Abstract: A downhole tool suitable for use in a wellbore, the tool having a double cone having a dual-cone outer surface. The downhole tool includes a carrier ring disposed around one end of the double cone, and a slip disposed around or proximate to an other end of the double cone. There is a guide assembly engaged with the slip.

Abstract: Valve systems and methods for inserting into a casing used in a downhole environment are provided. The valve system includes a tool mandrel, a check valve assembly, and a setting system. The setting system includes inner and outer setting mandrels and a slip collar. The inner setting mandrel is located around at least a portion of the tool mandrel and includes a frustoconical outer surface. The outer setting mandrel is located around at least a portion of the inner setting mandrel and includes a frustoconical inner surface. The slip collar is located around at least a portion of the outer setting mandrel and includes a plurality of tabs and each tab includes gripping elements.

Abstract: The present disclosure relates generally to equipment utilized and operations performed in conjunction with a subterranean well and, more particularly, to an improved liner hanger system. A downhole expandable liner hanger positioned in a subterranean wellbore may comprise a liner. The downhole expandable liner hanger may further comprise an expansion element. The expansion element may comprise one or more annular seals bonded to the expansion element, a first spike; and a second spike. The downhole expandable liner hanger may further comprise a woven mesh, wherein the woven mesh is disposed around the expansion element between the first spike and the second spike, wherein the woven mesh comprises a first material layer and a second material layer.

Abstract: A sliding sleeve well device has a first sliding sleeve received in a second sliding sleeve. A polymer seal having a polymer sealing surface is between and in sealing contact with the sliding sleeves. A metal-to-metal seal is between the sliding sleeves and actuable into sealing contact with the first and second sliding sleeves.

Abstract: A rubber composition for a studless tire according to an embodiment includes a rubber component containing a natural rubber and a polybutadiene rubber; oil-absorbent polymer particles having a glass transition temperature of ?70 to ?20° C., formed from a polymer whose molecular weight distribution is less than 3.0, and having an oil absorption of 100 to 1,500 ml/100 g; and an oil. The content of the oil-absorbent polymer particles is 0.5 to 25 parts by mass per 100 parts by mass of the rubber component. As a result, on-ice performance and rolling resistance performance can be improved.

Abstract: An anchoring extrusion limiter for a non-retrievable packer has a plurality of ring segments with a top surface having at least one ring segment insert designed to bite and grip a well casing in which a packer is set. The anchoring extrusion limiter inhibits an extrusion of a main sealing element of the packer while providing anchoring backup to the anchoring slips of the packer.

Abstract: A resettable elastomeric packer element of a packer, compressed for sealing in a wellbore, is released from sealing engagement in the wellbore by applying tension to an end of the packer element. The elastomeric packer element stretches and releases from the wellbore forming an annular passageway between the packer element and the wellbore. In the absence of a pressure equalization valve or flow passages through the packer, the annular passageway equalizes pressure differentials across the packer element allowing a tool, in which the packer is incorporated, to be moved in the wellbore with little or no damage to the packer element and further, allows debris to flow from above the packer to below the packer.

Abstract: A pre-set inhibiting extrusion limiter has a segmented anti-extrusion ring with a plurality of anti-extrusion ring segments supported by a stepped cone frustum. Each ring segment is retained in a run-in condition by a compression spring retained by a retainer ring held in a retainer ring groove in the respective anti-extrusion ring segments. A push ring moves the respective anti-extrusion ring segments from the run-in condition to a packer-set condition in which the anti-extrusion ring segments abut a cone frustum step of the stepped cone frustum.

Abstract: An extrusion ring has a base from which multiple segmented rows of rings integrally extend. Gaps in one row are offset from the adjacent row to cover any gaps. The rows gain strength from a common base that also prevents relative rotation among the rows. The overlapping rings are additively manufactured with breakable restraints in some or all the gaps that fail during the setting such as in shear. Faster running in rates can be realized as each ring row has hoop strength due to the ties in the gap or gaps that are incorporated into the additive manufacturing process to make the assembly. Residual stresses in each ring from the additive manufacturing process are resisted from the ties in the gaps. Ties between overlapping rows are also contemplated.

Abstract: A sealing system for a flow channel is disclosed. The sealing system includes a mandrel; a swellable element disposed about the mandrel; and a swell control element disposed on a surface of the swellable element and configured to delay swelling of the swellable element. The swell control element contains a polymeric matrix that is impermeable to oil, water, or a combination thereof; and a channel inducer dispersed in the polymeric matrix, the channel inducer including carbon nanotubes, a hollow fiber, an oil swellable material, or a combination comprising at least one of the foregoing.

Abstract: A downhole apparatus for use in a tubular includes a mandrel, a slip, a wedge, a cone, and seal elements. The mandrel, which can be permanent or temporary, has an end shoulder. The slip is disposed on the mandrel adjacent the first end shoulder, and the wedge is disposed on the mandrel between the cone and the slip. The cone is movable relative to the end shoulder to engage the slip toward the tubular. The seal elements are disposed on the wedge and slip and fit between each other. The fit seal elements seal against the tubular and seas off fluid communication in the annular space between the plug and the tubular.

Abstract: A sealing element is flanked by wedge-shaped extrusion ring assemblies. The extrusion rings are continuous for 360 degrees and are slotted from the outside dimension and alternatively from the inside dimension to allow the diameter to increase to the surround tubular or open hole. The extrusion rings climb a ramp on an adjacent pedestal ring on the way out to the borehole wall. Depending on the dimension of the gap to be spanned the extrusion ring slides a variable distance up the pedestal ring ramp. An optional anchor ring is initially forced up an opposite ramp of the pedestal ring. If the sealing gap is short the anchor ring can be eliminated. For larger gaps the anchor ring moves out far enough toward the borehole wall to contact the extrusion ring located on an opposing ramp of the pedestal ring so that reaction forces are directed to keep the anchor ring wedged in position for support of the extrusion ring assembly.

Abstract: An adjustable packing element assembly includes a tubular, and a packing element supported by the tubular. The packing element includes a first end portion and a second end portion. A backup ring is arranged at the first end portion. The backup ring includes a first section mounted to the tubular and a second section extending over the packing element. An expandable ring is mounted to the backup ring. The expandable ring includes a selectively expandable portion. An adjustable sleeve is mounted to the expandable ring. The adjustable sleeve is selectively arranged to constrain an amount of expansion of the selectively expandable portion.

Abstract: An extrusion ring has a base from which multiple segmented rows of rings integrally extend. Gaps in one row are offset from the adjacent row to cover any gaps. The rows gain strength from a common base that also prevents relative rotation among the rows. The overlapping rings are additively manufactured with breakable restraints in some or all the gaps that fail during the setting such as in shear. Faster running in rates can be realized as each ring row has hoop strength due to the ties in the gap or gaps that are incorporated into the additive manufacturing process to make the assembly. Residual stresses in each ring from the additive manufacturing process are resisted from the ties in the gaps. Ties between overlapping rows are also contemplated.

Abstract: A backup ring assembly has a plurality of radially offset ring members including an outermost ring member formed from plurality of axially extending segments. Each of the plurality of axially extending segments includes an outer surface. A first interlock member support is coupled to the outer surface of one of the plurality of axially extending segments of the outer most ring member. A second interlock member support is coupled to the outer surface of an another one of the plurality of axially extending segments of the outermost ring member. An interlock member includes a first end supported at the first interlock member support and a second end supported at the second interlock member support. The interlock member restrains radially outward expansion of the ring and circumferential expansion of a gap extending between the one of the axially extending segments and the another one of the axially extending segments.

Abstract: Fluid-sealing downhole bridge plugs may include a pair of sealing rings which prevent flow of well fluid through the interface between a mandrel shaft of a mandrel and expansion elements of the downhole bridge plug. An illustrative embodiment of the fluid-sealing downhole bridge plugs includes a mandrel. At least one sealing element may be provided on the mandrel. A first backup ring may be provided on the mandrel on a first side of the at least one sealing element. A second backup ring may be provided on the mandrel on a second side of the at least one sealing element. A first gage ring may be provided on the mandrel in engaging relationship to the first backup ring. A second gage ring may be provided on the mandrel in engaging relationship to the second backup ring. A first ring space may be provided between the at least one sealing element and the first backup ring. A first seal ring may be provided in the first ring space.

Abstract: An improved c-ring slip retention system and method for extraction of the c-ring slip are provided. The c-ring slip retention system may use a lip portion of a retention sleeve to hold the c-ring slip against a liner hanger body. The c-ring slip may have a multi-load shoulder profile that interfaces directly with a complementary profile formed in the liner hanger body. The disclosed retention system prevents the c-ring slip from being prematurely extracted from a liner hanger body while the liner hanger is lowered through a borehole. The c-ring slip retention system may include a first retention mechanism and a second retention mechanism used to secure the retention sleeve to the liner hanger body. A single actuation of at least one setting segment in an axial direction may disengage both retention mechanisms, move the retention sleeve axially relative to the liner hanger body, and extract the c-ring slip.

Abstract: A method of using a downhole tool that includes the step of operating a workstring to run the downhole tool into a wellbore to a desired position. The downhole tool includes a mandrel having a proximate end with a first outer diameter; a distal end having a first set of threads and a second outer diameter; a flowbore extending from the proximate end to the distal end; and an inner set of shear threads disposed in the flowbore at the proximate end.

Abstract: A downhole tool suitable for use in a wellbore that includes a wedge mandrel having a distal end; a proximate end; an outer surface; and a flowbore extending through the wedge mandrel from the proximate end to the distal end. The tool includes a fingered member disposed around the wedge mandrel. The tool includes a ball seat insert made of a reactive metal-based material, the ball seat insert disposed in the flowbore and engaged with a first set of threads. The tool includes a support platform disposed in the flowbore and engaged with a second set of threads.

Abstract: A method of using a downhole tool that includes the step of operating a workstring to run the downhole tool into a wellbore to a desired position. The downhole tool includes a mandrel having a proximate end with a first outer diameter; a distal end with a second outer diameter; a flowbore; and an inner set of shear threads disposed in the flowbore at the proximate end.

Abstract: A resettable elastomeric packer element of a packer, compressed for sealing in a wellbore, is released from sealing engagement in the wellbore by applying tension to an end of the packer element. The elastomeric packer element stretches and releases from the wellbore forming an annular passageway between the packer element and the wellbore. In the absence of a pressure equalization valve or flow passages through the packer, the annular passageway equalizes pressure differentials across the packer element allowing a tool, in which the packer is incorporated, to be moved in the wellbore with little or no damage to the packer element and further, allows debris to flow from above the packer to below the packer.

Abstract: A system comprises a casing; a liner that is disposed in the casing and that is concentric with the casing; and a layer of material disposed between the liner and the casing; where the layer of material forms a first bond with the liner and a second bond with the casing thereby enabling the liner to hang from the casing. A method for hanging the liner from the casing comprises disposing in a borehole a system comprising a casing; a liner that is disposed in the casing and being concentric with the casing; and a layer of material disposed between the liner and the casing; heating the system at a point proximate to the layer of material; and forming a first bond between the layer of material and the liner and a second bond between the layer of material and the casing.

Abstract: A packer assembly includes an elongate body, an upper shoulder and a lower shoulder each disposed about the elongate body, and an upper sealing element and a lower sealing element each disposed about the elongate body and positioned axially between the upper and lower shoulders. A spacer interposes the upper and lower sealing elements and has an annular body that provides an upper end, a lower end, and a recessed portion extending between the upper and lower ends. A diameter of the annular body at the upper and lower ends is greater than the diameter at the recessed portion.

Abstract: The present invention relates to a downhole wireless transfer system (1) for transferring signals and/or power, comprising a production casing (2) arranged in a borehole (3), defining an annulus (4) therebetween, the production casing having an inner face (5) and an outer face (6), a downhole tool (7) comprising a first ultrasonic transceiver (8), a second ultrasonic transceiver (9) connected to the outer face of the production casing, wherein the tool comprises a projectable means (10) configured to bring the first ultrasonic transceiver in contact with the inner face of the production casing, so that signals and/or power can be transferred through the production casing via ultrasonic waves between the first and second ultrasonic transceivers. The present invention also relates to a method for wirelessly transferring signals and/or power in a downhole wireless transfer system according to the present invention.

Abstract: An improved weight-set hanger system and method of securing the weight set hanger for use comprises three independent locking mechanisms that are built into an actuator/packoff assembly. These independent locking mechanisms comprise two locking rings, one of which fastens the actuator/packoff assembly to a spool body, and the other of which internally locks the hanger to the actuator/packoff assembly. A third locking mechanism comprises a plurality of screw down spring loaded lock pin assemblies, which, in an embodiment, are spaced out at 90 degree intervals.

Abstract: A slip assembly for downhole tools comprises a slip ring for engaging a surface of a wellbore and a cone for expanding the slip ring into engagement with the surface of the wellbore. The slip ring has an interior surface defining a trough. The cone has an exterior surface defining a ridge. The trough is wider than the ridge, whereby the slip ring can bend over a top of the ridge.

Abstract: A slip assembly for downhole tools comprises a slip ring for engaging a surface of a wellbore and a cone for expanding the slip ring into engagement with the surface of the wellbore. The slip ring has an interior surface defining a trough. The cone has an exterior surface defining a ridge. The ridge is wider than the trough, whereby the slip ring can unbend over a top of the ridge.

Abstract: A downhole tool, such as a composite bridge plug, has a packing element disposed on a mandrel of the tool adjacent an activating element, such as a cone and slip arrangement. The packing element includes a packer and at least one backup ring. The packer is composed of packing material and is compressible on the downhole tool at least in part due to the activating element. The at least one backup ring limits extrusion of the packer. The at least one backup ring is molded into the packing material at one end of the packer adjacent the activating element. Preferably, each end of the packer has at least two backup rings molded therein, and slots in the adjacent backup rings are preferably offset at the ends.

Abstract: A new resin blend is disclosed, which may be referred to as a hybrid resin. The resin blend includes an effective amount of benzoxazine resin or benzoxazine derivative mixed with at least one of epoxy resin, phenolic resins and other thermosetting polymers at varying ratios.

Abstract: A composite cone assembly for use with a frac or bridge plug system is discussed herein having shaped outer contours and the strength needed for high pressure applications but with reduced machining requirements by forming part of the cone assembly from a high strength fiber material and the contoured surface from molding, such as from injection molding or compression molding.

Abstract: An improved hold-down assembly for a well tie-back string and methods of use of the same are disclosed. The improved hold-down assembly includes a tie-back string and a hold-down assembly coupled to the tie-back string. The hold-down assembly includes one or more slips and a packer assembly disposed about the tie-back string.

Abstract: A downhole tool, tool assembly, and method, of which the downhole tool includes an expandable sleeve defining a bore extending axially therethrough, and including a shoulder that extends inward from the bore, 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, a second swage positioned at least partially within the bore. The first and second swages are configured to deform the expandable sleeve radially outwards when the first and second swages are moved toward one another within the expandable sleeve, and the shoulder is configured to prevent at least one of the first and second swages from sliding therepast.

Abstract: A downhole tool useable for isolating sections of a wellbore, the downhole tool having: a mandrel made of composite material, a metal slip, a seal element, a composite slip, a first cone, and a lower sleeve. The first cone is disposed around the mandrel, and proximately between an underside of the composite slip and an end of the seal element. The first cone has a completely smooth circumferential conical surface engaged with the underside of the composite slip.

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 frangible slip ring is disposable on a mandrel of a plug disposable in a casing of an oil or gas well. The slip ring is radially expandable during setting to fragment and radially expand to engage the casing. A plurality of external teeth are formed in an exterior of the slip ring, and spaced-apart axially along the slip ring. The plurality of teeth is radially segmented around a circumference of the slip ring by a plurality of axial slots spaced-apart around the circumference of the slip ring and extending into the exterior of the slip ring. An interior of the slip ring is axially segmented along a longitudinal axis by a plurality of annular grooves spaced-apart along the longitudinal axis of the slip ring and extending into the interior of the slip ring.

Abstract: A system and method for treating a portion of a wellbore that includes a bottom hole assembly (BHA) connected to a work string. The BHA includes a packing element movable between an unset position and a set position and a locator device movable between retracted position and expanded positions. The locator device may be a locator collet. The locator collet may be expanded by a cone movable with respect to the collet. The expanded locator device is configured to engage a profile in a ported tubular within the wellbore. The engagement between the locator device and the profile selectively prevents further movement of the BHA and provides an indication of the location the BHA. The packing element may then be actuated and the wellbore treated through a port in the ported tubular. The BHA may then be moved to a different ported housing to treat another portion of the wellbore.

Abstract: Bridge plug or packer assemblies include a mandrel, at least one sealing element provided on the mandrel and a pair of backup rings provided on the mandrel on respective sides of the at least one sealing element. Each of the pair of backup rings including an annular backup ring body having a ring opening receiving the mandrel, a ring opening edge encircling and facing the ring opening, an engaging ring surface, an outer ring surface extending from the engaging ring surface to the ring opening edge, an inner ring surface extending from the engaging ring surface to the ring opening edge opposite the outer ring surface and a single spiraled ring groove in the backup ring body. A mandrel cap may be provided on the mandrel in engaging relationship to a second one of the pair of backup rings. A first shear-able ring retainer pin may couple the backup ring body of the first one of the pair of backup rings to the gauge ring.

Abstract: A tool and method employing sand jetting to perforate a wellbore casing at various locations using sandjetting, and to further flush the wellbore in the region of the tool, and to further frac the formation, all without having to remove 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, and a piston member is further provided to set the upper packer member. A bypass port, selectively openable and closeable, is provided to assist in moving the tool uphole during the perforating and fracking process.

Abstract: Embodiments pertain to a downhole tool that includes a mandrel made of a composite material, a bearing plate disposed around the mandrel, the bearing plate having an angled inner plate surface configured for engagement with a mandrel surface; a composite slip disposed around the mandrel, and having a composite slip body configured with a one-piece configuration, a first cone disposed around the mandrel, and proximate to the composite slip; a second slip disposed around the mandrel; a sealing element disposed around the mandrel; and a lower sleeve coupled to the mandrel, and proximate to a second side of the metal slip.

Abstract: A downhole tool including a mandrel, a sealing element, a cone, a plurality of fingers, and a slip. The sealing element may be positioned around the mandrel. The sealing element is configured to expand radially-outward from a contracted state to an expanded state. The cone may be positioned around the mandrel and proximate to the sealing element. The plurality of fingers may be positioned at least partially around the mandrel. The fingers may be axially-aligned with at least a portion of the sealing element. The fingers are coupled to a base and configured to break away from the base at a weak point when the sealing element expands into the expanded state. The slip may be positioned around the mandrel and proximate to the cone. The slip may include a tapered inner surface configured to slide along a tapered outer surface of the cone.

Abstract: A packoff for hanging a liner string from a tubular string cemented in a wellbore includes: a tubular body having an outer groove and an inner groove; an inner seal assembly disposed in the inner groove; an outer seal assembly disposed in the outer groove; a cap connected to an upper end of the body for retaining the seal assemblies; a plurality dogs disposed in respective openings formed through a wall of the body; and a lock sleeve. The lock sleeve is: disposed in the body, longitudinally movable relative to the body, and has a cam profile formed in an outer surface thereof for extending the dogs.

Abstract: Embodiments of the disclosure pertain to a downhole tool useable for isolating sections of a wellbore that includes a mandrel and a slip comprising a one-piece configuration disposed around the mandrel. The mandrel further includes a body comprising an external surface, and an inner bore formed therein; a distal end; and a proximate end; wherein the mandrel is made of composite material, wherein a set of shear threads are disposed along a surface of the inner bore at the proximate end.

Abstract: A wellbore cementing tool configured for placement in a wellbore or in a drill string, and method of using same. The tool comprises a body having upper and lower members connected by a shear component. A rod is connected to the upper member, and the tool can be lowered with the rod into the wellbore or drill string to a desired depth. At the desired depth, locking means are deployed to lock the tool in position, the tool is sealed, and cement can be injected through the tool to the annulus of the outer casing. In some embodiments the tool is locked using a pushing motion that extends locking members outwardly from the tool to engage the wellbore walls or the inner surfaces of the drill string. Once cementing is completed, the rod is pulled from surface thereby causing the shear component to rupture and the upper and lower members to disconnect, and the upper member can be drawn to surface leaving the rest of the tool downhole.

Abstract: A method of treating a formation includes, setting a treating plug within a structure, withdrawing a mandrel from the treating plug after having set the treating plug, maintaining the setting of the treating plug within the structure without a member extending longitudinally through the treating plug, pumping fluid against a plug seated at the treating plug, treating a formation upstream of the treating plug, and disintegrating at least a portion of the treating plug.

Abstract: Rapid swelling and un-swelling materials provide for rapid actuation of well tools. A well tool can include a swellable material, with the swellable material comprising a swellable glass material. A method of actuating a well tool in a subterranean well can include contacting a swellable material of the well tool with an activating fluid in the well, thereby causing the swellable material to swell. The well tool rapidly actuates in response to contacting the swellable material with the activating fluid.

Abstract: A packer system including a packer and a setting mechanism. The setting mechanism has a setting piston that is actuatable in response to a fluid pressure in order to set the packer with the setting piston. The setting mechanism prevents actuation of the setting piston until the pressure is decreased below a threshold pressure from a value greater than the threshold pressure. A method of setting a packer is also included.

Abstract: A wellbore treatment tool for setting against a constraining wall in which the wellbore treatment tool is positionable, the wellbore treatment tool including: a tool body including a first end formed for connection to a tubular string and an opposite end; a no-go key assembly including a tubular housing and a no-go key, the tubular housing defining an inner bore extending along the length of the tubular housing and an outer facing surface carrying the no-go key, the no-go key configured for locking the no-go key and tubular housing in a fixed position relative to the constraining wall, the tubular housing sleeved over the tool body with the tool body installed in the inner bore of the tubular housing; and a sealing element encircling the tool body and positioned between a first compression ring on the tool body and a second compression ring on the tubular housing, the sealing element being expandable to form an annular seal about the tool body by compression between the first compression ring and the second c

Abstract: A system configured to seal at least one flexible longitudinal member is provided. In one embodiment, the system includes a sealing member having at first set of apertures, a second set of apertures, and inner and outer interface surfaces. The system also includes a clamping member having a first set of apertures and an interface surface. The first set of apertures in the clamping member is configured to align with the first set of apertures in the sealing member. The first sets of apertures are configured to receive the at least one flexible longitudinal member. The interface surface of the clamping member is configured to abut the inner interface surface of the sealing member. The system also includes at least one threaded blind bore in the interface surface of the clamping member, and at least one fastener configured to draw the clamping member into engagement with the sealing member.

Abstract: A packer that is usable with a well includes a tubular inner core and a swellable body that is mounted to the core and is adapted to swell in the presence of a triggering agent to form an annular seal in the well. The swellable body longitudinally extends between first and second ends of the body and includes a first region that is located between the first and second ends of the swellable body to swell at a first rate and at least a second region that is located closer to one of the first and second ends than the first region to swell at a second rate less than the first rate.

Abstract: Embodiments of the disclosure pertain to a downhole tool useable for isolating sections of a wellbore that includes a mandrel, the mandrel further having a body comprising an external surface, and an inner bore formed therein; a distal end; and a proximate end; wherein the mandrel is made of composite material, wherein a set of shear threads are disposed along a surface of the inner bore at the proximate end. Embodiments of the tool include a slip disposed about the mandrel, wherein the slip comprises a one-piece configuration.