Abstract: Methods and apparatuses used in locking downhole tools such as locking packers, bridge plugs, and frac plugs are shown herein that decrease the loss of energy during pack-off.

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: An internal completion string is anchored within a closed casing valve of a production liner in a wellbore. The internal completion string comprises a packer and a shifting tool. The production liner comprises a casing valve having a port and a moveable member. The annulus defined between the production liner and the internal completion string is sealed, and the shifting tool is remotely operated to move the moveable member away from the port, thereby opening the casing valve.

Abstract: A packer assembly can include an annular seal element and an end ring including leaves formed on a body of the end ring, whereby the leaves are biased radially outward when the seal element extends radially outward. A method of sealing an annulus in a subterranean well can include positioning a circumferential series of leaves radially outwardly overlying an annular seal element of a packer assembly, and the leaves pivoting radially outward in response to swelling of the seal element. Another packer assembly can include an annular seal element which swells in response to contact with a selected fluid in the well, and an end ring including an end ring body with a removable portion being engaged with the end ring body via interlocking profiles.

Abstract: A non-damaging slip assembly includes slips having grit on a smooth surface, the slips preferably made from a ductile material, such that the slips do not cause damage to the wall of a tubular when the slips are set. The slips fail under tensile force during setting. The cone used to expand the slips may have slits that narrow during setting of the slips. The slip assembly may be used to anchor a variety or devices inside a tubular. A drillable, non-damaging bridge plug using the non-damaging slip assembly has a threaded mandrel holding the cone by threads inside the cone. When the slips are set, the slits in the cone narrow such that threads in the cone do not allow rotation of the slips as they are drilled. The bridge plug can be drilled by a PDC bit without damaging the tubular.

Abstract: A downhole tool or plug includes a mandrel with an element, a slip ring, and a cone pressable between an upper push sleeve assembly and a lower anvil. The upper push sleeve assembly including a lock ring having one or more interior teeth on an interior of the lock ring. A mandrel sleeve is at least partially received within a recess in the mandrel and affixed with respect to the mandrel, and has one or more exterior teeth on an exterior of the mandrel sleeve.

Abstract: An improved downhole tool apparatus for limiting the extrusion of a sealing elements in downhole tools that use segmented retaining assemblies, retaining shoes or retaining limiters. The apparatus provides for locating the retaining bands for the retaining assemblies in a groove on the inner surface of the retaining assembly so that the bands are protected from breaking prematurely by inadvertently contacting the wellbore, casing within a wellbore, or other object.

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 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: One or more fluid-jetting subs having jet ports and a packer element are incorporated into a completion string for deployment into a wellbore for perforation and treatment operations. The packer element, being either an inflatable packer element or a compressible packer element, is downhole of the jet ports and is fluid pressure actuated. Pressure in the completion string is maintained at a pressure higher than in the annulus thereabout to keep the packer set for sealing the annulus therebelow while fluid is delivered through the jet ports for perforating or treatment such as fracturing.

Abstract: A downhole apparatus having a radially expanding portion and a support structure are described. The support structure comprises an attachment means for coupling to the apparatus and a support portion configured to be deployed from a first unexpanded condition to a second expanded condition by expansion of the apparatus. In one aspect of the invention, the downhole apparatus is expanded by exposing the swellable material to at least one predetermined fluid, and the support structure abuts the swellable material in its expanded form. A method of use and its application to a well packer, a hanging member, an anchor and a centralising apparatus are described.

Abstract: A downhole formation testing and sampling apparatus. The apparatus includes an expandable packer having a radially contracted running configuration and a radially expanded deployed configuration. At least one elongated sealing pad is operably associated with the expandable packer such that operating the expandable packer from the running configuration to the deployed configuration establishes a hydraulic connection between the at least one elongated sealing pad and the formation. The at least one elongated sealing pad has at least one opening establishing fluid communication between the formation and the interior of the apparatus. In addition, the at least one elongated sealing pad has an outer surface operable to seal a region along a surface of the formation to establish the hydraulic connection therewith. The at least one elongated sealing pad further has at least one recess operable to establish fluid flow from the formation to the at least one opening.

Abstract: A downhole apparatus, such as a wellbore packer, is provided with a swellable member and a fluid supply assembly. The fluid supply assembly is to receive fluid and expose the swellable member to the fluid to cause expansion of the swellable member, and comprises a support structure for supporting the swellable member on the body. In a preferred embodiment, the support structure defines a chamber and is configured to allow fluid to flow and access the swellable member. A method of use and method of sealing a wellbore is described.

Abstract: The present invention relates to an expansion device to be inserted in a casing or well tubular structure for expanding an annular barrier downhole. The annular barrier comprises a tubular structure for mounting as part of the well tubular structure, an expandable sleeve surrounding the tubular structure, and a connection part connecting the expandable sleeve with the tubular structure. The tubular structure has an opening and two projecting elements decreasing an inner diameter of the tubular structure. The expansion device comprises a tubular part extending between a first and a second end part, the tubular part comprising at least one opening arranged between the first and the second end; an inner face surrounding an inner space; and an outer face. Furthermore, the expansion device comprises at least a first and second sealing element sealingly connected to the outer face of the tubular part.

Abstract: A packer device for forming a fluid seal between an inner tubular member and an outer tubular member. The packer device includes a swage assembly that is expandable from a reduced diameter condition to an expanded diameter condition and a substantially deformable packer element for contacting and forming a fluid seal against a surrounding tubular.

Abstract: A downhole packer for providing a seal in a well bore to allow integrity testing of well bore with drill ahead capability immediately thereafter has a disengageable packer assembly wherein the packer element may be rendered disengageable by mounting the packer to the string using a tool body (61) provided with a sleeve (62) bearing a packer element (55), wherein the body is initially restrained from movement within the sleeve by engagement of an internal selectively movable retaining element (64). A method of testing a well bore with follow on drilling after disengaging the packer element is described.

Abstract: A rubber pocket is described that is suitable for use on tubing, such as a packer-type seal, on casing, such as a cement-type seal, or on liners. The rubber pocket may contain cement particles, rubber particles, swellable particles, cement filled rubber particles, cement filled swellable particles, calcium oxide, magnesium oxide, magnesium sulfate, iron (III) oxide, calcium sulfoaluminate, clay, magnetic particles and/or reactants such as crosslinkers, retardants or epoxy. The particles may be bulk spheres, bulk fibers, hollow spheres, hollow fibers, etc. The rubber pocket or bladder may also be fully or partially filled with fluids such as polymer reactants. The pocket may also be empty or contain a small volume of reactants. The slurry or epoxy or other type of fluid and granular solid or injectable matter can be injected after the completion positioning downhole.

Abstract: The invention provides a method and apparatus for use in a wellbore gravel pack operation. The method comprises providing an apparatus in a downhole annulus. The apparatus comprises a mandrel and a swellable element formed from a material selected to increase in volume when exposed to a downhole stimulus. The method comprises placing a gravel pack below the apparatus via the downhole annulus in which the apparatus is located, and placing a gravel pack above the apparatus. Subsequent to placing the gravel packs, the swellable element is increased in volume to create an annular barrier in the wellbore. The invention allows isolation of multiple intervals of a well in a single gravel pack operation using swellable elastomers, and does not rely on the use of shunt tube alternate path systems.

Abstract: In one aspect, an apparatus for use in a borehole includes a tubular disposed in the borehole. The apparatus also includes an expandable device disposed outside the tubular and proximate a selected device, the expandable device including a material that causes the expandable device to expand from a first shape to a second shape when exposed to an activating fluid. In addition, the expandable device reduces vibration of the selected device when the expandable device is in the second shape.

Abstract: A backup ring assembly is disposed between opposed cones. The assembly rides up a wedge ring to contact a surrounding tubular when the opposed cones are pressed axially together to also compress the sealing element. The backup ring assembly has nested split rings that are slant cut for the split. The split for the nested rings can be circumferentially aligned or offset. Another ring is stacked axially adjacent the nested rings and has a slant cut for a split that is preferably rotated from the slant cuts of the nested rings. The interface of the nested rings can be along a line that is parallel to the mandrel axis or askew to the mandrel axis. The preferred material is a non-metallic composite material.

Abstract: A swellable packer can include a material which swells when contacted with a swelling fluid, and a barrier comprising a highly crystalline polymer which is substantially impermeable to the swelling fluid. A method of controlling swelling of a material can include positioning the material and a barrier in a well, the barrier preventing contact between the material and a swelling fluid, the barrier comprising a polymer, and increasing a permeability of the barrier to the swelling fluid in response to the barrier polymer being heated to its crystallization temperature. A well system can include a material which swells in response to contact with a hydrocarbon gas, and a barrier which comprises a crystalline polymer, the polymer being substantially impermeable to the hydrocarbon gas, whereby the polymer initially prevents swelling of the material, but the polymer becomes increasingly permeable to the hydrocarbon gas when heated to its crystallization temperature.

Abstract: Conventional formation evaluation with dual inflatable packers includes the steps of pressurizing the packers so as to isolate an annular portion of the borehole wall, collecting one or more samples of formation fluid via the isolated portion of the borehole wall, and depressurizing the packers so as to permit movement of the mandrel within the borehole. A sampling method and apparatus that utilize one or more of the following to advantage is provided: restricting deformation of the packers during inflation using an annular bracing assembly; actively retracting the packers using ambient borehole pressure; and substantially centralizing the mandrel intermediate the packers so as to resist buckling of the mandrel.

Abstract: A method described herein involves lowering a tool into a wellbore adjacent a subterranean formation; inflating a first packer on the tool to initiate a fracture of the formation; inflating second and third packers on the tool to seal an interval of the wellbore containing the fracture, the first packer being between the second and third packers; and pumping fluid into the interval to increase a pressure in the interval to propagate the fracture.

Abstract: Embodiments of the present disclosure generally provide a packer for use within a conduit, such as casing, having non-extrusion rings. The non-extrusion ring is comprised of rigid segments, a support ring and an elastic matrix.

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: An apparatus including a downhole tool for conveyance in a wellbore extending into a subterranean formation. The downhole tool includes a feature to physically interface a sidewall of the wellbore, and first and second setting pistons each extendable from the downhole tool opposite the feature. The downhole tool also includes a rigid member spanning and extendable with the first and second setting pistons, wherein a length of the rigid member is variable.

Abstract: A downhole tool for use in a well has a mandrel with an expandable sealing element disposed thereabout. The mandrel has a head portion threadedly connected thereto. A shoulder in the head portion and an upper end of the mandrel define an annular space. A sleeve with a bore therethrough may be positioned in the annular space. The head portion may be removed and a solid plug installed so that it fits within the annular space and so that the downhole tool will act as a bridge plug. The downhole tool has slip rings made up of a plurality of individual slip segments that are adhesively bonded to one another at the sides thereof.

Abstract: An apparatus for use in a wellbore is provided. The apparatus comprises a mandrel, a sealing element carried on the mandrel, the sealing element being radially expandable from a first run-in diameter to a second set diameter in response to application of axial force on the sealing element, and an extrusion limiting assembly carried on the mandrel and proximate the sealing element. The extrusion limiting assembly comprises a plurality of separate segments and a first circumferential band that retains the plurality of segments in a ring shape and substantially covers an outer circumferential surface of the plurality of segments while in a run-in condition of the apparatus.

Abstract: A sealing and/or anchoring element for use in pipelines. The sealing and/or anchoring element includes at least one helical element disposed around a string section, with the helical element being configured so as to be able to expand radially towards an inner wall of the pipeline as the circumferential diameter thereof is increased.

Abstract: Device for carrying a replacement safety valve in a well tube, with a straddle structure for placement inside a damaged “Down Hole Safety Valve” nipple seal area. It is comprising a pair of sealing assemblies (15, 16) to be activated upon setting of the device to seal said nipple seal area, and a locking dog assembly (17) for locking the device in the well tube, said elements being carried by a tubular mandrel (12). At least one of the sealing assemblies (15, 16) comprises a expandable element (22; 34) being activated by a pair of annular press elements (19, 20).

Abstract: A packer having a swellable element is configured for axial expansion of the swellable element. The axial expansion causes the slip mechanism to deploy and engage a sidewall of a tubular or casing. The axial expansion may directly cause activation of the slip mechanism, or may trigger a triggering mechanism to activate a spring-loaded slip mechanism. The swellable element may be the same element used for sealing the packer to the sidewall, or may be a sleeve dedicated for deployment of the slip mechanism.

Abstract: An apparatus including a downhole tool for conveyance in a wellbore extending into a subterranean formation. The downhole tool includes a mandrel, and a first packer and a second packer expandable from the mandrel into contact with a wall of the wellbore. The downhole tool includes a standoff coupled to the mandrel between the first packer and the second packer and having a rigid outer perimeter that is diametrically larger than an outer perimeter of the mandrel.

Abstract: An anchor system includes an anchoring device. The anchoring device is operably connected to at least one of a restriction indicator and a load isolation device each of which include a release member that releases at a selected load in order to ensure setting of the anchor at a desired location. A method is included.

Abstract: An isolation packer. The packer is both an inflation packer and swell-based. That is, an outer shell or bladder may be utilized in conjunction with internal swell material. In advance of inflation, a void or cavity may be disposed between the inner surface of the shell and an outer surface of the swell material. Thus, fluid inflation of this void may result in an inflation that becomes swell-material filled until the void is eliminated leaving behind a more unitary and swollen packer of enhanced reliability.

Abstract: Embodiments of the disclosure pertain to a composite slip for a downhole tool, the composite slip having a circular slip body having one-piece configuration with at least partial connectivity around the entire circular slip body, and at least two grooves disposed therein. In aspects, the slip body may be made from one of filament wound material, fiberglass cloth wound material, and molded fiberglass composite.

Abstract: Embodiments of the disclosure pertain to an anti-rotation assembly for a downhole tool, the anti-rotation assembly having an anti-rotation device; and a lock ring engaged with the anti-rotation device, wherein the anti-rotation device is selected from a group consisting of a spring, a mechanically spring-energized member, and composite tubular piece. Other embodiments pertain to a method of operating a downhole tool that includes an anti-rotation assembly.

Abstract: Embodiments of the disclosure pertain to a mandrel for a downhole tool that may include a body having a proximate end with a first outer diameter and a distal end with a second outer diameter; a first set of threads disposed on the distal end; and a transition region formed on the body between the proximate end and the distal end. In aspects, the mandrel may be made from filament wound composite material.

Abstract: Embodiments of the disclosure pertain to a metal slip for a downhole tool that may include a slip body; an outer surface comprising gripping elements; and an inner surface configured for receiving a mandrel. In aspects, slip body may include at least one hole formed therein, and a buoyant material may be disposed in the hole.

Abstract: A packer arrangement for forming a seal between an inner tubular string and an outer tubular string in a borehole includes: an outer tubular string member defining an axial flowbore and having an associated packer setting mechanism; a packer device disposed at least partially within the outer tubular string member to form a seal against an inner tubular string, the packer device including a degradable layer for temporarily and at least partially protecting the packer device; an inner tubular string member to be disposed within the flowbore of the outer tubular string member; and an actuator carried on the inner tubular string member, the actuator being operable to actuate the packer setting mechanism to set the packer device against the inner tubular string.

Abstract: Slip members for use with downhole tools comprise a body formed of a first or body material and one or more hard material elements formed of a second or element material. The element material is harder than the body material. The hard material element is disposed through the body and in communication with a first surface and a second surface of the body, the second surface being disposed opposing the first surface. During manufacturing of the slip members, the hard material element may extend outwardly from one or both of the first and second surfaces. After manufacturing, the hard material element can be shaped to provide a gripping member.

Abstract: Disclosed herein are sealing assemblies which include a mandrel; an inner element formed around the mandrel; an outer element formed around the inner element; and a plurality of slats arranged between the inner and outer elements. The slats have a friction-reducing agent on the surface of the slats. Also disclosed herein are methods for zonal isolation within a wellbore. The methods include providing a mandrel; providing an inner element formed around the mandrel; providing an outer element formed around the inner element; providing a plurality of slats arranged between the inner and outer elements; and axially compressing the inner element and the outer element to radially expand the inner element and outer element. The slats have a friction-reducing agent on their surface.

Abstract: Disclosed are apparatuses useful for forming a seal in a subterranean wellbore and methods for using the disclosed apparatuses for forming a seal in a wellbore.

Abstract: Apparatuses for restricting fluid flow through a well conduit comprise a tubular member having a radially expandable seat member disposed within the tubular member. The radially expandable seat member comprises one or more arcuate members, each having first and second ends. The radially expandable seat member comprises a first position in which the first and second ends are disposed relative to each other to provide a first inner diameter opening through the radially expandable seat member for receiving a plug element, and a second position in which the first and second ends are moved radially outward relative to one another to provide a second inner diameter opening through the radially expandable seat member, the second inner diameter being greater than the first inner diameter thereby facilitating the plug element passing through the radially expandable seat member.

Abstract: A method of removing a downhole tool from a wellbore comprising contacting the tool with a heat source wherein the tool comprises at least one load-bearing component comprising a thermally degradable material. A method of reducing the structural integrity of a downhole tool comprising fabricating the load-bearing components of the tool from a thermally degradable material. A method of removing a downhole tool comprising mechanically milling and/or drilling the tool from a wellbore wherein the tool comprises at least one load bearing component comprising a phenolic resin wherein the phenolic resin comprises a rosole, a novalac or combinations thereof.

Abstract: A packer for sealing against an inner cylindrical mandrel and a wellbore wall.

Abstract: A method of forming a swellable oilfield apparatus provides an apparatus with a body of swellable elastomeric material which increases in volume on exposure to at least one triggering fluid, and the surface energy of the swellable elastomeric material is modified to increase the water-wettability of the swellable elastomeric material. The swellable elastomeric material may comprise a base elastomer and at least one additive selected to modify the surface energy. Alternately, the swellable elastomeric material may comprise a base elastomer treated by an electrical treatment process to modify the surface energy of the swellable elastomeric material. An apparatus constructed according to the method provides improved swelling performance in aqueous fluids.

Abstract: Methods and apparatus include tubing expanded to create a seal in an annulus surrounding the tubing. The tubing includes a sealing material selected to cause forming of undulations in a diameter of the tubing upon expansion of the tubing. Various factors of the sealing material such as deviations in its thickness influence sealing performance of the tubing with the sealing material.

Abstract: A downhole tool having a body or structural component comprises a material that is at least partially consumed when exposed to heat and a source of oxygen. The material may comprise a metal, such as magnesium, which is converted to magnesium oxide when exposed to heat and a source of oxygen. The downhole tool may further comprise a torch with a fuel load that produces the heat and source of oxygen when burned. The fuel load may comprise a flammable, non-explosive solid, such as thermite.

Abstract: A downhole tool having a body or structural component comprises a material that is at least partially consumed when exposed to heat and a source of oxygen. The material may comprise a metal, such as magnesium, which is converted to magnesium oxide when exposed to heat and a source of oxygen. The downhole tool may further comprise a torch with a fuel load that produces the heat and source of oxygen when burned. The fuel load may comprise a flammable, non-explosive solid, such as thermite.

Abstract: A downhole tool provided within a casing string for use in cement staging operations. The tool includes a sleeve in the tool that selectively slides downward under pressure to expose ports formed in a side wall of the tool. Also, an annulus through the tool is selectively blocked so that cement in the casing string flows radially outward through the ports and into an annulus between the tool and a wellbore. An inflatable packer is included that is integral to the body of the tool and is inflated with a fluid that is pushed into the packer as the sleeve slides downward. An optional expanding agent can be included in the packer that is a metal oxide and is activated with the addition of water.