Abstract: Linear movement via a sliding mandrel configured to translate axially is converted into radial movement to compress a packer. The packer is configured to seal an item of oilfield equipment typically in a subsea environment. The packer may also be used to return or reverse the radial movement and/or the linear movement.

Abstract: A technique includes deploying a seat assembly having a plurality of segments into a tubing string installed in a well and expanding the seat assembly at a downhole location in the well to secure the assembly to the tubing string and form a seat that is adapted to receive an untethered object. The technique includes receiving the untethered object in the seat of the seat assembly and using the received untethered object in the seat assembly to perform a downhole operation in the well.

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

Abstract: A ring member for a downhole apparatus includes a swellable material selected to increase in volume on exposure to at least one triggering fluid. The ring member is configured to cooperate with a swellable member disposed on a body of the apparatus, and may function as a gauge ring or a retaining member. The ring member is secured to the apparatus via a coupling arrangement which couples the body to an adjacent well string section. The ring member is threaded into the well string. Alternately, the ring member may be disposed over an upstanding formation such as a coupling sleeve by clamping.

Abstract: A well barrier is for sealing off a first portion of a wellbore from a second portion of the wellbore, the first portion having a higher fluid pressure than the second portion. The well barrier is held in place in the wellbore by a holding means. The well barrier is preshaped to disintegrate in at least three barrier elements upon activation of a disintegration means, at least one of the barrier elements having a surface area facing the first portion of the wellbore that is larger than the surface area facing the second portion of the wellbore. A method is for controlling a disintegration of the well barrier.

Abstract: A process for making packer elements for use in sealing an area between surfaces in a wellbore and packer elements formed from that process. The process includes extruding an elastomeric material to form a tubular structure and machining the outer surface of the tubular structure to provide a desired surface geometry. The tubular structure may be machined to provide a contoured surface geometry. The tubular structure with a contoured surface geometry may be machined to form a plurality of packer elements, which are separated by cutting the tubular structure.

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 wellhead assembly having an inner tubular insertable into an outer tubular. A packoff is provided on an outer surface of the inner tubular for sealing between the inner and outer tubulars. The packoff includes an energizing ring, a U-shaped seal member, and a nut for retaining the seal member against the energizing ring. The seal member includes legs that are spaced apart by interaction with the energizing ring. The outer tubular has a bore wall that is profiled so that when the inner tubular is inserted into the outer tubular, an outer leg of the seal member is spaced radially outward from the bore wall until the inner tubular is landed in the outer tubular. When the inner tubular member is landed, a portion of the bore wall adjacent the outer leg tapers radially inward into sealing contact with the outer leg of the seal member.

Abstract: A pressure control apparatus and methodology related to a drilling operation has a housing such as, for example, a bearing assembly configured to engage an item of oilfield equipment being delivered through the oilfield pressure control apparatus. The housing has an upper and/or a lower portion with a seal element coupled to the upper and/or lower portion and configured to seal around the item of oilfield equipment. A guide is coupled proximate the seal element. The guide is configured to support and/or limit lateral deflection of the seal element during the lateral deflection of the seal element created by movement of the item of oilfield equipment.

Abstract: An isolation device with seal element having substantial elongation properties at a time of setting and insubstantial elongation properties at time of drill out. That is, the seal element may be constructed of materials that are geared toward providing effective temporary sealing, for example to support stimulation operations. The seal is also tailored to change elongation properties over time such that upon sufficient exposure to downhole conditions the elongation properties may be substantially reduced. Thus, drillable removal of the device and seal element may be readily attained without undue concern over stretchable tearing of the element leading to an accumulation of large debris left behind in the well.

Abstract: A swellable packer for use in a subterranean well can include a seal element with a swellable material which contracts in response to temperature decrease, and a temperature compensator which applies increased force to the seal element in response to temperature decrease. A method of compensating for thermal contraction of a swellable material in a subterranean well can include a temperature of the swellable material increasing in response to installing the swellable material in the well, and a temperature compensator applying an increased force in response to a temperature decrease occurring after the temperature increasing step. A well tool for use in a subterranean well can include a swellable material and a temperature compensator which applies an increased force when the swellable material contracts.

Abstract: A method for sealing a conduit in a spoolable wellbore intervention rod includes exposing an interior of the conduit at a location proximate the earth's surface while the spoolable rod is deployed in a wellbore. A curable sealing compound is introduced into the exposed interior of the conduit and the compound is allowed to cure.

Abstract: A downhole retrievable dual directional isolation tool is provided. The down hole tool comprises a mandrel, a compressor concentric with the mandrel, and a packing element disposed around the mandrel, wherein a body section of the packing element is asymmetrical.

Abstract: A downhole isolation tool for insertion in a wellbore, for allowing, when a ported sliding sleeve thereof is slidably positioned in a first position and when coupled to a lower end of said pump apparatus, fluids within a hydrocarbon formation to be drawn through such tool and allowed to pass to the pump apparatus for pumping uphole, and when such sliding sleeve is positioned in a second position and decoupled from said lower end of the pump assembly, for preventing said fluids from passing therethrough and uphole.

Abstract: A pump assembly for recovering hydrocarbons from downhole wells. The pump assembly comprising a seating surface adapted to sealingly engage an interior surface of a first circumferential seal means situated within production tubing when said pump assembly is in a downhole operative position. A downhole ported sleeve is further provided and comprises a first port means and a second port means. The ported sleeve is adapted to move within a seal sub comprising a lower seal means and an upper seal means. The first port means is positioned between the lower seal means and the upper seal means when the pump assembly is removed from the well, thereby preventing pressurized fluids and/or gases from reaching surface. A method for sealing a well upon removal of a pump is further disclosed.

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: The seal has a base ring that expands with the underlying supporting tubular. Extending from the base ring is a pleated structure with segments folded over each other so that the run in shape is small and up against the supporting tubular for run in. The pleated segments can have internal stiffeners that also add a bias radially outwardly when the structure is freed to move in that direction. A retaining band keeps the assembly retracted until tubular expansion defeats the band to allow the unitary structure to move out radially to the wellbore or surrounding tubular. The pleated portion unfolds and spans outwardly from the base ring to retain pressure differential in one direction while allowing fluid flow in the opposite direction. The assembly can be attached to a swage device so that pressure from above can drive one or more swage members to expand a tubular.

Abstract: Arrangements and packer devices having anti-extrusion backup rings that are expanded radially outwardly by a setting mechanism that lies proximate the elastomeric packer element that is being protected against extrusion. The setting mechanism can be a slip assembly that has a radially expandable slip element.

Abstract: Downhole tool packing element systems comprise a sealing element having a support system. The support system can include one or more of a first spacer ring, a second spacer ring, a third spacer ring, a mesh ring, and one or more petal rings. One or more of these components can be disposed at one or both of the upper end and/or lower end of the sealing element. When compressed, the sealing element is moved radially outward to engage an inner wall surface of a wellbore due to compressive forces of the one or more spacer ring(s), mesh ring, and/or petal ring(s). In certain embodiments, the lower end of one or more of the mesh ring(s) and/or petal ring(s) rotate outwardly toward the casing and, in certain embodiments, engage the casing to facilitate creation of the seal.

Abstract: A system for plugging an oil well after a blowout comprises a hollow drill string. A connecting device is loosely situated around the string. The connecting device has an upper surface, a side surface and a lower surface having a recess. An inflatable bladder comprises an impermeable material. A skirt has a plurality of rods, each of which are pivotally connected to the lower surface. The first fastening ring is configured to selectively allow the bladder to transition from an unfilled state to a filled state. A second fastening ring is configured to selectively allow the skirt to transition from a closed position to an open position. A stop having a beveled edge is secured to the drill string. The recess is configured to allow the connecting device to mate with the stop beveled edge.

Abstract: A process for fracturing a lined well uses a packer assembly in a liner string that provides a cement-free segment and interface with the formation. The device has multiple packers with inflatable elements that are run as an integral assembly. After the liner assembly is positioned, cement is circulated into the assembly and wiped from the interior of the liner string into the annulus. Pressure within the liner string is elevated to initiate time delays for the radial inflation of the packer elements. The inflation radially and axially displaces the cement surrounding the elements before the cement sets. Each packer is subsequently opened to expose the frac ports in the packer directly to the formation for frac operations.

Abstract: An apparatus positionable along a downhole string. The apparatus includes a flexible structure retained on a surface of the string in a first condition. The flexible structure movable by a flow to substantially fill an annular space between the string and a radially positioned structure in a second condition. A method of diverting fracturing treatments in a wellbore is also included.

Abstract: A seal assembly sealingly engages a packer that is retrievable from the packer. The seal assembly comprises a sealing structure for receiving by a seal bore of the packer, and a housing assembly defining an inner chamber and having at least one control line conduit and at least one flow conduit passage. The seal assembly further comprises at least one control line extending through the control line conduit into the inner chamber, and at least one flow conduit extending through the flow conduit passage into the inner chamber.

Abstract: A straddle packer tool for setting against a constraining wall includes: a drag assembly with a locking mechanism for locking a position of the drag assembly relative to the constraining wall; a mandrel installed in and axially moveable through an inner bore of the drag assembly; and a packing element housing including a first annular packing element and a second annular packing element spaced from the first annular packing element, the packing element housing positioned between a stop shoulder on the mandrel and the drag assembly, the packing element being settable to expand the first annular packing element and the second annular packing element by compression between the drag assembly and the stop shoulder. A valve sub including a pressure actuated piston is also described and may be operated to open using the straddle packer tool.

Abstract: A system for plugging an oil well comprises a hollow drill string. A connecting device having an upper surface, a side surface, and a lower surface having a recess is loosely situated around the drill string. A first skirt has a plurality of first rods that are each pivotally connected to the upper surface. A second skirt has a plurality of second rods that are each pivotally connected to the lower surface. A first fastening ring is configured to selectively allow the first skirt to transition from a closed position to an open position. A second fastening ring is configured to selectively allow the second skirt to transition from a closed position to an open position. A stop having a beveled edge is secured to the drill string. The recess is configured to allow the connecting device to mate with the stop's beveled edge.

Abstract: A sealing apparatus for sealing an annulus is described. The apparatus comprises a first sealing element (20) adapted for sealing the annulus against fluid pressure from above the sealing apparatus and adapted to be actuated by fluid pressure from above the apparatus and a second sealing element (40) adapted for sealing the annulus against fluid pressure from below the sealing apparatus and adapted to be actuated by fluid pressure from below the apparatus. In use, the sealing elements are arranged such that the second sealing element is above the first sealing element.

Abstract: In one embodiment, the sealing apparatus includes a mandrel having at least two portions, a first portion having a seal ring disposed on an exterior surface and a second portion without a seal ring disposed on an exterior surface. In one embodiment, the seal ring is disposed around the first portion. In another embodiment, the burst and collapse integrity of the first portion is substantially the same as the second portion.

Abstract: A system and method is provided for the controlled entry of a tubing string, and cable adjacent thereto, into a wellbore. A stationary housing is fit to a wellhead and has a bore in communication with the wellbore. The cable can be laterally displaced from the bore into a cable access formed into the side wall of the stationary housing for fitting a sealing assembly to the bore and engages a sealing surface therein. The sealing assembly seals tubulars passing therethrough. The cable access interrupts the sealing surface. A cable bypass sub is fit to the cable access and permits the cable to extend sealingly from above the sealing surface to the wellbore wherein the cable bypasses the sealing assembly and sealing surface. A seal reconstitutes the interrupted portion of the sealing surface at the cable access.

Abstract: A technique involves a packer formed as an expandable packer with an internal expandable bladder. A mechanical structure is deployed around the expandable bladder, and an anti-extrusion layer is located between the internal, expandable bladder and the mechanical structure. A separate protective layer is positioned between the internal, expandable bladder and the mechanical structure to reduce friction.

Abstract: A system and method for sealing a passage around a cable is disclosed. Embodiments of the system can include an axial passage, such as a conduit and subsea wellhead housing connected to a wellbore, that can have a cable extending therethrough. The system can include an upper restrictor and a lower restrictor for closing the axial passage. An injection module having an injector and a reservoir can be fluid communication with the axial passage at an axial location between the upper restrictor and the lower restrictor. The injector can discharge a curable sealant initially stored in the reservoir into the axial passage so that at least a portion of the sealant contacts the cable at the axial location of the restrictor while the cable remains static.

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

Abstract: A 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. A 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. The support assembly may be configured to direct a force from the swellable material to boost or energise a seal created between the radially expanding portion and a surrounding surface in use.

Abstract: Disclosed herein is a method of sealing a liner top packer to a tubular. The method includes, positioning the liner top packer within a tubular and moving a sleeve of the liner top packer in a first axial direction thereby radially deforming a first deformable metal member and a second deformable metal member. The method further includes sealably engaging the radially deformed first deformable metal member with a tubular and sealably engaging the radially deformed second deformable metal member with the first deformable metal member and a body of the liner top packer.

Abstract: A tool for setting an annular seal, including an inner body, a first outer body coaxial with the longitudinal axis, and a second outer body coaxial with the longitudinal axis, wherein the second outer body is coupled to the first outer body. The inner body is configured to rotate about a longitudinal axis of the tool and is configure to bias a retaining ring, the first outer body is configured to couple to a potion of the mineral extraction system, and the second outer body is configured to move along the longitudinal axis to bias the annular seal.

Abstract: A tubular has an exterior sealing element disposed in a recess. A swage passes through the tubular to increase its drift dimension from a location above the seal to below the seal. The interior projection that initially defined the exterior wall recess where the seal is located is expanded to the new drift dimension of the balance of the tubular. Extending members that are initially embedded in the seal while extending from the tubular wall that defines the recess move out during the expansion to engage the surrounding tubular to act as extrusion barriers and to aid in the fixation of the seal while being able to penetrate the wall of the surrounding tubular in so doing.

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 swellable packer with composite material end rings. A packer assembly includes at least one generally tubular seal element extending longitudinally between opposite ends thereof. At least one end ring is positioned proximate one of the seal element opposite ends. The end ring includes a nonmetal material. A method of constructing a packer assembly includes the steps of: chemically bonding at least one end ring to a base pipe; providing at least one generally tubular seal element which extends longitudinally between opposite ends thereof; and restricting longitudinal displacement of the seal element relative to the base pipe utilizing the end ring positioned at one of its opposite ends.

Abstract: An expandable packer features a sealing element in an exterior recess that is straddled by projections or bumps. Upon expansion the bumps move out against the borehole wall as an anchor support. Optionally, the bumps may be covered with a sealing material and may be constructed to assist in their radial movement to the borehole wall as a result of expansion particularly if the mandrel is expanded in compression. The bumps are not necessarily expanded with the swage and their radial growth can be induced from longitudinal shrinkage resulting from radial expansion.

Abstract: Packer assemblies capable of providing desired load-bearing performance and of being retrieved from a bore in a subterranean formation are described. A packer assembly can include a wedge that can respond to a force in a downhole direction by un-supporting the slip. The unsupported slip is configured to disengage from a casing string, allowing the packer assembly to be removed from the bore. The wedge can include a collet to allow the wedge to separate from the slip to prevent slip re-setting.

Abstract: A tie back assembly and method of use is presented. In one method, a tie back seal mandrel is inserted into a tie back receptacle. Both the inner surface of the tie back receptacle and the outer surface of the seal mandrel are tapered to cooperate when mated. A seal assembly forms an annular seal between the tapered surfaces when the mandrel is inserted into the receptacle. Preferably the seal assembly has a burst seal and a collapse seal carried on one of the tapered surfaces, where the seals are spaced apart longitudinally. The seals are positioned at locations along the tapered surfaces to provide adequate wall thickness for support at pressure. Hydrostatic fluid in the wellbore increases the force necessary to withdraw the seal mandrel dues to creation of a lower pressure zone between the spaced apart seals.

Abstract: A swellable apparatus for filling a space in oil or gas tool such as a wellbore packer is described. The swellable apparatus comprise a hydrocarbon swellable body which swells on exposure to a hydrocarbon fluid, and at least one water swellable body which swells on exposure to a second fluid comprising water. The hydrocarbon swellable body is interposed between the aqueous fluid and the water swellable body and comprises at least one access pathway configured to permit the passage of water to the water swellable body. The pathway may be formed by perforation, or by incorporating an additive into the hydrocarbon material, such as a foaming agent or polyoctenamer. Embodiments of the invention comprise variations in cross-linking in the hydrocarbon swellable body.

Abstract: A packer deactivation system can include a packer and a safety joint. Activation of the safety joint can prevent setting of the packer. A method for use with a subterranean well can include activating a safety joint in the well, and deactivating a packer connected to the safety joint, in response to the safety joint activating. Another packer deactivation system can include a safety joint and a packer drag block locking mechanism. Activation of the safety joint can operate the drag block locking mechanism, thereby preventing a drag block from displacing in a certain direction relative to a mandrel of a packer.

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: The present invention is directed to rotating flow control diverter having sealed bearing assembly that does not require external hydraulic pumping to circulate and cool the lubricating fluid used to lubricated the bearings of the sealed bearing assembly.

Abstract: A packer that includes a mandrel, primary and secondary opening seats attached to an interior of the mandrel, a landing seat attached to the interior of the mandrel, a packer element attached to an exterior of the mandrel, and a closing seat attached to the interior of the mandrel. The secondary opening seat may be between the primary opening seat and the landing seat, and the primary opening seat may be between the closing seat and the secondary opening seat. The primary opening seat engages an opening plug and moves from a first position covering an opening to a second position not covering the opening, and the secondary opening seat engages the primary opening seat and moves from a first position covering a port to a second position not covering the port.

Abstract: An electric submersible pump ESP is run in to a desired subterranean location with a packer attached. Once at the desired location the packer is set either using the ESP or some other source of force or pressure. After the ESP has completed the task and needs to be removed, the packer stays set and the ESP releases from it. Removal of the ESP assembly allows a valve in the packer mandrel to close to isolate the zone from which the ESP had been pumping. The ESP can be run in on coiled tubing or rigid tubing or wireline.

Abstract: A method of producing oil which begins by drilling, casing and inserting a tubing string in a wellbore. The method then perforates both an upper portion and a lower portion of the casing to establish communication between the wellbore with a upper horizontal fracture and a lower horizontal fracture. A retrievable packer or a seal assembly is inserted horizontally between the tubing string and the casing and vertically between the upper horizontal fracture and the lower horizontal fracture for heat isolation. Steam is then injected into the wellbore both into the upper horizontal fracture and the lower horizontal fracture. Heavy oil is then produced from the lower horizontal fracture while injecting steam into the upper horizontal fracture.

Abstract: Disclosed is a downhole completion assembly for sealing and supporting an open hole section of a wellbore. The system may include a sealing structure movable between contracted and expanded configurations, a truss structure also movable between contracted and expanded configurations, wherein, when in their respective contracted configurations, the sealing and truss structures are each able to axially traverse production tubing extended within a wellbore, a conveyance device operably coupled to the sealing and truss structures and configured to transport the sealing and truss structures in their respective contracted configurations through the production tubing and to an open hole section of the wellbore, and a deployment device operably connected to the sealing and truss structures and configured to radially expand the sealing and truss structures from their respective contracted configurations to their respective expanded configurations.

Abstract: Disclosed is a downhole completion assembly for sealing and supporting an open hole section of a wellbore. One downhole completion system includes a sealing structure movable between a contracted configuration and an expanded configuration, wherein, when in the contracted configuration, the sealing structure is able to axially traverse production tubing extended within a wellbore, a conveyance device coupled to the sealing structure and configured to transport the sealing structure through the production tubing and to an open hole section of the wellbore, and a deployment device operably connected to the sealing structure and configured to radially expand the sealing structure from the contracted configuration to the expanded configuration when the sealing structure is arranged in the open hole section.