Abstract: A well tool for sealing an annular gap between a tubing string and a wellbore wall is described. In one implementation, the well tool includes an annular inner seal, an annular sleeve disposed over the inner seal, an annular outer seal residing over the sleeve and comprising a swellable elastomer adapted to swell when contacted by a specified fluid, the annular outer seal being axially shorter than the sleeve, and an end ring adapted to be disposed at an end of the sleeve, the sleeve configured to buckle against the end ring in response to a deformation of the outer seal due to directional pressure.

Abstract: A device and method allow a longer sealing element to be used on a packer or other downhole tool while providing an increase in the total amount of setting force that can be used and providing for more uniform or balanced setting of the sealing element. The packer may be first set using internal bore pressure to radially expand one end of the sealing element with a first hydraulic setting mechanism. The packer may then be set a second time using annulus pressure to continue the radial expansion of the sealing element with a second hydraulic setting mechanism.

Abstract: The power charge of a wireline pressure setting assembly includes a barrier located adjacent an open upper end of the power charge. The barrier centralizes the power charge in horizontal applications to ensure the associated tool properly sets. The barrier also limits how much of the power charge can flow out of its housing in a horizontal application. The barrier can be porous or impervious to contain as much of the power charge in a small sub-chamber in the pressure chamber defined by the barrier. Once ignition starts in the power charge the barrier can be consumed or otherwise disabled for the normal functioning of the setting device to set a tool and release from the set tool in a normal manner.

Abstract: A permanent inflatable packer enabling wellbore isolation in both open hole and cased hole wells expands multiple times its original diameter to conform to borehole irregularities and eccentricities. Cement, water based mud or oil based mud activation fluid under prerequisite fluid pressure causes retainer to slide upon a mandrel causing fracture of shearing screws and compression of Belleville metal ring washers to enable activation fluid to flow around an O-ring and into a recess area to effectuate inflation of ribs sandwiched between rubber layers.

Abstract: A setting apparatus for use on a downhole tool in a wellbore is described. The setting apparatus comprises an expandable member configured for axial expansion under fluid pressure wherein said expansion moves said downhole tool from an unset position to a set position. Generally, the fluid will be a gas generated downhole and can be generated near or in the expandable member.

Abstract: A system includes a back pressure valve. The back pressure valve includes a body, a plunger disposed internal to the body, and a friction member disposed about the exterior of the body. The friction member is configured to expand radially to contact an internal surface of a bore. A method includes disposing a back pressure valve into a straight bore and expanding a friction member of the back pressure valve radially into contact with an internal surface of the straight bore.

Abstract: A well tool includes: a well packer; a hydraulic sub-assembly coupled to the well packer; an anti-preset assembly coupled to the hydraulic sub-assembly; a slip assembly coupled to the anti-preset assembly; and a fold-back assembly coupled between the well packer and the hydraulic sub-assembly. The well packer includes an expandable member that rides on a mandrel extending at least a portion of the well tool. The fold-back assembly includes a bias member carried on the mandrel and adapted to engage a profile formed on the mandrel based on a setting stroke that adjusts the expandable member into an expanded position in substantially sealing contact with a tubular.

Abstract: A packer can include a mandrel having a longitudinal section, the packer being releasable in response to the section being severed, a slip support and a load transfer device that extends longitudinally across the section, the device being secured to the mandrel on one side of the section, and the device being secured to the member on an opposite side of the section. A method of constructing a releasable packer can include assembling a mandrel, at least one slip, a slip support and a load transfer device, the mandrel having a longitudinal section, and the packer being releasable in response to the section being severed. The assembling can include preventing relative longitudinal displacement between the device and the mandrel on one side of the section while preventing relative longitudinal displacement between the device and the member on an opposite side of the section.

Abstract: A completion assembly for treating a wellbore. The completion assembly can include a tubular member having a bore formed axially therethrough and a port formed radially therethrough. An annulus can be disposed radially outward from the tubular member and the port can provide fluid communication between the annulus and the bore. A packer can be coupled to the tubular member and adapted to isolate first and second portions of the annulus. A seal bore can be coupled to the tubular member such that the port is disposed axially between the packer and the seal bore. A straddle seal can be adapted to contact the packer and the seal bore to prevent fluid flow between the annulus and the bore. The straddle seal can be run into the wellbore with the completion assembly in a single trip.

Abstract: A downhole tool having a throughbore is disclosed for use in a tubular located in a wellbore. The downhole tool has a sealing element configured to seal an annulus between the downhole tool and an inner wall of the tubular; at least one flow path formed in the downhole tool, wherein the flow path is configured to allow fluids in the annulus to flow past the sealing element when the sealing element is in a sealed position; and at least one valve in fluid communication with the flow path and configured to allow the fluids to flow through the flow path in a first direction while preventing the fluids from flowing through the flow path in a second direction. A guard may be installed proximate anchor elements. The guard extends radially beyond an outer diameter of the anchor elements when the anchor elements are in a retracted position.

Abstract: To address concerns of kobe plug cap portions being inadvertently removed, for example, by abutment with strings or tools passing thereby, a shielding structure may be employed to protect the cap against inadvertent removal. The port opening tool useful with the kobe plug is selected to overcome the shielding structure to open the kobe plug. To address concerns of a portion of the kobe plug becoming loose in the tubing string inner bore, a capturing mechanism may be provided that captures the cap portion after it is removed to open the kobe plug and prevented the cap portion from becoming loose in the inner bore of the tubing string.

Abstract: A downhole tool assembly is presented for use in a wellbore, the tool having a mandrel assembly for substantially bearing the tensile and rotational loads placed on the tool assembly during run-in to the wellbore, a displacement assembly for substantially bearing displacement loads and for providing relative movement to the mandrel assembly, the displacement assembly for actuating a actuable tool attached to the mandrel assembly. The mandrel assembly has an upper mandrel positioned radially outward of the displacement assembly and a lower mandrel positioned radially inward of the displacement assembly. A load cross-over mandrel transfers the tensile and rotational loads between the upper and lower mandrels. The load cross-over mandrel has a plurality of passages which allow corresponding rods of the displacement assembly to slide therethrough. The rods transfer the displacement loads from actuators above the rods to an actuable tool below the rods.

Abstract: An actuation system, including a first member having a first profile engagable with a tool operatively arranged for actuating the member from an initial configuration to an actuated configuration. A second member is included that is movable relative to the first member. The second member has a lockout feature configured to prevent engagement of the first member with the tool while the second member is located proximate to the first member. A method of selectively actuating a system is also included.

Abstract: The present invention relates to a downhole plug with an expandable elastomeric packer (1) having two ends, surrounding a main section (25). The intended application of the downhole plug is for sealing wellbores and tubulars (4). At least one expansion ring (13) adjoins at least one of said two ends of the elastomeric packer (1), and at least one support ring (15) applies an axial force (16) in a longitudinal direction of the downhole plug. At least one of said two ends of the elastomeric packer (1) is made with a tapered surface. The at least one expansion ring (13) is made with a tapered surface configured in such a manner that the application of the axial force (16) in a longitudinal direction of the downhole plug leads to the simultaneous expansion of the elastomeric packer (1) and the at least one expansion ring (13).

Abstract: Methods and systems for testing a subterranean formation penetrated by a wellbore are provided. A testing tool has a plurality of packers spaced apart along the axis of the tool, and at least a testing port. The testing tool is positioned into the wellbore and packers are extended into sealing engagement with the wellbore wall, sealing thereby an interval of the wellbore. In some embodiments, the wellbore interval sealed between two packers is adjusted downhole. In one embodiment, the location of the testing port is adjusted between two packers. The methods may be used to advantage for reducing the contamination of the formation fluid by fluids or debris in the wellbore.

Abstract: A hydrostatically set packer is held against setting by a locking member that is made of controlled electrolytic material (CEM). After introduction into a wellbore and exposure to thermal or well fluid inputs the lock made of CEM dissolves or is otherwise weakened to the point where relative movement can occur for the setting of the packer with available hydrostatic pressure. The locking member can also be a shape memory alloy at least in part whose shape change allows the tool to set.

Abstract: Disclosed are systems and methods for mechanically reclosing a hydraulically actuated sliding side door of a sleeve assembly. One sleeve assembly includes a housing defining one or more flow ports, a sliding sleeve arranged within the housing and movable between a closed position and an open position and back to the closed position, wherein, when in the closed position, the outer sleeve occludes the one or more flow ports, and, when in the open position, the one or more flow ports are exposed. A piston is movably arranged within a piston bore defined in the housing, and a locking mechanism is arranged within the piston bore and configured to engage the piston with the sliding sleeve, thereby allowing the piston to move the sliding sleeve to the open position.

Abstract: A method can include interconnecting a well tool in a well tool assembly with a shock mitigating connection, the interconnecting being performed without threading, and positioning the well tool assembly in a wellbore. A well perforating assembly can include at least two perforating devices, a detonation train extending through the perforating devices, and a shock absorber positioned between the perforating devices. A method of assembling a perforating assembly can include, prior to installing the perforating assembly in a wellbore, pushing one perforating device connector into another perforating device connector without threading the connectors together, thereby: a) preventing disconnection of the connectors and b) making a connection in a detonation train. A well system can include a perforating assembly including multiple perforating guns and multiple shock absorbers. Each shock absorber may be interconnected between at least two of the perforating guns.

Abstract: A configurable insert for a downhole tool. The configurable insert can include a body having a bore that is blocked by an impediment such that fluid flow is prevented through the body in both axial directions. The impediment can include a decomposable material. The configurable insert can also include at least one shear element disposed on the body for connecting to a setting tool. The shear element can be adapted to shear when exposed to a predetermined force, thereby releasing the setting tool from the body. The configurable insert can also include one or more threads disposed on an outer surface of the body below the at least one shear element for connecting the body to the downhole tool.

Abstract: A dual string packer may be provided with a crossover module located such that fluid communication may be provided from any tubular bore to the internal shifting chamber without completely disassembling the dual string packer. The crossover module may be attached to the through tubing mandrels at or near the bottom or lower end of the dual string packer.

Abstract: Disclosed herein is a segmented seat for use in wellbore servicing systems, comprising an annular-shaped seat with an upward facing surface for receiving an obturator, the seat defining a central passageway. The segments are locked together at their faces by protrusions and matching recesses.

Abstract: The removable plug features a solid material that is housed in a porous container that has its shape changed to transition from the run in shape to the set shape. A running string and setting tool that creates relative movement deliver the plug and pull on its lower end while holding the top stationary against a backing plate. The container is pulled into itself as the radial dimension grows for the set. There can be a mandrel that remains in position and can lock to the backing plate or alternatively there can be no mandrel or a removable mandrel. The porous container can be removed in a variety of ways to let the solid material escape to be removed with fluid circulating in the wellbore. Alternatively the mandrel can be undermined to let the solid material escape for recovery.

Abstract: The invention relates to an improved downhole tool apparatus for limiting the extrusion of a sealing elements in downhole tools. The apparatus provides for using a limiter ring or shoe located in a channel on the slip wedge so as to abut the sealing element. The limiter ring extends outward to the casing to minimize the gap through which the sealing element can extrude when the tool is in a set position.

Abstract: Disclosed are downhole subassembly systems and method of use thereof. One downhole subassembly system is an orientable whipstock subassembly that includes a whipstock apparatus including a deflector surface operable to direct a cutting tool into a casing sidewall to create a casing exit, and an orienting sub comprising an upper coupling operatively coupled to the whipstock apparatus and a lower coupling at least partially engaged with the upper coupling and rotationally movable with respect thereto while in an un-collapsed configuration and rotationally fixed with respect thereto while in a collapsed configuration.

Abstract: A Bottom Hole Assembly (BHA) tool and methods of downhole fluid management are disclosed. The BHA is deployed on a conveyance string to access a completion string and forming a tool annulus therebetween. A first assembly having a first bore fluidly connected to the conveyance string. A second assembly supports an packer for releasably sealing to the completion string, and a third assembly supporting a packer actuator thereon, the second assembly telescopically movable within the third assembly for forming a resettable packer releasably sealable to the completion string. A bypass valve is formed between the first and second assembly. Closing of the bypass valve directs fluid through a treatment port uphole of the resettable packer to the tool annulus and opening of the bypass valve bypasses fluid about the resettable packer. The packer actuator can further comprise an anchor for releasably anchoring to the completion string.

Abstract: Systems and methods for remotely setting a down hole device. The system includes a base pipe having inner and outer radial surfaces and defining one or more pressure ports extending between the inner and outer radial surfaces. An internal sleeve is arranged against the inner radial surface and slidable between a closed position, where the internal sleeve covers the one or more pressure ports, and an open position, where the one or more pressure ports are exposed to an interior of the base pipe. A trigger housing is disposed about the base pipe and defines an atmospheric chamber in fluid communication with the one or more pressure ports. A piston port cover is disposed within the atmospheric chamber and moveable between blocking and exposed positions. A wellbore device is used to engage and move the internal sleeve into the open position by applying predetermined axial force to the internal sleeve.

Abstract: A lock assembly for a mechanically set packer for deep deployments is described. The lock housing wall has at least one bore for a rod piston that is selectively actuated when wellbore hydrostatic is allowed to reach on side of the piston. Movement of the piston, after breaking a shear pin, allows a c-ring to spring outwardly and out of a locking groove in the mandrel so that the mandrel can be string manipulated with respect to the housing to set the packer. Once unlocked the lock assembly remains defeated. The piston can be optionally exposed to hydrostatic and will unlock at a given depth without manipulation of the wellbore annulus pressure. Other mechanisms to admit wellbore hydrostatic to move the piston or to move the piston in general by other techniques are described.

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 to a driving force and configured to set the packing elements in the borehole, wherein the driving force is not tubing string pressure.

Abstract: A packer assembly can include a setting mechanism with a shock dissipation device that deforms and thereby dissipates shock produced by the setting mechanism. A method of constructing a packer assembly can include assembling a setting mechanism by releasably securing a piston of the setting mechanism, the piston displacing in response to a predetermined pressure differential being applied across the piston, and positioning a shock dissipation device with the piston, the shock dissipation device dissipating shock produced by displacement of the piston when the predetermined pressure differential is applied. Another packer assembly can include a setting mechanism which outwardly extends a seal element and/or a gripping device, the setting mechanism including a shock dissipation device which deforms and thereby dissipates shock produced by the setting mechanism, and the shock dissipation device including a generally tubular member having multiple openings formed through a wall of the tubular member.

Abstract: A setting assembly including a settable member. A housing including a chamber and a setting material disposed in the chamber and having a first phase of matter and a second phase of matter. The setting material occupying a greater volume in the second phase than in the first phase. The setting material arranged to exert a setting force on the settable member during transition of the setting material from the first phase to the second phase. Also included is a method of setting a settable member.

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

Abstract: A hydraulic anchor is coupled to a packer subassembly of a tool string. The hydraulic anchor, when actuated by fluid pressure, engages the surrounding wellbore, holding the tool string in place within the wellbore. A packer may then be actuated, held in position within the wellbore by the hydraulic anchor. In some embodiments, an inflatable packer may be held in the desired location by the hydraulic anchor. In some embodiments, a straddle packer assembly may be held in place by the hydraulic anchor. In some embodiments, a swellable packer may be held in place during the swelling process by the hydraulic anchor.

Abstract: A fluid container reloading tool for a downhole fluid sampling tool (114) is described. The reloading tool includes an elongated cylindrical body. The body may include a bottom opening sized to engage with a fluid sampling tool deployed within a borehole. A cache (263) of empty fluid containers (210) may be included within the body (201). A piston may be coupled to at least one of the fluid containers in the cache of fluid containers. The piston may be used to transfer the cache of fluid containers into the fluid sampling tool. The reloading tool may also include a pump in fluid communication with the piston.

Abstract: An adjustable pressure hydrostatic setting module includes a collapsible pressure chamber and a setting chamber. The pressure chamber is precharged at a fluid pressure that is greater than atmospheric pressure and greater than the fluid pressure within the setting chamber. In a described embodiment, the setting module also includes a frangible rupture member that closes off the setting chamber from annulus pressure. A regulator governs the transfer of fluid pressure from the collapsible chamber to the setting chamber.

Abstract: A retrievable well packer for downhole operations, comprising an upper mandrel and a lower mandrel connected through a quick threaded connection, a hydraulic actuating assembly for downwardly moving under fluid pressure, a packing assembly for sealing against the well, first coupling mechanism between the upper mandrel and the hydraulic actuating assembly and second coupling mechanism between the lower mandrel and the hydraulic actuating assembly, with the second coupling mechanism connecting the lower mandrel and the hydraulic actuating assembly against rotation but permitting relative axial movement.

Abstract: A device and method allow a longer sealing element to be used on a packer or other downhole tool while providing an increase in the total amount of setting force that can be used and providing for more uniform or balanced setting of the sealing element. The packer may be first set using internal bore pressure to radially expand one end of the sealing element with a first hydraulic setting mechanism. The packer may then be set a second time using annulus pressure to continue the radial expansion of the sealing element with a second hydraulic setting mechanism.

Abstract: Embodiments of the invention generally relate to tools and methods for hanging and/or expanding liner strings. In one embodiment, a method of hanging a liner assembly from a previously installed tubular in a wellbore includes running the liner assembly and a setting tool into the wellbore using a run-in string. The setting tool includes an isolation valve and the liner assembly includes a liner hanger and a liner string. The method further includes sending an instruction signal from the surface to the isolation valve, wherein the isolation valve closes in response to the instruction signal and isolates a setting pressure in the setting tool from the liner string; and increasing fluid pressure in the setting tool, thereby setting the liner hanger.

Abstract: A downhole tool includes, a body having a recess, a first seal bore, a second seal bore, and a tool disposed at the body that is responsive to differential pressure across a piston. The downhole tool is configured to allow a differential pressure to form across the piston in response to a first plug sealing to and located at the first seal bore by the recess and preventive of forming a pressure differential across the piston in response to a second plug sealing to and located at the second seal bore by the recess.

Abstract: The removable plug features a solid material that is housed in a porous container that has its shape changed to transition from the run in shape to the set shape. A swage is moved through a passage in the container to enlarge the passage and move the container to a borehole wall. The passage is then closed such as with a flapper valve or by moving in a mandrel into the expanded passage and lodging the mandrel in the expanded passage. Various release techniques are described.

Abstract: A hydraulic packer including a chamber and at least one piston that slides down inside said chamber. The entire mandrel is made of a glass-fiber composition including glass-fiber 30%, resin 60%, and epoxy with accelerator 10%.

Abstract: A bottom hole assembly (BHA), adapted to be positioned in a casing and to isolate a portion of a wellbore, which includes a packer assembly with a first sealing element extending between first and second portions of the packer assembly. A method of setting a BHA in a casing which includes increasing a BHA pressure to activate an anchor assembly, applying a mechanical force to mechanically deform a first sealing element to thereby establish an initial seal between the first sealing element and an interior surface of the casing, and increasing a pressure in a space between the BHA and the casing and in a cavity within the BHA to increase a differential pressure across the first sealing element and thereby establish a pressure-energized seal between the first sealing element and the interior surface of the casing.

Abstract: An apparatus includes an impervious body, a sealing element, an energy source, and a trigger. The impervious body is configured to prevent passage of fluid therethrough. The sealing element is disposed about the impervious body. The energy source is operationally connected to the sealing element. The trigger is configured to transfer energy from the energy source to the sealing element. The trigger is activated, at least in part, by receiving a signal transmitted through the impervious body.

Abstract: A sampling assembly has an inner expandable packer, and an outer layer formed by rings may be disposed about and/or may be positioned on the outer surface of the inner expandable packer member. Drains may be positioned between the rings and may be located under ports positioned between the rings. Flowlines may be connected to the drains, may be positioned in the rings and may extend through the rings. For each of the ports, a plate may be positioned between the port and the laterally adjacent port. The flowlines may be connected to a downstream component, such as a fluid analysis module, a fluid containment module and/or the like.

Abstract: Apparatus for a downhole tool in a well bore includes at least one locking mechanism and at least one sleeve. The locking mechanism is configured in a first position to prevent the upper slips from engaging the well bore wall before being positioned at the desired setting location in the well bore and is moveable into a second position that allows the upper slips to be moved into engagement with the well bore wall. A sleeve is moveable axially in the direction of the lower end of the downhole tool and configured to move the locking mechanism from its first to its second positions and also to move the upper slips axially relative to the downhole tool into engagement with the well bore wall.

Abstract: A downhole apparatus and support assembly is described. The downhole apparatus has a radially expanding portion comprising a swellable elastomeric material selected to increase in volume on exposure to at least one predetermined fluid, and the support assembly is operable to be deployed from a first retracted position to a second expanded condition. The support assembly comprises an inner surface arranged to face the radially expanding portion, and at least a portion of the inner surface is concave. In another aspect the support assembly is configured to direct a force from the swellable material to boost or energize a seal created between the radially expanding portion and a surrounding surface in use.

Abstract: A method and an apparatus for closing an earth borehole, wherein an expandable closure body is inserted into the earth borehole and expanded in its diameter in order to seal the leak. The closure body, at least a part thereof, is moved beyond the lower end of the borehole to enter into the raw material filled cavity, and is expanded within the cavity below the borehole and, with an axially sealing surface, is urged from below against the cavity's sealing surrounding the borehole. With regard to the device, to achieve this, the expandable part has an expandable portion with an axially sealing surface which, once expanded, has a diameter significantly greater than the diameter of the borehole. In order to permit the sealing part being pushed against the borehole wall once it has been expanded inside the cavity, a reversible feed motion or advancing drive is provided.

Abstract: An array of plugging devices are pumped sequentially from the surface through a liner, that typically becomes horizontal in nature, where each plugging device is anchorable at a specified position along the length of the liner. When the plugging device is anchored, a cluster of perforations is generated above the plugging device where the perforations may be created by detonation of a perforating gun attached to the top side of the plugging device or the perforations may be created by shifting of a sleeve that is anchored to the plugging device. The plugging device may be a cup plug where the cup is similar to a swab cup and when pump pressure is applied to the cup, a force is generated to make the cup move through the liner. When anchored, the cup also directs frac fluids through the perforations to treat the well formation.

Abstract: A packer or bridge plug has slips that bind to the surrounding tubular with an adhesive bond. The tubular wall is not penetrated but a roughening of the target location in the tubular can help the bond material to adhere to support the packer or bridge plug. A removable cover can overlay the surface to be bonded to the tubular and the cover can come off in a variety of techniques before the members to be bonded are radially extended. An acrylic adhesive can be the bonding agent. The packer or bridge plug can be made of mostly or entirely non-metallic materials to facilitate mill out.

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 to a driving force and configured to set the packing elements in the borehole, wherein the driving force is not tubing string pressure.

Abstract: A retrievable well packer for downhole operations, comprising an upper mandrel and a lower mandrel connected through a quick threaded connection, a hydraulic actuating assembly for downwardly moving under fluid pressure, a packing assembly for sealing against the well, first coupling mechanism between the upper mandrel and the hydraulic actuating assembly and second coupling mechanism between the lower mandrel and the hydraulic actuating assembly, with the second coupling mechanism connecting the lower mandrel and the hydraulic actuating assembly against rotation but permitting relative axial movement.