion between the expanded end portions.

Abstract: A field created integral electrically isolated centralizer and swell packer system for wellbore tubulars having in series over the wellbore tubular, a first end ring, a swell packer portion over a first and second primer optionally with cured resin, a second end ring, wherein the end rings inhibit axial movement of the swell packer portion. Integral with the swell packer portion an electrically isolating centralizer; a cured resin bonded to the wellbore tubular filling all hollow spaces of the centralizer portion integrally forming a high strength bond, while excluding bonding to the first and second end rings, the cured resin configured to cure to a hardness of at least 50 shore A and withstand temperatures and pressures within a wellbore for at least twenty-four hours without melting, while specifically excluding a sand screen.

Abstract: A downhole tool for controlling the flow of a fluid in a wellbore comprises: an annular body having a flow passage therethrough; a frustoconical element disposed about the annular body; a sealing element carried on the annular body and configured to engage a portion of the frustoconical element; and a bottom sub disposed about the annular body; wherein at least one of the frustoconical element and the bottom sub comprise a polymeric composite that includes: a polymer component comprising one or more of the following: a poly(ether ether ketone); or an epoxy, and a filler crosslinked with the polymer component.

Abstract: A method employs sand jetting to perforate a wellbore casing at various locations using sandjetting, to further flush/clean the wellbore in the region of the tool, and to further frac the formation, all without removing the tool from the wellbore. An uphole and downhole packer is provided, uphole of which a sand jet port is provided for jetting a fluid stream containing sand. Locking jaw members and a ‘j’ slot subassembly, downhole of both the jet port and frac port are together used to set and unset the tool in the wellbore for the fracking operation. A slidable sleeve is utilized to open and close the jet port. A piston member is provided to set the uphole packer. A selectively openable and closeable bypass-port is provided to assist in moving the tool uphole during the perforating and fracking process.

Abstract: A wellhead assembly includes an outer wellhead member having a bore and an inner wellhead member located in the bore, defining an annular pocket between the outer and inner wellhead members. A sealing assembly is located within the annular pocket, the sealing assembly having an annular seal and an energizing ring. The energizing ring engages inner and outer legs of the annular seal to push the inner and outer legs into sealing engagement with the inner and outer wellhead members. A retainer nut is threadingly attached to the free end of the outer leg of the sealing assembly. Mating grooves are located on one of an inner diameter of the retainer nut and an outer diameter of the energizing ring and mating protrusions located on the other. The mating protrusions mate with the mating grooves to prevent relative axial movement between the energizing ring and the annular seal.

Abstract: A ball seat is expanded and held in place within a casing using an expander. The ball seat includes one or more gripping elements and one or more sealing elements. An apparatus for expandably installing a ball seat in a casing includes a ball seat having one or more gripping elements and one or more elastomeric sealing elements disposed on an exterior of an expandable sleeve portion of the ball seat that is expanded by pulling an expander into the bore of the expandable sleeve portion of the ball seat. A mechanical fuse is predisposed to fail at a level of force sufficient to move the expander to the installed position. Failure of the fuse and further movement of a pulling mandrel positions a channel on the mandrel into alignment with a distal end of the collet, enabling the collet to collapse and pass through the expander for removal.

Abstract: A method of forming multiple inclusions into a subterranean formation can include initiating the inclusions into the formation, the inclusions extending outwardly in respective multiple azimuthal orientations from a casing section, and flowing fluid into each of the inclusions individually, thereby extending the inclusions into the formation one at a time. A system for initiating inclusions outwardly into a subterranean formation from a wellbore can include a casing section having multiple flow channels therein, each of the flow channels being in communication with a respective one of multiple openings formed between adjacent pairs of circumferentially extendable longitudinally extending portions of the casing section. Another system can include a casing section, and an injection tool which engages the casing section and selectively directs fluid into each of the inclusions individually, whereby the inclusions are extended into the formation one at a time.

Abstract: A wellhead assembly includes an outer wellhead member, the outer wellhead member having a locking profile on an inner surface. An inner tubular wellhead member lands within the outer wellhead member, defining a seal pocket between the inner tubular wellhead member and the outer wellhead member. A seal ring is located in the seal pocket. A seal energizing ring urges the seal ring into sealing engagement with the outer wellhead member and the inner tubular wellhead member. An annular lock ring is carried with the seal energizing ring and engages the locking profile. A lock energizing ring retains the annular lock ring in engagement with the locking profile.

Abstract: A controlled swell-rate swellable packer comprises a mandrel; a sealing element, and a jacket. The sealing element is disposed about at least a portion of the mandrel, and the jacket covers at least a portion of an outer surface of the sealing element. The jacket is configured to substantially prevent fluid communication between a fluid disposed outside of the jacket and the portion of the outer surface of the sealing element covered by the jacket.

Abstract: The present invention provides a system and method for measuring downhole parameters within a SAGD system. The system includes one or more downhole sensors that are positioned at least within a heel portion of a long production tubing string. Positioning the system within the long production tubing string avoids pulling the sensors to surface each time that the short production tubing string is worked over. The system comprises a ported sub that is threadably connected as part of the long production tubing string. When the tubing string is in a desired position, the ported sub is near the heel portion of the production well. The system further comprises a pumpable sleeve that carries the instrument line downhole into the ported sub. When the pumpable sleeve lands in the ported sub, the instrument line detects information regarding downhole parameters at the heel portion of the production well.

Abstract: Embodiments of the present disclosure are directed towards a downhole slot cutter. The downhole slot cutter a housing of the downhole slot cutter configured to be inserted into a tubular positioned within a wellbore, and a plurality of dies supported by the housing, wherein the plurality of dies is configured to extend radially outward from the housing.

Abstract: Methods and compositions for a treatment fluid composition are disclosed for use within a subterranean formation, comprising: a degradable diverting agent, and a Schiff base comprising a degradation accelerator. The treatment fluid may be introduced into a formation and the Schiff base allowed to hydrolytically release the degradation accelerator, allowing the degradation accelerator to degrade the degradable diverting agent.

Abstract: An expansion tool includes a housing and a hydraulic power section for stroking an expander on a pulling mandrel through a bore of an expandable liner, the expansion tool including a ratcheting reaction assembly, having a ratchet rack and a ratcheting component thereon, that engages a proximal end of the liner to prevent axial movement of the liner as the expander is drawn through a portion of the bore of the liner to expand the liner. The ratcheting reaction assembly remains engaged with the proximal end of the liner as the housing is repositioned uphole to permit staged expansion of the liner using the expander. The expansion tool improves sealing and structure integrity of the expanded liner within the casing by maintaining the liner in a position throughout the staged expansion process.

Abstract: A packer can include an end ring positioned proximate a seal element on a base pipe, and a gripping device positioned in an annular space between the end ring and the base pipe, the gripping device comprising a polymer composition material. A method of constructing a packer can include positioning an end ring on a base pipe, and then injecting a gripping device into an annular space between the end ring and the base pipe, whereby the gripping device grips the base pipe. Another method of constructing a packer can include positioning a gripping device in an annular space between an end ring and a base pipe, so that the gripping device grips the base pipe, the gripping device comprising a polymer composition material.

Abstract: A controlled swell-rate swellable packer comprises a mandrel; a sealing element, and a jacket. The sealing element is disposed about at least a portion of the mandrel, and the jacket covers at least a portion of an outer surface of the sealing element. The jacket is configured to substantially prevent fluid communication between a fluid disposed outside of the jacket and the portion of the outer surface of the sealing element covered by the jacket.

Abstract: A packer for use in a wellbore includes a packer mandrel. First and second pistons are slidably disposed about the packer mandrel defining first and second chambers therewith. An activation assembly initially prevents movement of the first piston. A release assembly initially prevents movement of the second piston. First and second seal assemblies are disposed about the packer mandrel such that actuation of the activation assembly allows a force generated by a pressure difference between the wellbore and the first chamber to shift the first piston in a first direction toward the first seal assembly to radially expand the first seal assembly and to actuate the release assembly and, actuation of the release assembly allows a force generated by a pressure difference between the wellbore and the second chamber to shift the second piston in the first direction toward the second seal assembly to radially expand the second seal assembly.

Abstract: A plug for well drilling process comprising: (a) a mandrel formed from a degradable material; (b) a pair of rings placed on an outer peripheral surface existing in the orthogonal to an axial direction of the mandrel, at least one of the rings being formed from a degradable material; and (c) at least one diameter-expandable circular rubber member placed at a position between the pair of rings on the outer peripheral surface existing in the orthogonal to the axial direction of the mandrel; the percentage of mass loss in the degradable material after immersion for 72 hours in water at a temperature of 150° C. preferably being from 5 to 100%; and a well drilling method comprising the step of plugging well hole using the plug for well drilling process, wherein part or all of the plug for well drilling process degrades after the plugging.

Abstract: The present invention relates to a millable plugging device for use in a well pipe. The device includes an inner mandrel and an outer housing provided radially outside at least parts of the inner mandrel. A sealing assembly is provided radially outside the inner mandrel, where the sealing assembly is configured to be brought from a run state to a set state by a relative axial displacement between the inner mandrel and the outer housing. The millable plugging device has a first center axis and the second mandrel section has a second center axis which is displaced parallel in relation to the first center axis. Rotation of the inner mandrel in the set state is bringing a third mandrel section of the mandrel to a locked state, in which further rotation of the inner mandrel is prevented.

Abstract: Certain aspects of the present disclosure are directed to tools actuated by pipe swell. A downhole assembly for a wellbore may be provided. The downhole assembly can include a first sleeve and a second sleeve. The first sleeve can expand from a first position to a second position in response to a first pressure applied to the first sleeve. The first sleeve can contract to the first position in response to a cessation of the first pressure. The second sleeve can be positioned adjacent to the first sleeve to define a swell chamber. The swell chamber can actuate a downhole tool by a pressure stored in the swell chamber by the expansion of the first sleeve.

Abstract: A backup ring design for a packer sealing element features a folding shape where opposed legs are pushed together for extension in a radial direction toward the surrounding tubular to span the extrusion gap. The design can use a V-shape where the vertex is toward the mandrel and the legs are oriented toward the surrounding tubular. The legs in that instance can be thicker than the vertex thickness to aid in folding while providing enhanced strength at the surrounding tubular where shear forces apply as a result of seal compression against the surrounding tubular. The design features a single or multiple vertices that are similarly aligned or alternatingly oppositely aligned to create a zigzag shape in cross-section. Material selection can vary with the expected service conditions.

Abstract: A wellbore servicing tool is disclosed, which includes a packer element that exhibits radial expansion upon being longitudinally compressed, wherein the packer element is movably positioned about a mandrel generally downward relative to an upper housing, wherein the wellbore servicing tool is selectively transitionable from an unset configuration to a set configuration or from the unset configuration to the set configuration upon rotation of the upper housing with respect to the mandrel.

Abstract: A swellable packer can include a base pipe, at least one swellable seal on the base pipe, the seal comprising a swellable material, and at least one other swellable seal on the base pipe, the other swellable seal comprising another swellable material, and the swellable materials being different materials. Another swellable packer can include at least one swellable seal, the seal comprising a swellable material, and at least one other swellable seal, the other swellable seal comprising another swellable material, and wherein one swellable seal displaces the other swellable seal into contact with a well surface, in response to contact between the one swellable seal and an activating agent.

Abstract: Well tools including valves operable by low electrical input. One well tool includes a valve which controls fluid communication between pressure regions in a well, the valve including a rotatable member which is biased to rotate, and a brake or clutch which prevents rotation of the member. Another valve includes a barrier which separates reactants, with the valve being operable in response to the barrier being opened and the reactants thereby reacting with each other. Yet another valve includes a barrier which separates the pressure regions, and a control circuit which heats the barrier to a weakened state. Another valve includes a member displaceable between open and closed positions, a restraining device which resists displacement of the member, and a control device which degrades or deactivates the restraining device and thereby permits the member to displace between its open and closed positions, in response to receipt of a predetermined signal.

Abstract: A packer for a well comprises a seal element and seal setting apparatus. The seal setting apparatus is moveable with respect to the seal element in a setting direction to apply a setting force to the seal element to move the seal element from a run-in configuration to a set configuration in which the seal element forms a contact seal with a conduit wall. The packer is arranged such that, in the set configuration, a pressure differential across the packer, which creates a force in the setting direction, will increase the setting force applied by the seal setting apparatus to the seal element to maintain the seal.

Abstract: A fold back ring for a swell packer is disclosed. A swell packer has a support member, a swellable element coupled to the support member, and a fold back ring coupled to the support member and engaging the swellable element. The fold back ring is sized and positioned such that when the swellable element swells, the fold back ring flexes outwardly and is caught between the swellable element and the interior surface of the well. The fold back ring therefore forms a barrier against extrusion of the swellable element.

Abstract: Embodiments of the present disclosure are directed toward a seal assembly comprising a main body comprising a production fluid port configured to align with a production fluid bore of a tubing spool of a mineral extraction system, a first annular seal supported by the main body and disposed on a first side of the production fluid port, and a second annular seal supported by the main body and disposed on a second side of the production fluid port, wherein the seal assembly is configured to be disposed in an annular region between a hanger and the tubing spool of the mineral extraction system, the first annular seal and the second annular seal are configured to isolate the production fluid port from the annular region, and the seal assembly is configured to be removed from the tubing spool without the hanger.

Abstract: A swellable packer with enhanced sealing capability. A packer assembly includes multiple seal elements, each seal element being swellable downhole, each seal element having at least one face inclined relative to a longitudinal axis of the assembly, and the inclined faces of adjacent seal elements contacting each other. A method of constructing a packer assembly having a desired differential pressure sealing capability includes: providing a base pipe and multiple seal elements, each seal element being swellable in a downhole environment, and each seal element having a predetermined differential pressure sealing capability less than the desired sealing capability; and after the desired sealing capability is determined, installing a selected number of the seal elements on the base pipe, so that the combined predetermined differential pressure sealing capabilities of the installed seal elements is at least as great as the desired sealing capability.

Abstract: A subterranean wellbore assembly includes an outer cylindrical wall and an inner cylindrical wall cooperatively defining an annular space. A seal assembly is disposed within the annular space. The seal assembly includes chevron seals. Each chevron seal includes a central portion and two axially and radially extending wing portions. Chevron seals may be of polymeric PEEK material or of nickel based material. Other seal assemblies may be arranged in the annular space in place of the seal assembly.