Abstract: Application of a photocurable lining to a downhole fixed surface surrounding the axis of a wellbore is carried out by skimming an applicator over the downhole surface while delivering a porous tape impregnated with a photocurable liquid composition between the applicator and the downhole surface so that the tape lies on the downhole surface and directing light of wavelength in a range from 100 nm to 1500 nm onto the curable composition impregnating the tape so as to initiate curing of the composition and thereby attach the tape to the downhole surface.

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

Abstract: A seal assembly between a wellhead housing having a bore and a casing hanger, has an inner seal leg for sealing against hanger and an outer seal leg for sealing against housing. An extension extends downward from outer seal leg and has a downward facing shoulder that rests on an upward facing shoulder formed on a nose ring. Connection connects seal ring to the nose ring with a lower portion of the nose ring resting on the upward facing shoulder of the casing hanger. Bellows are formed on the nose ring to increase lockdown capacity. Bellows have an inner surface that faces an outer profile of the hanger, and an outer surface on the bellow that faces the bore of the housing. When the bellows are axially collapsed, they expand radially outward and contract radially inward into the bore of the housing and the outer profile of the hanger.

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). The lower end of one or more of the mesh ring(s) and/or petal ring(s) rotate outwardly toward the casing and engage the casing to facilitate creation of the seal.

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

Abstract: The present invention generally relates to a weight setting indicator which is used to indicate that an applied force to a tool achieved or exceeded a predetermined amount. In one aspect, a packer actuator for use with a packer is provided. The packer actuator includes a body with a recess. The packer actuator further includes a dog assembly disposed in the recess of the body. The dog assembly is configured to set the packer when a force is applied to the packer actuator. The packer actuator also includes a setting indicator disposed in the recess adjacent an end of the dog assembly. The setting indicator is configured to move from a pre-set position to a post-set position when the force is applied to the packer actuator, wherein the setting indicator is plastically deformed in the post-set position.

Abstract: A downhole tool with a swellable mantle is configured for insertion of a cable into a longitudinal slit in the mantle. An arcuate groove is formed in an outer surface of the mantle corresponding to a displacement caused by the inserted cable, so that the displacement is counteracted and the outer surface of the mantle remains smooth.

Abstract: A device and method prevent damage to an anti-extrusion device on a tool, such as a plug or a packer, prior to and during setting of the tool. Typically, the upper or outer edges of the anti-extrusion device are relatively delicate. A reinforcing band on the device's sheath strengthens or armors the upper or outer edge of the anti-extrusion device so the anti-extrusion device may be protected while running the tool into the well or casing. Longitudinal slots on the sheath allow the sheath to expand at least partially with the expansion of the sealing element, while the reinforcing band resists expansion of the distal edge of the sheath.

Abstract: A downhole sealing assembly (10) comprises a sleeve (12) adapted to be mounted on a body, the sleeve (12) including a swellable material and defining a sealing arrangement comprising inner and outer seals (18, 20). Swelling of the material radially extends the seals (18, 20).

Abstract: A hydraulic regulating mechanism for disposal in a well. The mechanism includes a degradable metal based element and a swellable component for hydraulic regulation. The mechanism is configured for ease of setting and removal by allowing degrading of the metal based element upon exposure of certain downhole conditions to trigger shrinking of the swellable component. Further, the swellable component may be initially set by exposure to downhole conditions as well. Ultimately, a mechanism is provided which may effectively regulate high pressure applications downhole and yet, as a practical matter, be removed via a displacement or drill out that may take less than 15 to 30 minutes to achieve.

Abstract: A device and method to control the rate of radial expansion of a compressible sealing element on a packer over the longitudinal length of the sealing element. By varying the rate of compression of the element, the rate of radial expansion of the corresponding portions of the element may also be controlled. Additionally, the rate of radial expansion may also be controlled by controlling the direction and amount of radial expansion along the length of the sealing by reinforcing certain portions of the sealing element while decreasing the rigidity of the reinforcement for other portions.

Abstract: A tieback receptacle is configured with an exterior cone and externals seals with a clearance space to accept a tieback shoe that will wash over the receptacle and expand when landed and advanced over the cone. The lower end of the shoe is tapered so that the thickness opposing the upper seal adds to burst and collapse resistance while the tapered lower end allows a thicker receptacle to be used in the area of the lower seal. The expansion can be accomplished with setting down weight which can also enhance the set of the liner hanger below. Minimal expansion in the order of 3% or less is needed. Exterior slots create cement flow passages and a no-go for the stem to prevent damage to the box further below. A metal to metal seal is created at the cone that is straddled by the exterior seals on the extension.

Abstract: Apparatus useful for remotely actuating the drag blocks of a downhole tool includes at least one remotely actuated sleeve configured to allow the drag blocks to move from one position to another when the downhole tool is disposed in a well bore.

Abstract: A wellbore servicing tool comprising a mandrel generally defining an axial flowbore and comprising a threaded exterior surface, an upper housing generally comprising a threaded interior surface, wherein the upper housing is movably positioned about the mandrel such that the threaded exterior surface at least partially engages the threaded interior surface, a packer element exhibiting radial expansion upon being longitudinally compressed, wherein the packer element is movably positioned about the mandrel generally downward relative to the upper housing, and a lower housing movably positioned about the mandrel, wherein the wellbore servicing tool is selectively transitionable from an unset configuration to a set configuration or from the unset configuration to the set configuration upon rotation of the upper housing with respect to the mandrel.

Abstract: A method of preventing fluid flow past a tapered face of a mill diverter in a wellbore comprises: positioning the mill diverter in the wellbore, wherein the mill diverter comprises: a body; the tapered face, wherein the tapered face is located at one end of the body; and a swellable material, wherein the swellable material: is positioned circumferentially around the body of the mill diverter adjacent to the tapered face; swells in the presence of a swelling fluid; and prevents substantially all of a fluid from flowing past the swellable material after the swellable material has swelled; and causing or allowing the swellable material to swell. The swellable material can also prevent a loss of pressure in the wellbore above the swellable material or prevent a first fluid having a first density from mixing with a second fluid having a second density after the swellable material has swelled.

Abstract: A wellbore packer for setting against a wellbore wall in a wellbore, the wellbore packer including: a mandrel including a upper end and an lower end; and an outer housing encircling the mandrel and including a first compression ring, a second compression ring, an annular packing element encircling the mandrel and positioned between the first compression ring and the second compression ring, the sealing element being expandable to form an annular seal about the packer by compression between the first compression ring and the second compression ring; and an anchoring mechanism including a slip that is expandable outwardly into a set position and a slip actuation assembly to drive expansion of the slip.

Abstract: An annular seal for use in a wellhead assembly has inner and outer legs that each extend in a direction that is generally parallel with an axis of the seal to define an annular space therebetween. Wickers are provided on an outer surface of the seal, so that when the seal is energized and the legs are urged radially apart from one another, the wickers engage with a mating surface of a downhole tubular. Embedding the wickers into the tubular creates a flow barrier across the interface between the seal and the tubular. The wickers deform the surface of the tubular, which creates a lock down force that opposes relative axial movement of the tubular.

Abstract: An actuator and method for setting a subterranean tool uses an externally mounted actuator on a tubular string that is operably engaged to the tool to be actuated. At the desired location for actuation a signal is given to a valve assembly. The opening of the valve releases the pressurized compressible fluid against a floating piston. The piston drives viscous fluid ahead of itself through the now open valve that in turn drives an actuating piston whose movement sets the tool. The triggering mechanism to open the valve can be a variety of methods including an acoustic signal, a vibration signal, a change in magnetic field, or elastic deformation of the tubular wall adjacent the valve assembly.

Abstract: A shutoff tool for being entered into a well bore and shutting off openings or leaks, said shutoff tool comprising: one or more enclosures prepared for comprising a sealant, said sealant being capable of shutting off openings or leaks when cured. An outer inflatable bladder arranged outside and covering said one or more enclosures, said outer inflatable bladder being prepared for rupturing in positions where it is not supported during inflation, said rupturing will provide access from said one or more enclosures to the outside of said outer inflatable bladder. An inner inflatable bladder arranged inside the outer inflatable bladder and such that said one or more enclosures will be arranged between the outer and the inner inflatable bladders, such that when inflated said inner inflatable bladder can exert a pressure on said one or more enclosures. A core arranged inside said inner inflatable bladder, and prepared for supplying a pressurized fluid into said inner inflatable bladder.

Abstract: A method and apparatus for a debris barrier assembly having a sleeve, an outer housing assembly coupled to the sleeve, and first and second biasing members disposed within the outer housing assembly. A support member is coupled to the sleeve and is in contact with an end of the first and second biasing members. The debris barrier assembly is coupled to a polished bore receptacle to prevent debris from entering the PBR. The debris barrier assembly is operable to compensate for a pressure differential between the internal region of the PBR and the external region of the surrounding wellbore. The debris barrier assembly and the PBR may be run in the wellbore on a work string, and the sleeve may be actuated to actuate a downhole tool connected to the sleeve to perform a downhole operation. The debris barrier assembly may be retrieved from the wellbore using the work string.

Abstract: A swellable material seal includes a quantity of swellable material disposed in a geometric configuration; and a plurality of openings in the material to enhance wettability thereof by a swelling fluid.

Abstract: A downhole apparatus is described comprising a body and a sealing arrangement located on the body. The body has a longitudinal axis and the sealing arrangement comprises at least one elongated sealing member with an axis of elongation extending around the longitudinal axis. The sealing member comprises a material selected to expand on exposure to at least one predetermined fluid, such as a hydrocarbon or aqueous fluid encountered in a wellbore. A method of forming the apparatus and methods of use are described. Embodiments of the invention relate to wellbore packers.

Abstract: An apparatus, system and method of sampling a reservoir fluid is disclosed. An inflatable packer is deployed into a wellbore having one or more fluid ports for receiving the reservoir fluid. The fluid ports are positionable at different longitudinal and/or radial positions. One or more pumps are connected to the fluid ports and are within the packer. A fluid exit may optionally be provided in the packer to expel the reservoir fluid received from one of the fluid ports back into the wellbore.

Abstract: Disclosed herein is an apparatus for use downhole comprising an expandable component; a support member that has a selected corrosion rate; wherein the support member is disposed on the expandable component; where the support member comprises a plurality of particles fused together; the particles comprising a core comprising a first metal; and a first layer disposed upon the core; the first layer comprising a second metal; the first metal having a different corrosion potential from the second metal; the first layer comprising a third metal having a different corrosion potential from the first metal.

Abstract: A swellable packer with an enhanced sealing ability comprises a tubular body, a swellable element, and a filler ring disposed about the tubular body between the tubular body and the swellable element. The filler ring is formed of a material harder than the swellable element. The filler ring enhances the sealing ability of the swellable packer. Any number of filler rings may be used. The filler ring or rings may be fixed to the tubular body or may be unfixed.

Abstract: The present invention relates to an annular barrier to be expanded in an annulus between a well tubular structure and an inside wall of a borehole for providing zone isolation between a first zone and a second zone of the borehole, comprising a tubular part for mounting as part of the well tubular structure and having an expansion opening, an expandable sleeve surrounding the tubular part, each end of the expandable sleeve being connected with the tubular part, and an annular barrier space between the tubular part and the expandable sleeve, wherein the annular barrier further comprises a pressure intensifying means having an inlet in a first end in fluid communication with the expansion opening and having an outlet in a second end in fluid communication with the annular barrier space.

Abstract: A hydraulically set packer has a mandrel with an internal bore and a port communicating the internal bore outside the mandrel. A packing element disposed on the mandrel can be compressed by a piston to engage the borehole. The piston is disposed on the mandrel on a first side of the packing element and moves against the packing element when tubing pressure is communicated into a first piston chamber via the mandrel's port. To increase the setting forces, a sleeve disposed between the packing element and the mandrel defines a space communicating an opposite side of the packing element with a second pressure chamber of the piston. During high pressure operations, high pressure on the first side of the packing element acts with high pressure on the first side of the piston, increasing the pistons movement from a high pressure region to a low pressure region.

Abstract: A wellbore ball valve includes a ball-type valve closure having an interior, central bore. A lower ball carrying assembly defines a first annular, sealing seat surface in contact with and adapted to seal with the exterior of the valve closure. The first seat surface defines a first through hole. An upper assembly defines a second annular seat surface in contact with the exterior of the valve closure. The second seat surface defines a second through hole. The second through hole is shaped differently from the first through hole in that it at least partially overlaps with the central bore while the first through hole is sealed from the central bore.

Abstract: This disclosure is related to downhole tool having an erosion resistant material metalurgically bonded to portions of the downhole tool. The downhole tool can have the erosion resistant material can be disposed on predetermined portions of inner and outer surfaces of the downhole tool. The disclosure is also related to a method of using the downhole tool described herein.

Abstract: A method includes in a single trip running a completion system having an internal bore into a wellbore that penetrates a formation zone, the completion system having an upper completion connected to a lower completion, setting an isolation packer forming a barrier above the formation zone, displacing the annulus fluid above the set isolation packer and then setting an upper packer thereby providing a completion barrier above the set isolation packer. The annulus fluid may be displaced prior to setting an upper completion packer.

Abstract: A method of releasing a well packer can include applying a predetermined tension in a tubular string connected to the packer, and then reducing the tension, thereby retracting inward at least one slip of the packer. A well packer can include a generally tubular mandrel, at least one slip configured for gripping a well surface, the slip being extendable outward by engagement with a support surface, and a gripping device which permits displacement of the mandrel relative to the support surface in one direction, and which prevents displacement of the mandrel relative to the support surface in an opposite direction. A method of manufacturing a gripping device can include deforming a sleeve, thereby changing a diameter of the sleeve, aligning teeth on the sleeve across at least one slot in the sleeve, and heat treating the sleeve while the sleeve remains deformed and the teeth remain aligned.

Abstract: Zonal isolation apparatus includes at least one packer assembly and can be used in completing an open-hole portion of a wellbore, which open-hole portion extends through at least two subsurface intervals. The zonal isolation apparatus includes base pipe and filter medium, which together form a sand screen. Each packer assembly comprises at least two mechanically set packer elements. Intermediate the at least two mechanically set packer elements is at least one swellable packer element. The swellable packer element is actuated over time in the presence of a fluid such as water, oil, or a chemical. Swelling may occur should one of the mechanically set packer elements fail. The zonal isolation apparatus also includes alternate flow channel(s) that serve to divert gravel pack slurry from an upper interval to lower intervals during gravel packing operations. A method for completing a wellbore using the zonal isolation apparatus is also provided herein.

Abstract: An example downhole completion system includes a first sealing structure arranged within an open hole section of a wellbore and being movable between a contracted configuration and an expanded configuration, a second sealing structure arranged axially adjacent the first sealing structure and also being movable between a contracted configuration and an expanded configuration, and a flow control device arranged between the first and second sealing structures and configured to provide a flow path for fluids to communicate between a surrounding subterranean formation and an interior of the downhole completion system.

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 technique enables sealing of downhole components by providing a downhole pressure barrier for communication lines. The system comprises a communication line cementing sub that may be coupled into a tubing string. The cementing sub comprises a flow passage, a radially protruding region, a first connector, and a second connector. The first connector is generally disposed on a first longitudinal end of the radially protruding region, and the second connector is disposed on a second longitudinal end of the radially protruding region. Additionally, a passageway extends through the radially protruding region from the first connector to the second connector. The first and second connectors enable routing of a communication line through the radially protruding region.

Abstract: Processes and systems for fracturing a formation are disclosed. Tools that may be selectively opened and closed are positioned on a tubular liner that in turn is positioned within a subterranean well bore. Separate pairs of packers are also attached to and positioned along the tubular liner so as to straddle each tool. Fracturing fluid is pumped from the surface through the tubular and open tool and past a pair of packers at a temperature and injection rate which causes contraction of the tubular liner. Thereafter, the velocity of the fracturing fluid is sufficient to set the pair of packers adjacent the open tool. Continued pumping of fracturing fluid is directed by the set packers into the adjacent subterranean environs at a pressure sufficient to fracture the subterranean environs.

Abstract: Methods and apparatus include an expandable packer having a tubing expanded to create a seal in an annulus surrounding the tubing. The tubing includes a non-uniform outer surface configured to cause formation of undulations in a diameter of the tubing upon expansion of the tubing. A plurality of expandable packers may be connected to a tubular string to isolate multiple zones in a wellbore. A production tubular equipped with multiple expandable packers may be installed in the tubular string. The expandable packers may also include non-uniform outer surfaces configured to form undulations upon expansion. The combination of tubular string and production tubular may be used in an enhanced oil recovery application such as injecting steam into a formation to enhance production.

Abstract: Modular hydraulic packer-and-port system and corresponding methods of operation. The system may be installed for temporary, semi-permanent, or permanent deployments. The system and method may provide for hydraulic isolation of target zones in a well while allowing pass-through tubes to the target zones for taking samples, inserting monitoring sensors, and the like.

Abstract: A seal assembly for sealing an annulus between inner and outer wellhead members includes an energizer ring formed of a high strength elastic material having inner and outer legs. An annular inner recess with grooves on its base is formed on an inward facing surface of the inner leg. An inner diameter seal ring formed of an inelastic material engages the grooves of the inner recess. An annular outer recess with grooves on its base is formed on an outward facing surface of the outer leg. An outer diameter seal ring formed of an inelastic material engages the grooves of the outer recess. When the energizer ring is coaxially inserted in the annulus, the inner diameter seal ring is compressively and permanently deformed into sealing contact with the inner wellhead member, and the outer diameter seal ring is compressively and permanently deformed into sealing contact with the outer wellhead member.

Abstract: An apparatus that is usable within a well includes a string and an object. The object is adapted to be communicated into the well through a passageway of the string to form an obstruction downhole in the well. The object includes an inner core; a layer to surround the inner core; and a structure to extend from the layer to support the inner core while the layer is being formed to position the inner core with respect to the layer.

Abstract: A method of releasing a well packer can include applying a predetermined tension in a tubular string connected to the packer, and then reducing the tension, thereby retracting inward at least one slip of the packer. A well packer can include a generally tubular mandrel, at least one slip configured for gripping a well surface, the slip being extendable outward by engagement with a support surface, and a gripping device which permits displacement of the mandrel relative to the support surface in one direction, and which prevents displacement of the mandrel relative to the support surface in an opposite direction. A method of manufacturing a gripping device can include deforming a sleeve, thereby changing a diameter of the sleeve, aligning teeth on the sleeve across at least one slot in the sleeve, and heat treating the sleeve while the sleeve remains deformed and the teeth remain aligned.

Abstract: A millable bridge plug system includes a mandrel having an upper portion and a lower portion, a shearing member attached at said upper portion of the mandrel, a sealing member, ring members, cone assemblies, slip devices, and a cap member at a lower portion of the mandrel. The shear member and the cap member are modular so that one bridge plug interchangeably connects to another bridge plug. The shear members are compatible with cap members of other bridge plugs. The shear member and the cap member further include a locking mechanism for rotational engagement by protrusions on the cap member being fit into the shear member and a locking mechanism for triggering a spring loaded lock into a groove on the cap member.

Abstract: A gravel pack system and method for zonal isolation includes a swellable element used in conjunction with a primary isolation device, such as a cup packer. The zones may be isolated by both the isolation device and the swellable element. Shunt tubes may be used to convey a gravel slurry to each zone. At least one upper shunt tube extends through the isolation device to provide the slurry to the zone therebelow. Once the gravel packing is completed, the swellable member may be activated to provide and supplement a hydraulic seal between adjacent zones.

Abstract: A downhole apparatus, for example a centralizer, comprises a swellable material which expands upon contact with at least one predetermined fluid. In a first aspect of the invention, a centralizer comprises a body and a plurality of formations upstanding from the body. In another aspect, a downhole apparatus comprises a throughbore configured to receive a tubular, a swellable member, and a rigid assembly integrally formed with the swellable member. The rigid assembly provides stand off to the apparatus in use. In a further aspect, the downhole apparatus has a first condition before expansion of the swellable member in which a rigid assembly defines a maximum outer diameter of the apparatus. In a second condition after expansion of the swellable member, the swellable member defines a maximum outer diameter of the apparatus. In a preferred embodiment, the rigid assembly is designed to flex or deform under an axial or radial load.

Abstract: A seal assembly for use between wellbore tubulars employs an inner seal ring partially circumscribed by an outer seal ring. The seal rings are axially slidable with respect to one another and can be made from pliable inelastic materials such as graphite or a fluoropolymer. The seal rings contact one another along profiled surfaces that are angled such that by axially urging the seal rings towards one another produces a bulge in the seal assembly directed radially outwards and inwards. The bulging seal rings come into contact with opposing sides of the wellbore tubulars to define a sealing surface. Axial supports at opposing lateral ends of the seal rings maintain the seal between the tubulars.

Abstract: A setting tool comprises a centralizer section, a latching section configured to selectively engage the packer, and a setting section configured to provide a setting force to the packer through the setting sleeve. The centralizer section is configured to centralize a setting sleeve within a packer, and the centralizer section is configured to control the rate at which the setting sleeve engages the packer.

Abstract: An end ring for a swell packer for use in a wellbore, wherein the swell packer has a central metal tubular with a rubber exterior tubular disposed over the central metal tubular. The rubber exterior tubular can swell in the presence of a well completion fluid and the end ring can sealingly engage one end of the rubber exterior tubulars disposed over the central metal tubular.

Abstract: A shape memory polymer is initially fabricated to a size where its peripheral dimension will be at least as large as the borehole wall in which it is to be deployed. After the initial manufacturing the material temperature is elevated above the transition temperature and the material is stretched on a mandrel to retain its inside dimension as its outside dimension is reduced to size that will allow running the seal to a desired subterranean location without failing the material during the stretching. The material is allowed to cool below the transition temperature to hold the new shape. The material on the mandrel is then secured to a tubular string and delivered to the desired location. Wellbore fluid at given temperature raises the material again above the transition temperature, which causes the material to revert to its originally manufactured shape.

Abstract: An actuator and method for setting a subterranean tool uses an externally mounted actuator on a tubular string that is operably engaged to the tool to be actuated. At the desired location for actuation a signal is given to a valve assembly. The opening of the valve releases the pressurized compressible fluid against a floating piston. The piston drives viscous fluid ahead of itself through the now open valve that in turn drives an actuating piston whose movement sets the tool. The triggering mechanism to open the valve can be a variety of methods including an acoustic signal, a vibration signal, a change in magnetic field, or elastic deformation of the tubular wall adjacent the valve assembly.

Abstract: A hydraulically set packer assembly actuated over an electronic line. The assembly includes a hydraulic packer setting mechanism that serves as an intensifier that is activated by way of an electronic trigger. As such, the trigger may be electronically coupled to an electronic line that is conventionally available for surface communications between surface equipment and a downhole gauge. The gauge generally present for monitoring well conditions such as pressure. Thus, a separate dedicated hydraulic or other powering line need not be outfitted as part of the assembly. Once more, for sake of gauge and well monitoring integrity, communications with the setting mechanism may be severed upon setting of the packer.