Abstract: A packer assembly for use with a subterranean well can include a base pipe, at least one ring-shaped reinforcement plate which encircles the base pipe, and at least one swellable seal material which longitudinally straddles the reinforcement plate on the base pipe. A method of constructing a packer assembly can include securing at least one ring-shaped reinforcement plate to a base pipe, the plate encircling the base pipe, and then positioning at least one swellable seal material on the base pipe, the swellable seal material straddling the reinforcement plate. Another method of constructing a packer assembly can include securing at least one ring-shaped reinforcement plate to at least one swellable seal material, and then positioning the plate and the swellable seal material on a base pipe.

Abstract: Various embodiments disclosed relate to a viscosifier polymer for treatment of a subterranean formation, and methods and systems including the same. In various embodiments, the present invention provides a method of treating a subterranean formation. The method can include obtaining or providing a composition including a viscosifier polymer. The method can also include placing the composition in a subterranean formation.

Abstract: A downhole system including a tubular having a wall with at least one port there through. At least one member arranged to cover the at least one port in a compressed condition thereof. Configured to at least partially displace cement pumped on an exterior of the tubular in a radially expanded condition of the at least one member. Also included is a method of non-ballistically opening ports in a tubular of a downhole system.

Abstract: Apparatus and method for completing a wellbore including providing a packer having an inner mandrel, alternate flow channels along the inner mandrel, and a sealing element external to the inner mandrel, including connecting packer to tubular body, then running the packer and connected tubular body into the wellbore. In one aspect, the packer and connected tubular body may be placed along an open-hole portion of the wellbore. Tubular body may be a sand screen, with the sand screen comprising a base pipe, a surrounding filter medium, and alternate flow channels. The method includes setting a packer and injecting a gravel slurry into an annular region formed between the tubular body and the surrounding wellbore, and then further injecting the gravel slurry through the alternate flow channels to allow the gravel slurry to at least partially bypass sealing element of the packer.

Abstract: A packoff and a locking assembly installed in a bore of a wellhead component are provided. In one embodiment, a packoff includes inner and outer annular seals and an energizing ring shaped to be wedged between the inner and outer annular seals so as to apply a radially inward biasing force on the inner annular seal and a radially outward biasing force on the outer annular seal. In another embodiment, a locking assembly includes a lock ring that extends into a recess in a wall of the bore of the wellhead component and an actuator radially disposed between an inner component within the bore and the lock ring to retain the lock ring within the recess. The actuator can have an interference fit with the inner component to inhibit movement of the actuator between the lock ring and the inner component. Additional systems, devices, and methods are also disclosed.

Abstract: A hydraulic setting tool. The tool is configured to allow hydraulic setting of a bridge plug, packer or other radially expansive mechanical well isolation mechanism. Wireline or slickline deployment may be utilized. In either case, parameters of the setting application may be recorded. In the case of wireline deployment such parameters and downhole data may be monitored in real-time allowing an operator to make intelligent setting application adjustments as necessary.

Abstract: A secondary barrier for use in conjunction with an isolation device in a portion of a non-vertical wellbore comprises: a swellable material, wherein the swellable material: (A) has dimensions such that, prior to swelling, the secondary barrier is capable of being placed into the portion of the non-vertical wellbore, and (B) fills a void within the portion of the non-vertical wellbore, wherein the swellable material fills the void after the swelling of at least a portion of the swellable material has occurred, wherein the secondary barrier is positioned adjacent to the isolation device in the portion of the non-vertical wellbore. A method of creating a secondary barrier comprises: introducing the secondary barrier into the portion of the non-vertical wellbore; and contacting or allowing the swellable material to come in contact with the swelling fluid or the increase in temperature.

Abstract: Backup rings are disposed on opposed sides of a sealing element. The backup rings are initially bow shaped in the run in position. Opposed ends of the bow shape are brought together to extend the extrusion barriers and compress the sealing element. The relative axial movement that brings the opposed ends of the bow shape together results in radially extending the bow shape. The bow shape is reformed into a teardrop shape that extends radially beyond a pinch location created by relative axial movement of adjacent support members coming closer together. A sealing element extends radially during the deployment of the extrusion barriers and is contained between them. The extension of the extrusion barriers allows conformance to surface irregularities in the surrounding tubular or wellbore wall.

Abstract: Methods and apparatus for conducting fracturing operations using a wellbore fracturing assembly are described. The assembly may be mechanically set and released from a wellbore using a coiled tubing string. The assembly may include a pair of spaced apart packers for straddling the area of interest, an injection port disposed between the packers for injecting fracturing fluid into the area of interest, and an anchor for securing the assembly in the wellbore. At least one of the packers includes a pressure balanced mandrel. After conducting the fracturing operation, the assembly may be relocated to another area of interest to conduct another fracturing operation.

Abstract: Expandable reamers comprise a housing and at least one blade supported by the housing. The at least one blade is movable between an extended position and a retracted position. The at least one blade is in the retracted position when a travel sleeve is in a first sleeve position and a trigger sleeve is in an unobstructed position. The at least one blade is movable to the extended position when the travel sleeve is in a second sleeve position and the trigger sleeve is in the unobstructed position. The at least one blade is in the retracted position when the travel sleeve is in the second sleeve position and the trigger sleeve is in an obstructed position.

Abstract: A well isolation includes a radially expandable sealing element that engages an interior wall of the wellbore tubular and a radially expandable expansion cone in telescopic relationship with the sealing element. The expansion cone expands the sealing element and a swage telescopically engages and expands the expansion cone.

Abstract: A millable bridge plug system includes a mandrel, a sealing member, ring members, cone assemblies, and slip devices. The sealing member, ring members, cone assemblies and slip devices are positioned on and around the mandrel. Ring members abut against an upper end and a lower end of the sealing member. The other sides of the ring members abut against the cone assemblies, and the cone assemblies engage respective slip devices. The cone assemblies have surface interfaces contacting each of the slip devices so that pressure from the cone assemblies is exerted according to contact along the surface interfaces. Each surface interface can have a curvature or be a single radiused surface. Coordination of the surface interfaces control pressure to insure improved fixed positioning in the wellbore.

Abstract: A method for re-calibrating installed downhole sensors used in hydrocarbon wells by the application of a calibration string inserted in the wells and deployed in close proximity to the installed downhole sensor.

Abstract: A sealing system includes, a body, at least one swellable member in operable communication with the body configured to swell into sealing engagement with a structure proximate the body, and at least one shape memory member in operable communication with the body and configured to increase at least one dimension thereof in response to exposure to transition stimulus to cause the at least one shape memory member to contact both the body and the structure, the at least one shape memory member also configured to support the at least one swellable member against pressure urging it to move relative to at least one of the body and the structure.

Abstract: A system and method is provided for hydraulically presetting a metal-to-metal seal, which may be installed in an annular space between wellhead components. A hydraulic running tool may be landed on a first wellhead component and coupled to a second wellhead component, for example, via a hydraulic or mechanical coupling assembly. Fluid pressure may then be applied to the hydraulic running tool to move the components axially together, thereby setting the metal-to-metal seal (i.e., axially compressing and radially expanding the seal). A coupling may secure the wellhead components in place relative to one another, while fluid pressure is being applied so that the metal-to-metal seal remains in the set position after the hydraulic tool is removed.

Abstract: The method allows a pressure test of a string with external packers without having the packer setting apparatus exposed to tubing pressure so that at a later time and at a lower pressure than the pressure test pressure, the external packers can be set with annulus pressure opened to a piston that references a low pressure chamber. The packers can be set in any desired order. Thereafter, a circulation sub can be triggered to open to allow the fracking to start. Fracking each interval beyond the first in an uphole direction can be accomplished with pumping ever increasing balls to seats associated with sliding sleeves to open the sleeves in order. In cemented completions, after a pressure test, a ported sub can open on a timer or other signal to allow pumping a combination of a bridge plug and a perforating gun to the desired location.

Abstract: A well tool for sealing against a wall of well includes an elongate mandrel. A seal assembly encircles the mandrel and can change between an unset state and an axially compressed set state. The seal assembly includes an annular elastomer seal element configured to radially deform into contact with the wall of the well in the set state. An annular anti-extrusion ring is included to compress the seal element and form a containing space with a garter spring embedded in the seal element. The garter spring is embedded in the seal element adjacent the axial end of the seal element and configured to span the gap between the anti-extrusion ring and the wall of the well in the set state. The containing space can prevent the seal element from excessive deformation.

Abstract: A bridge plug tool for use in a well, comprising: a tool body (70); a hollow mandrel (26) extending through the tool body, the mandrel having a removable plug (32) in an upper region (37) to prevent from of fluids through the mandrel, the plug comprising a plug locking member (40) that is axially movable between a first position in which it locks the plug inside the mandrel and a second position in which the plug is released from the mandrel and can be removed; a setting sleeve (16) positioned on the tool body; a packer module (18) located below the setting sleeve; an anchor module (20) located blow the packer module; and an end fitting located below the anchor module; wherein the mandrel extends through the sleeve, packer module and anchor module to the end fitting; and wherein the end fitting comprises a first part that is configured for engagement with the mandrel, and a second part that is releasably connected to the first part and moveable between a connected position in which the second part holds the f

Abstract: A rotating control device comprises an outer housing having a bore for receiving a tubular member. An inner housing and a piston assembly are rotatably disposed within the outer housing. An annular sealing assembly is disposed between the piston assembly and the inner housing so that axial movement of the piston assembly moves the annular sealing assembly into sealing engagement with the inner housing and the tubular member. A plurality of bearings is disposed between the inner housing and the outer housing. At least one of the plurality of bearings is a hydrodynamic journal bearing.

Abstract: A system and method for replacing equipment at a wellsite is provided. The wellsite has a subsea stripper installed proximate a subsea borehole. The system has a conveyance for delivering a BHA into the subsea borehole. The system has a subsea stripper having a central bore for passing the conveyance and the BHA therethrough, and at least one actuator connected to the subsea stripper for actuating a packer whereby the wellbore is sealed. The system has at least one replaceable seal assembly for installation within the stripper. The replaceable seal assembly has at least one packer extendable within the subsea stripper to form a seal thereabout and at least one locator sleeve for positioning the seal assembly in an install position within the subsea stripper. The replaceable seal assembly has a frangible member for connecting the seal assembly to the conveyance prior to deployment in the subsea stripper.

Abstract: A cap for sealing a wellhead assembly of a subterranean well and suspending well assets (e.g., tubing, rods, etc.) therefrom within the well to facilitate production at the well after a period of abandonment. For instance, a decompletion process may be performed on a particular well to be temporarily abandoned which may include disconnecting a pumpjack (e.g., horsehead unit, pumping unit, etc.) from a wellhead of the well, breaking (e.g., disconnecting) the wellhead at the first flange (e.g., closest to ground level) to leave a casing head of the wellhead exposed, and/or the like. Ends of a tubing string and a rod string disposed within the subterranean well may be respectively secured within portions of the disclosed cap. The cap may then be placed and secured over the exposed casing head to limit entry of foreign objects and debris into the well.

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 swellable packer includes a base pipe; a swellable sealing element disposed around the outer diameter of the base pipe; and at least one internal backup ring disposed within the swellable sealing element. It may be manufactured by disposing the internal backup ring on the base pipe; applying an elastomeric material over a section of the base pipe and the internal backup ring; and applying a bonding agent over the section of the base pipe and the at least one internal backup ring. It may be used to isolate a section of a well by disposing a swellable packer in the well, and exposing the swellable packer to a fluid, wherein the fluid exposure causes the elastomeric material to radially expand into contact with a well wall.

Abstract: A downhole isolation tool adapted to be converted in the field into any one of a bridge plug, ball drop plug, or a caged ball plug. The components used to assemble the tool, such as the mandrel, slips, and conversion adapters and accessories, are constructed primarily of non-metallic material. Through use of the disclosed isolation tool, drillout time is greatly reduced.

Abstract: This invention relates to an expansion-control device (2), a piping tool (46), a method and uses for a packer body (52) on a mandrel (50) with a supporting ring (54; 58) arranged adjacent to an end (56; 60) of the packer body (52). The expansion-control device (2) includes a packer-control element (4; 4a; 4b) for positioning adjacent to the supporting ring (54; 58) and for radial movement relative to the mandrel (50); and a power-transmission body (6) connected to the packer-control element (4; 4a; 4b) for the transmission of activating power thereto.

Abstract: A formation tester tool can include a longitudinal probe drill collar having a surface, a formation probe assembly located within the probe drill collar, the formation probe assembly including a piston reciprocal between a retracted position and an extended position beyond the probe drill collar surface, the piston being slidingly retained within a chamber, a seal pad located at an end of the piston, the seal pad including an outer surface defining a partial cylindrical surface. The piston includes an outer surface having non-circular cross-sectional shape and the chamber includes an inner surface having a non-circular shape similar to the shape of the piston outer surface. The formation tester tool can include interchangeable draw down assemblies and a flow bore having a curving path.

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 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 method of pressure testing a wellbore during a cementing operation includes positioning a tubular within a wellbore, the tubular including a collar assembly at a distal end of the tubular; urging cement through the collar assembly using a plug, the plug including a releasable sealing member; releasing the sealing member from the plug; sealing the collar assembly using the sealing member; and pressurizing the tubular to a predetermined test pressure and holding the predetermined test pressure for a predetermined time period. In another embodiment, a cementing plug for use with a collar assembly includes a plug body having a bore; and a releasable sealing member coupled to the bore, wherein sealing member is configured to engage and seal the collar assembly, after release.

Abstract: A packoff and a locking assembly installed in a bore of a wellhead component are provided. In one embodiment, a packoff includes inner and outer annular seals and an energizing ring shaped to be wedged between the inner and outer annular seals so as to apply a radially inward biasing force on the inner annular seal and a radially outward biasing force on the outer annular seal. In another embodiment, a locking assembly includes a lock ring that extends into a recess in a wall of the bore of the wellhead component and an actuator radially disposed between an inner component within the bore and the lock ring to retain the lock ring within the recess. The actuator can have an interference fit with the inner component to inhibit movement of the actuator between the lock ring and the inner component. Additional systems, devices, and methods are also disclosed.

Abstract: Apparatus useful for providing a liquid-tight seal around an opening formed in the earth's surface of an underground borehole includes a clamp and at least one platform. The clamp is configured to engage a wall extending around the borehole and the platform is configured to extend outwardly from the clamp over the earth's surface adjacent to the borehole.

Abstract: A downhole tool that is used to seal a well bore. The downhole tool has at least one of a nose cap coupled to a slip means for converting shear forces into compression forces, a pultrusion rod, and a butterfly ring. The pultrusion rod extends the full length of the center mandrel. The butterfly ring includes a plurality of wedges configured to remove the extrusion gap when the tool is expanded to prevent failure of a sealing member over increased well bore diameters. The downhole tool includes a pressure equalization port to equalize pressure between a first and a second fluid volume during removal of the tool from the well bore.

Abstract: The present invention generally relates to a stage tool. In one aspect, a downhole tool for use in a wellbore is provided. The tool includes a body having a bore. The tool further includes a seal assembly attached to the body. The seal assembly having an expandable annular member, a seal member and an expander sleeve, wherein the seal member includes one or more anti-extrusion spring bands embedded within the seal member. The tool further includes a slip assembly attached to the body. The slip assembly includes slips that are configured to engage the wellbore.

Abstract: Anchor areas are provided that are engaged by swelling of a swellable element of a downhole tool. When engaged with an open hole or casing, the anchor areas provide additional holding power for the swellable element. The anchor areas may be formed as separate elements disposed about the swellable element or may be formed into the surface of the swellable element.

Abstract: A wellhead seal assembly that forms a metal-to-metal seal between inner and outer wellhead members. A seal member has inner and outer walls separated by a slot, where the slot has an upper portion that is wider than a lower portion of the slot. An energizing ring having an upper end portion and a nose is moved into the slot, where the upper end portion has a greater cross-sectional thickness than the nose. As the energizing ring is moved into the slot, the nose of the energizing ring engages the lower portion of the slot to form a lock against the walls of the inner and outer wellhead members, and the upper end portion of the energizing ring engages the upper portion of the slot to form a seal against the walls of the inner and outer wellhead members.

Abstract: A liner hanger/packer apparatus operates by sequential expansion of a slip ring and then a sealing element. The hanger slips are set by pressure on a seated ball actuating anchor slips to grip followed by a stroker assembly and a swage making a first movement. The ball seat is defeated and the liner is cemented. A pickup force extends landing dogs so that a subsequent set down force releases a flapper to close and closes off fluid ports associated with the anchor slips so that pressure on the closed flapper sets the anchor and strokes the swage a second stroke to set the sealing element. A rupture disc breaks in the flapper after further relative movement of mandrel components to open the fluid displacement ports so that the anchor is in pressure balance to backpressure developed from fluid moving through the now broken disc as the running tool is removed.

Abstract: A wellbore packer for setting one or more packing elements in a borehole having an open hole section. The wellbore packer comprises a port-less mandrel configured with one or more packing elements and one or more setting mechanisms. The setting mechanism is responsive to a driving force and configured to set the packing elements in the borehole, wherein the driving force is not tubing string pressure. Where packers are set by annular pressure, a method for setting a plurality of such packers may include sequentially operating the packers. A mechanism may be provided for the packers to allow sequential operation thereof.

Abstract: Systems and methods for secondary sealing of a perforation present within a wellbore casing associated with a primary sealing agent. The wellbore casing defines a casing conduit present within a wellbore that extends between a surface region and a subterranean formation. The systems and methods include a sealing apparatus that retains a charge of sealing material with a secondary sealing agent and is conveyed within the casing conduit to within a threshold distance of the perforation. The systems and methods further include selectively releasing the charge of sealing material from the sealing apparatus, such as by a release mechanism, to deliver the charge of sealing material to the perforation, to supplement the primary sealing agent (and/or a seal formed thereby), and/or to decrease a flow rate of a fluid from the casing conduit through the perforation.

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 sealing arrangement and method for dynamic sealing around a drill stem (50) in water-carrying, drilling fluid-carrying or hydrocarbon-carrying wells, comprising at least one dynamic sealing (35a) which is arranged to envelop the drill stem (50), and a receiver unit (30) arranged to receive the at least one sealing (35a), with the dynamic sealing being arranged to be driven into the receiver unit (30) with the help of the drill stem, and to be securely locked in the receiver unit, and also that internal pressure support in the sealing arrangement is provided corresponding to at least the surrounding pressure.

Abstract: A lock holds a movable member in position to a stationary member. The set position of the tool is held while being configured to release with the capability of being reset in the same trip to lock a set position of the tool in the same or a new location.

Abstract: An apparatus for installing two sensing instruments and cables inside of a single tubing string in a wellbore for monitoring well conditions at two different locations includes an upper sensor attached to an inner sleeve seated at a first location in a ported outer sleeve in the tubing string. The upper sensor is allowed to be in pressure communication with the exterior of the tubing string at the first location. A second lower sensor is deployed on a pump down cup (PDC) assembly to a lower depth in the outer sleeve to allow fluid pressures to be monitored at a second location in the wellbore.

Abstract: Embodiments of a bottomhole assembly BHA for completion of a wellbore are deployed on electrically-enabled coiled tubing (CT) and permit components of the BHA to be independently electrically actuated from surface for completion of multiple zones in a single trip using a single BHA having at least two electrically-actuated variable diameter packers. One or both of the packers may be actuated to expand or retract for opening and closing off a variety of flowpaths between the BHA and the wellbore, in new wellbores, old wellbores, cased wellbores, wellbores with sleeves and in openhole wellbores. Additional components in the BHA, which may also be electrically-actuated or powered, permit perforating, locating of the BHA in the wellbore such as using casing collar locators and microseismic monitoring in real time or in memory mode.

Abstract: A technique that is usable with a well includes deploying a segmented ring assembly in the well; and disposing the segmented ring assembly between a first element fixed in place in the well and a second unfixed element. The technique includes using the second element to compress the assembly to produce radially and tangentially acting forces on segments of the assembly.

Abstract: A pipe designed to be placed within a well for producing a fluid of interest, a pipe onto the outer face whereof is crimped a tubular metal element, wherein: the inner face of the tubular element exhibits an annular groove wherein is engaged a metal anchoring ring or a pair of anchoring rings set back-to-back; each anchoring ring consists of a ring split transversely at least partially, is provided on its inner face with projecting anchoring members, and exhibits, in cross-section, a base equipped with the projecting members and at least one flank forming an acute angle with the base; the annular groove exhibits a profile that is substantially complementary to that of the ring or of the pair of rings; the depth of the groove being less than the thickness of the ring or of the rings; such that the projecting members are at least partially embedded into the pipe after crimping of the metal element onto the pipe.

Abstract: A swellable packer for use with a subterranean well can include a swellable seal having a circumferentially extending recess formed on a surface of the seal. Another swellable packer can include a swellable seal having a helically extending recess formed in the seal. A method of constructing a swellable packer can include forming a circumferentially extending recess on a surface of a swellable seal.

Abstract: In some embodiments, an apparatus and a system, as well as a method and an article, may operate to advance a sampling and guard probe (100) with a surrounding sealing pad (108) against a borehole wall, to adjust the size of the area associated with a fluid flow inlet of the probe, where the size of the inlet area (104) is selectably and incrementally variable, and to draw fluid into the fluid flow inlet by activating at least one pump (344) coupled to at least one fluid passage (128) in the probe. Additional apparatus, systems, and methods are disclosed.

Abstract: Downhole apparatus comprises a base pipe and a plurality of non-concentric pressure deformable chambers mounted externally on the pipe. The chambers may be inflated to increase the diameter of the apparatus and engage and support a surrounding bore wall.

Abstract: A valve assembly connectable between first and second downhole components that each have first and second internal flowpaths. The valve assembly comprises a first valve operable to selectively fluidly couple the first internal flowpaths of the first and second downhole components, as well as a second valve operable to selectively fluidly couple the second internal flowpaths of the first and second downhole components.

Abstract: The present invention relates to a downhole annular barrier (1) with an axial extension having an outer surface facing an inner surface of an outer structure (2). The downhole annular barrier comprises a tubular part (5), an expandable part (3), and at least one annular sealing element (41). The annular sealing element (41) is connected with the expandable part (3) and has an axial length along the axial extension of the downhole annular barrier which is less than 50% of a length of the downhole annular barrier along the axial extension of the downhole annular barrier. The annular sealing element comprises a spring element (43). Also, the present invention relates to a downhole system and to a seal providing method.