Abstract: A sand removal system configured to remove sand from a casing installed within a producing wellbore. The system utilizes a bottom hole assembly comprising a check valve sub and at least one sand removal tool. A swab cup installed within a vertical section the casing is used to create a pressure differential around the bottom hole assembly, causing fluid and sand to flow at a high velocity into the sand removal tool. The sand is caused to flow upstream where is later removed from the wellbore.

Abstract: A compression-set straddle packer with fluid pressure-boosted packer set has a two-part multicomponent mandrel and a multicomponent sliding sleeve that reciprocates within a limited range on an upper part of the two-part multicomponent mandrel. A two-part lower packer element compression sleeve in a lower part of the two-part multicomponent mandrel reciprocates on a packer element piston mandrel component and pressure-boosts compression of a lower packer element when high-pressure fluid is pumped into the straddle packer. A bias element constantly resists relative movement between the multicomponent mandrel and the multicomponent sliding sleeve and balances pressure-boost between the lower packer element and an upper packer element supported by the upper part of the two-part multicomponent mandrel.

Abstract: A plug includes a tubular conduit having a first end and a second end. The plug also includes a cap disposed over the first end of the tubular conduit and coupled thereto. The cap is configured to mate with a wireline adapter kit of a perforating string. The plug additionally includes a guide shoe disposed over the second end of the tubular conduit and coupled thereto. The guide shoe is configured to move along the tubular conduit from an unset position, away from cap, to a set position, toward the cap. A gripping assembly is disposed around the tubular conduit between the cap and the guide shoe and coupled to the guide shoe. A sealing assembly is disposed between the cap and the gripping assembly. The sealing assembly includes a first sealing band and a second sealing band. The first sealing band is disposed around the tubular conduit and has an annular lip.

Abstract: A technique facilitates servicing of a subterranean formation by treating a specific section of a well. The technique utilizes a straddle packer conveyed downhole and then activated via coiled tubing. The straddle packer comprises a first, e.g. upper, packer and a second, e.g. lower, packer which are deployed downhole into the wellbore to the specific section of the wellbore proximate a target formation zone. Once properly located, the straddle packer is uniquely activated by compression and tension inputs applied via the coiled tubing.

Abstract: A pipe-in-pipe bulkhead assembly has inner and outer rings spaced in concentric relation to define a thermally-isolating gap in the annulus between them. Interlocking formations project into the annulus from each of the rings, presenting confronting faces where they overlap radially. The gap extends between the longitudinally-spaced faces. A thermally-insulating spacer is interposed between the faces in the gap to carry axial mechanical loads between the inner and outer rings. Heating elements outside the inner ring extend longitudinally beyond the gap between the faces and along a longitudinal passageway that passes through or beside an interlocking formation of the inner ring. The spacer may be positioned before or after the outer ring is placed, for example as a discrete element or as an injected mass. An additional sealing mass may also be positioned in the annulus, for example by injection, to promote a gas-tight seal.

Abstract: A cover configured to dispose over a treatment port of a downhole treatment tool, the cover comprising a dissolvable material. A system for protecting treatment ports in a downhole treatment tool, the treatment tool having an outer surface and an inner bore, the inner bore in fluid communication with the outer surface through one or more treatment port orifices disposed on the outer surface of the treatment tool, and a dissolvable treatment port cover disposed in the fluid communication path of the treatment port. A method for treatment of a well including the steps of locating a treatment tool in a well, the treatment tool having a treatment port and a cover over the treatment port; setting an activation tool in the well; placing a treatment, applying pressure to rupture the cover; and unsetting the activation tool.

Abstract: A seat assembly includes a hollow frustocone; a slip subassembly interactive with the frustocone to anchor the frustocone in place during use. A seal disposed at the frustocone to receive a plug and upon receipt of the plug seal the plug to the frustocone and to a tubular structure in which the frustocone is anchored during use. A method for treating a borehole.

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: 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 method of cementing a wellbore, comprising delivering a diversion and movable isolation tool into the wellbore and thereby at least partially isolating a first wellbore volume from a second wellbore volume, the second wellbore volume being uphole relative to the first wellbore volume, passing fluid through the diversion and movable isolation tool into the first wellbore volume, substantially discontinuing the passing of fluid through the diversion and movable isolation tool into the first wellbore volume, passing fluid through the diversion and movable isolation tool into the second wellbore volume. A diversion and movable isolation tool for a wellbore, comprising a body comprising selectively actuated radial flow ports, and a fluid isolation assembly, comprising one or more segments, each segment comprising a central ring and at least one tab extending from the central ring.

Abstract: Further disclosed herein is a method for controlling fluid flow. The method includes, selectively deforming at least one selectively deformable member disposed between two tubular members that are radially aligned with one another, at least one of the at least one deformable member being positioned between a fluid inlet and a fluid outlet. The method further includes regulating flow of fluid by deforming the at least one deformable member positioned between the fluid inlet and the fluid outlet sufficiently to achieve a desired flow rate.

Abstract: A well conveyance apparatus for conveying equipment into a wellbore possessing long-lasting movable and slidable hydraulic seals against the interior of a borehole casing located within a wellbore in a geological formation in the earth that is caused to move by the application of pressurized wellbore fluids against the seals. The seals are allowed to rotate on bearings about the tool mandrel to prevent the build-up of torque on the seals to minimize wear and to extend the life of the seals. Vibratory means are attached to the tool mandrel to vibrate the sealing portion of the seals, so as the extend the life of the seals and to minimize wear of the seals. Sensor arrays provide information to a computer system that is used to control the vibratory means, pressure relief valves, and other parameters to minimize wear of the hydraulic seals.

Abstract: Fluid flow reduction or cessation in a wellbore or pipe may be provided. A body member may be longitudinally translated through a wellbore or pipe. The body member may have an external wall facing an internal wall of the wellbore or pipe. The body member may have an internal flow path configured to facilitate communication of fluid within the wellbore or pipe through the body member. A braking force may be applied to the body member to slow and stop translation of the body member through the wellbore or pipe. A first fluidic seal may be provided between the external wall of the body member and the internal wall of the wellbore or pipe. The first fluidic seal may restrict fluid within the wellbore from being communicated between the external wall of the body member and the internal wall of the wellbore or pipe. A second fluidic seal may be provided restricting fluid within the wellbore or pipe from being communicated through the internal flow path of the body member.

Abstract: A casing device for a borehole in the ground, in which an annulus is formed between the casing and the wall of the borehole, and in which the casing is provided with at least two packer groups, each including activatable packers, the packers being formed, in their active state, to seal the annulus, and at least one packer group of the activatable packers being connected to sliding sleeves, so that at least one group of packers is movable relative to the casing.

Abstract: System, devices, and methods are described relating to the treatment (e.g., perforating, fracturing, foam stimulation, acid treatment, cement treatment, etc.) of well-bores (e.g., cased oil and/or gas wells). In at least one example, a method is provided for treatment of a region in a well, the method comprising: positioning, in a well-bore, a packer above the region of the well-bore, fixing, below the region, an expansion packer, treating the region, the treatment fixing the packer, moving the expansion packer, and moving the packer after the moving of the expansion packer.

Abstract: System, devices, and methods are described relating to the treatment (e.g., perforating, fracturing, foam stimulation, acid treatment, cement treatment, etc.) of well-bores (e.g., cased oil and/or gas wells). In at least one example, a method is provided for treatment of a region in a well, the method comprising: positioning, in a well-bore, a packer above the region of the well-bore, fixing, below the region, an expansion packer, treating the region, the treatment fixing the packer, moving the expansion packer, and moving the packer after the moving of the expansion packer.

Abstract: A high expansion plug has multiple sealing elements and an extrusion barrier system that uses overlapping petals in a stack of rings. When setting the plug, the petals are elastically moved toward a surrounding tubular wall in an elastic deformation between a housing that surrounds the mandrel and a tapered ring on the mandrel. That sandwich controls the amount of deformation and allows a potential energy force to be stored in the petals that allows them to return toward their initial position when the set of the plug is released and the seals are allowed to relax and extend axially as they shrink radially. The plug can then be removed without milling. Expansions in the order of 25% of the initial seal dimension are contemplated.

Abstract: A system and method for positioning a tool within a wellbore, wherein the interior surface of a positioning apparatus includes one or more pluralities of grooves, each defining a selected profile. A tool is lowered into the positioning apparatus, having a blade in communication therewith. The blade includes a plurality of protruding members, which define a profile complementary to at least one of the selected profiles formed by one of the pluralities of positioning apparatus grooves. A biasing member, in communication with the blade, can continually bias the blade toward the interior surface of the positioning apparatus to cause the profile of the blade to engage within the corresponding complementary profile of the positioning apparatus. Positioning a tool in this manner is advantageous for locating cutting tools at a precise location to sever a joint, perforate casing or stack multiple tool operations at a fixed, targeted point within a wellbore.

Abstract: A temperature activated actuator installed on a tubular to actuate an adjacent device may include one or more shape-memory alloy elements. The elements may be coupled between a first portion and a second portion of a device, or the elements may be coupled between the tubular and a portion of the device. The elements are activated by raising the temperature to a transition temperature to cause metallurgical phase transformation, causing the elements to shrink and displace at least a portion of the device. The actuator may be used, for example, to actuate a centralizer from a run-in mode to a deployed mode or, alternately, to actuate a packing member from a run-in mode to an isolating mode. A nickel-titanium alloy, for example, may be used as the shape-memory alloy material from which the shape-memory element is made.

Abstract: Equipment for servicing subterranean wells, and in some cases, an apparatus and method for remotely launching cementing plugs during the primary cementation of a subterranean well. The top plug and bottom plug are launched by different mechanisms, thereby preventing premature release of the top plug during a cementing operation.

Abstract: Anti-extrusion devices, packer elements, and inflatable packers include shape memory polymer (SMP) materials to enhance the operation of a packer, a bridge plug, or other downhole isolation tool. Seal system use seals of various material including SMP materials as booster for the seal produced. Tool for flow shut-off and sliding sleeve applications use SMP materials to open or close off flow through a tool.

Abstract: A high expansion plug has multiple sealing elements and an extrusion barrier system that uses overlapping petals in a stack of rings. When setting the plug, the petals are elastically moved toward a surrounding tubular wall in an elastic deformation between a housing that surrounds the mandrel and a tapered ring on the mandrel. That sandwich controls the amount of deformation and allows a potential energy force to be stored in the petals that allows them to return toward their initial position when the set of the plug is released and the seals are allowed to relax and extend axially as they shrink radially. The plug can then be removed without milling. Expansions in the order of 25% of the initial seal dimension are contemplated.

Abstract: An apparatus for regulating fluid-flow during a primary cementing job comprises a bottom cementing plug, adapted to house a one-way valve and means to regulate fluid flow through the plug interior. The apparatus is useful for minimizing or preventing free fall or U-tubing during primary cementing. The apparatus is compatible with conventional cementing-plug launching systems.

Abstract: A probe for establishing fluid communication between a downhole tool and a subterranean formation is provided. The downhole tool is positioned in a wellbore penetrating the subterranean formation. The probe includes a platform operatively connected to the downhole tool, at least one packer operatively connected to the platform, the packer having at least one hole extending therethrough and at least one embedded member disposed in the packer for enhancing the operation of the packer as it is pressed against the wellbore wall.

Abstract: Equipment for servicing subterranean wells, and in some cases, an apparatus and method for remotely launching cementing plugs during the primary cementation of a subterranean well. The top plug and bottom plug are launched by different mechanisms, thereby preventing premature release of the top plug during a cementing operation.

Abstract: An annular packer device that is expandable in an annulus between an inner body and an outer boundary. The annular packer is sealingly movable along at least one of the inner body and the outer boundary. A method of sealing an annulus formed between a pipe and a borehole in a subterranean well can include positioning an annular packer sealingly around the pipe, expanding the packer into sealing engagement with the borehole, and permitting the pipe to displace relative to the packer while the packer remains sealingly engaged with the borehole.

Abstract: Retrievable bridge plug used in oil and gas wells comprises a setting and anchoring mechanism, a locking and releasing mechanism and a sealing and anti-adhering mechanism. The bridge plug in which a self-lock mechanism is placed can be lowered through an coiled tubing or wireline, and provide reliable bi-directional sealing, and can be taken out by a specific tool after setting, in order to be used repeatedly after simple maintenance. By replacing its mandrel, the bridge plug can be refitted into a squeezing bridge plug, a conventional one and a hook-wall bridge plug to be used in a temporary/permanent and selective blocking operation. Also, the bridge plug can be associated with other downhole tools to perform well test, layer protection and snubbing.

Abstract: A packer includes first and second external seal elements. The first external seal element is adapted to form an annular seal in the well. The second external seal element is adapted to be moved in response to fluid in the well to produce a force to at least partially assist an operation of the packer.

Abstract: A probe for establishing fluid communication between a downhole tool and a subterranean formation is provided. The downhole tool is positioned in a wellbore penetrating the subterranean formation. The probe includes a platform operatively connected to the downhole tool, at least one packer operatively connected to the platform, the packer having at least one hole extending therethrough and at least one embedded member disposed in the packer for enhancing the operation of the packer as it is pressed against the wellbore wall.

Abstract: A subterranean well tool is provided for sealing along a section of a wall of the well and is carried on a conduit into the well. The tool is designed to be comparatively short in length to afford easier mill or drill out subsequent to the tool's useful need in the well. A plurality of anchoring elements and seal means are provided for respective anchoring and sealing engagement along the wall of the well in concert and substantially concurrently with one another when the tool is shifted to the set position. The anchoring means are sandwiched in between first and second, or upper and lower, sets of seal means.

Abstract: A packer assembly for use in wellbore operations includes a first packer and a second packer interconnected by an adjustable length spacer. The spacer provides a mechanism for adjusting the distance between the first packer and the second packer when the assembly is positioned in a wellbore.

Abstract: A fluid loss control system having a loss control valve and a plurality of zones including an isolation assembly disposed in a wellbore and a string having a stinger at a downhole most end thereof. The string is supportive of a moveable seal at a selected position uphole of the stinger, the position being calculated to cause engagement of the seal with the isolation assembly and to position the moveable seal to facilitate fluid-flow around the seal when the stinger is engaged with a seal bore of one of the plurality of zones. A method for controlling fluid loss including isolating a fluid column uphole of a pressure seal spaced from the lower completion, opening a fluid loss control valve, stabbing a stinger into a seal bore of the lower completion, and positioning the seal to facilitate fluid flow therearound.

Abstract: A debris barrier for a retrievable mechanical set packer is held retracted for run in. It is held spaced apart from upper slips and uses a spring bias that acts on the slips to keep them energized to also energize the barrier to the extended position to keep debris out of the upper slips when the packer is set. The debris barrier is preferably a sleeve that is axially compressed by the setting procedure to increase in diameter and span the gap between the packer mandrel and the set upper slips. Retrieving the packer is enabled by a retraction of the debris barrier as the upper slips are undermined with rotation and pickup force on the packer mandrel. The lack of a debris barrier could prevent retrieval of the packer in well bores where debris is present and has a tendency to settle around and more critically under the upper slips.

Abstract: A technique is provided for preventing buckling of a service tool assembly during a sand control operation in a wellbore. A completion assembly and a service tool assembly are positioned in a wellbore. An anti-buckling mechanism is positioned to limit the buckling load effects that can otherwise be experienced by the service tool assembly during the sand control operation.

Abstract: A packer includes first and second external seal elements. The first external seal element is adapted to form an annular seal in the well. The second external seal element is adapted to be moved in response to fluid in the well to produce a force to at least partially assist an operation of the packer.

Abstract: An apparatus for radially expanding and plastically deforming a tubular member.

Abstract: A packer element for use in forming a fluid pressure barrier within a wellbore. The packer element uses a thermoplastic component to accomplish the seal against the interior diameter of a surrounding tubular and an energizing component that is preferably formed of elastomeric material. The thermoplastic component of the packer element provides a sealing surface and defines an energizing chamber within. An energizing chamber is defined within the thermoplastic component and contains energizing elements that, when axially compressed, will urge the sealing surface of the thermoplastic component into sealing engagement with the surrounding tubular.

Abstract: A fluid loss control system having a loss control valve and a plurality of zones including an isolation assembly disposed in a wellbore and a string having a stinger at a downhole most end thereof. The string is supportive of a moveable seal at a selected position uphole of the stinger, the position being calculated to cause engagement of the seal with the isolation assembly and to position the moveable seal to facilitate fluid-flow around the seal when the stinger is engaged with a seal bore of one of the plurality of zones. A method for controlling fluid loss including isolating a fluid column uphole of a pressure seal spaced from the lower completion, opening a fluid loss control valve, stabbing a stinger into a seal bore of the lower completion, and positioning the seal to facilitate fluid flow therearound.

Abstract: A device and a method are provided for the hydraulic fracturing of multiple zones in a well bore. A stinger carries a plurality of packers into a well bore. Each packer is separably connected to each adjacent packer. As each packer is sequentially secured in the well bore, the stinger is withdrawn from the secured packer and the process is repeated as the remaining packers are sequentially secured and separated.

Abstract: An apparatus, system, and method useful for discouraging the extrusion of at least one deformable member of a device into a space adjacent to the deformable member when the device is disposed within a borehole and the deformable member extends from the device to the borehole wall involves at least one expandable member disposed upon the device. The expandable member is expandable into the annulus to reduce the width thereof and retractable therefrom to allow movement of the device within and out of the borehole and redeployment of the expandable member. The apparatus, system, and method are particularly suited for limiting the extrusion of packer elements.

Abstract: A retrievable packer (50) for establishing a sealing and gripping engagement between a tubing string and a well casing (34) disposed in a wellbore is disclosed. The retrievable packer (50) comprises a collet member (64) that is slidably disposed about a packer mandrel (52). The collet member (64) has a first operating position wherein the collet member (64) applies an axial force on a support ring (76) to positively position the support ring (76) at least partially between a first slip wedge (90) and the packer mandrel (52) to set a seal assembly (96, 98, 100). In addition, the collet member (64) has a second operating position wherein the collet member (64) applies an axial force on a slip assembly (80) to set the slip assembly (80).

Abstract: A device and a method are provided for the hydraulic fracturing of multiple zones in a well bore. A stinger carries a plurality of packers into a well bore. Each packer is separably connected to each adjacent packer. As each packer is sequentially secured in the well bore, the stinger is withdrawn from the secured packer and the process is repeated as the remaining packers are sequentially secured and separated.

Abstract: The borehole packer is for sealing the annular space around a pipe in a borehole. The packer is pre-manufactured, in-factory. To give the packer the rigidity it needs for handling and transport, the packer is built around an inner sleeve of rigid (metal) mesh. Alternatively, the packer may be built around a cardboard tube, which is discarded as the packer is assembled onto the pipe. When the packing material is bentonite, the bentonite may be compression-moulded into annular-rings, and the packer is built up from the rings.

Abstract: A conventional thru tubing bridge plug is rendered in a more effective and useful downhole tool by incorporating a sensor module complete with preferably a plurality of downhole sensors to monitor downhole parameters such as but not limited to temperature and pressure both within the inflatable tool and in the annulus of the well created thereby.

Abstract: A high temperature, high pressure retrievable packer adapted for service under extreme operating conditions when the packer apparatus is held in the wellbore with a mechanical slip and a barrel slip. The barrel slip has a barrel slip body with a plurality of openings defined in the outer surface of the body. Cylindrical inserts are received in the openings. The cylindrical inserts define upward facing and downward facing gripping edges that will engage casing when the barrel slip body is radially expanded. The inserts are preferably tungsten carbide inserts. A sufficient number of inserts are included along the length and around the circumference of the barrel slip so that the barrel slip can get a good grip in the casing wall. Separate metals may be used for the barrel slip body and the inserts so that a higher yield strength alloy steel may be utilized than is possible with other barrel slip arrangements.

Abstract: A high temperature, high pressure retrievable packer adapted for service under extreme operating conditions when the packer apparatus is held in the wellbore with a mechanical slip and a barrel slip. The barrel slip has a barrel slip body with a plurality of openings defined in the outer surface of the body. Cylindrical inserts are received in the openings. The cylindrical inserts define upward facing and downward facing gripping edges that will engage casing when the barrel slip body is radially expanded. The inserts are preferably tungsten carbide inserts. A sufficient number of inserts are included along the length and around the circumference of the barrel slip so that the barrel slip can get a good grip in the casing wall. Separate metals may be used for the barrel slip body and the inserts so that a higher yield strength alloy steel may be utilized than is possible with other barrel slip arrangements.

Abstract: A method and apparatus is disclosed for downhole remediation. In the preferred embodiment, a bridge plug and service packer can be run into a well on coiled or rigid tubing. The assembly is capable of being set without rotation. The service packer is locked against setting until it is separated from the bridge plug. Setting of the bridge plug closes a passage within it that had been open to facilitate circulation during run-in. The service packer is set with longitudinal movements using an indexing mechanism. At the conclusion of the procedure, the service packer is released and lowered to recapture the bridge plug. The bridge plug is equalized and released to allow the assembly to be repositioned elsewhere in the wellbore or retrieved. The spacing between the packer and bridge plug can be varied as desired.

Abstract: In a retrievable packer adapted for service under high temperature and high pressure operating conditions, improved retention of the packer in the wellbore is achieved by use of an inventive slip and wedge system, wherein the cones on the wedges are spaced a progressively slightly greater distance apart from their corresponding slip cones, from the centermost slip cone to the outermost slip cone. This forces the center of the slip to be loaded first. As greater forces are exerted on the wedges from end to end, the wedge will deform slightly and the next cone of the wedge will make contact with its matching portion of slip. Thereby, as the wedges are loaded higher and higher, more wedge cones come into bearing contact with the slip. Further, a barrel slip is used, to provide a uniform circumferential distribution of forces. This design effectively allows initial setting of the packer with very little slip tooth contact area. This permits the slip to quickly get a good grip into the casing wall.

Abstract: In a retrievable packer adapted for service under high temperature and high pressure operating conditions, improved retention of the packer in the wellbore is achieved by use of an inventive slip/wedge system, wherein the cones on the wedges are spaced a progressively slightly greater distance apart from their corresponding slip cones, from the centermost slip cone to the outermost slip cone. This forces the center of the slip to be loaded first. As greater forces are exerted on the wedges from end to end, the wedge will deform slightly and the next cone of the wedge will make contact with its matching portion of slip. Thereby, as the wedges are loaded higher and higher, more wedge cones come into bearing contact with the slip. Further, a barrel slip is used, to provide a uniform circumferential distribution of forces. This design effectively allows initial setting of the packer with very little slip tooth contact area. This permits the slip to quickly get a good grip into the casing wall.

Abstract: An improved well packer for removeable installation in a well casing. A mandrel is associated with the packer for latching engagement with the well packer which can be released from the well packer by a simple rotation of the mandrel by no more than one-quarter turn. Arcuate 60.degree. segments of teeth are formed on opposing sides of the mandrel and contact ratchetable arcuate 60.degree. segments of teeth on opposing sides of the packer such that when the mandrel is moved longitudinally in relation to the packer, the ratchetable teeth can engage the fixed teeth on the mandrel. When it is desired to release the mandrel from the packer assembly, the mandrel is rotated no more than one-quarter turn and the mandrel teeth move out of engagement with the 60.degree. segment of the ratchetable teeth, thus disengaging the mandrel from the packer.