Abstract: Provided are wiper plugs with removable cores and methods of using the wiper plugs with removable cores. An example wiper plug with a removable core comprises a molded body, a wiper, a cavity through the interior of the molded body, a support disposed in the cavity, and the removable core disposed in the cavity. An example method of use comprises removing the core of the wiper plug without drilling through the wiper plug, and leaving the remainder of the wiper plug in the wellbore.

Abstract: A sidetrack window is cut in a cased wellbore by disposing a sidetracking assembly within the cased wellbore. A first ball is deployed into a drill string of the sidetracking assembly. The first ball leaves the drill string and lands on a ball seat of a cement retainer to block fluid outlet of the cement retainer. Then, the cement retainer is set and a second fluid outlet of the cement retainer is exposed. Cement is flowed through the drill string to the portion of the cased wellbore downstream of the cement retainer to plug the portion of the wellbore. The whipstock assembly is separated from the cement retainer. A second ball is deployed inside the drill string to land on the seat of the whipstock assembly to block a fluid outlet of the whipstock assembly. The whipstock assembly is anchored in the cased wellbore and the milling system is actuated to begin cutting the sidetrack window.

Abstract: A wiper plug includes a mandrel and a seal unit disposed about the mandrel. The seal unit has a body and one or more fins extending outwardly from the body. An anti-extrusion assembly is disposed about the mandrel, and is arranged to transition between an initial configuration and an energized configuration. The anti-extrusion assembly limits extrusion of at least a portion of the seal unit.

Abstract: A subsurface release plug system includes a plug mandrel body and a plug. The plug mandrel body includes a bore, a flow port fluidly connected to the bore, and a sleeve adjustable from a first position to a second position. The sleeve prevents fluid flow through the flow port when in the first position and allows fluid flow through the flow port when in the second position. The plug is releasably connected to the plug mandrel body, wherein the plug is configured to be released from the plug mandrel body by fluid flowing through the flow port.

Abstract: A plug system includes a locked member of a first plug and a free member of a second plug. The locked member has a first locking end having a first anti-rotation feature. The free member has a second locking end having a second anti-rotation feature. The first anti-rotation feature and the second anti-rotation feature are configured to fit together to resist a rotation between the free member and the locked member to thereby resist rotation of the second plug with respect to the first plug.

Abstract: A method for operation in wellbore, the method comprises: pumping a fluid barrier into a wellbore through a tubular, the fluid barrier being operable to separate a cement slurry from a second fluid; the fluid barrier comprising a polyurethane member derived from a polyurethane forming composition comprising a para-phenylene diisocyanate terminated polycarbonate prepolymer and an aromatic diol.

Abstract: An assist device for propelling a tool through a conduit, the assist device including an upstream housing having a first port; a downstream housing movably attached to the upstream housing and the downstream housing having a second port; and a swab element attached to the downstream housing. The first port is closed when there is no gap between the upstream housing and the downstream housing, and the first port is open when there is a gap between the upstream housing and the downstream housing.

Abstract: A plug release system includes a tubular member having an outer surface and an inner surface defining a flow bore having a central longitudinal axis. A sleeve is positioned in the flow bore. The sleeve includes a first end having a radially outwardly extending annular lip, and a second end. A release mechanism is rotatably mounted in the tubular member radially offset from the central longitudinal axis. The release mechanism includes a sleeve support surface that selectively engages the radially extending annular lip. The release mechanism is rotatable between a first position wherein the sleeve maintains a plug in a retained configuration and a second position, wherein the sleeve releases the plug into the tubular member.

Abstract: An improved method and apparatus for dropping a ball, plug or dart during oil and gas well operations (e.g., cementing operations) employs a specially configured valving member with curved and flat portions that alternatively direct fluid flow through a bore or opening in the valving member via an inner channel or around the periphery of the valving member in an outer channel. In one embodiment, the ball(s), dart(s) or plug(s) are contained in a sliding sleeve that shifts position responsive to valve rotation. An optional indicator indicates to a user or operator that a ball or plug has passed a selected one of the valving members.

Abstract: A wellbore sealing system includes a dart retained in a top plug and deployable through a bore defined in the top plug and through a bore defined in the bottom plug to sealingly engage float equipment abutting the bottom plug. The dart and float equipment bear wellbore pressure directly. The dart latches with the float equipment and sealing features provide bi-directional sealing.

Abstract: An improved method and apparatus for dropping a ball, plug or dart during oil and gas well operations (e.g., cementing operations) employs a specially configured valving member with curved and flat portions that alternatively direct fluid flow through a bore or opening in the valving member via an inner channel or around the periphery of the valving member in an outer channel. In one embodiment, the ball(s), dart(s) or plug(s) are contained in a sliding sleeve that shifts position responsive to valve rotation. An optional indicator indicates to a user or operator that a ball or plug has passed a selected one of the valving members.

Abstract: Systems and methods comprising a cement head fluidly connected to a casing string located within a wellbore; a receptacle having a receiving end and a cement head end, wherein the cement head end is connected to an upper end of the cement head; and a casing running tool comprising at least one slip, wherein the at least one slip engages the receiving end of the receptacle.

Abstract: Certain exemplary embodiments comprise a seal assembly, a mandrel, a front module, and/or a rear module. At least one of the front module and the rear module comprises a mount hub, a seal assembly, a chassis, and/or a mount plate. Various annular sealing assemblies can be mounted and dismounted to and from the mount hub. The mount hub can provide substantial central support for the sealing system. The chassis can be constructed to couple the mount hub to the seal element. The mount plate can be constructed to couple the module to the mandrel. The modular pipeline pig is substantially modular. Certain exemplary embodiments provide for relatively rapid mounting and dismounting of elements to and from the module assembly. In practice, such embodiments allow for quickly and easily configuring a pigging system for many different applications.

Abstract: Example of the present disclosure relate to a bridge plug. More specifically, embodiments are directed towards a bridge plug with a flapper, wherein the flapper is configured to set and unset based on a pressure differential and/or fluid flow associated with the bridge plug.

Abstract: System and methods for engaging and disengaging running tools with a liner in a downhole system are described herein. The system and methods include a liner disposed in a borehole, the liner having at least one running tool engagement section, a running tool disposed within the liner, the running tool having at least one engagement module that is operable from a disengaged position to an engaged position and that is operable from an engaged position to a disengaged position, and an electronic device disposed at least one of in or on the engagement module.

Abstract: Hangers and related tools which actuate without fluid or mechanical communication between the interior of the tool and its exterior are disclosed. Devices as disclosed herein may include a piston for applying actuating force based on the fluid pressure outside of the tool. The piston may be fixed to a tubing wall or other body of the tool with a shear element to prevent the tool from actuating until a certain pressure is applied to piston, such as by the static pressure of wellbore fluid at a certain depth, by pressure applied to the annulus from surface, or a combination thereof. Actuation of the tool may cause latches to expand outwardly to engage a latch receptacle fixed in or along the host tubing or such actuation may lead to other hanging members, such as slips, to engage the host tubing wall in order to suspend the hanging string therein.

Abstract: A downhole shifting sleeve device includes a first segment and a second segment each including a housing, a sleeve, and a seat surface connected to the sleeve. Each seat surface is configured to engage a plug traveling through an inner bore of the device, which transfers the associated sleeve from a first position to a second position. The seat surface of the second segment is formed by a selective seat assembly. When the first sleeve is in the first position, the selective seat assembly is in a retracted position in which an inner diameter of the selective seat assembly is greater than or equal to an inner diameter of the second sleeve. When the first sleeve is in the second position, the selective seat assembly is in a deployed position in which the inner diameter of the selective seat assembly is less than the inner diameter of the second sleeve.

Abstract: A grout delivery system for delivery of a grout as a flowable substance comprising a mixture of two grout component materials at a downhole location. The grout delivery system comprises an elongate body comprises two reservoirs configured as cartridges for receiving respective charges of the two grout component materials. The two cartridges each comprise a piston. A selectively openable closure configured as a valve is provided adjacent the bottom end of each cylinder. Each piston is operably to progressively advance towards the valve, thereby expelling grout component material from the respective cartridge through the valve. When the grout delivery system is at the desired location downhole and a fluid seal established downhole, fluid such as water is pumped into the drill string and pressurized. Initially, fluid pressure is exerted on the two pistons indirectly via an actuator to initiate movement of the two pistons in concert.

Abstract: An improved method and apparatus for dropping a ball, plug or dart during oil and gas well operations (e.g., cementing operations) employs a specially configured valving member with curved and flat portions that alternatively direct fluid flow through a bore or opening in the valving member via an inner channel or around the periphery of the valving member in an outer channel. In one embodiment, the ball(s), dart(s) or plug(s) are contained in a sliding sleeve that shifts position responsive to valve rotation. An optional indicator indicates to a user or operator that a ball or plug has passed a selected one of the valving members.

Abstract: A cementing device for establishing a false bottom in a well bore for formation of a cement plug in the well bore. The cementing device includes a tool body which has a front end and a rear end. The cementing device further includes at least one propulsion device which is attached to the front end and/or the rear end of the tool body and is adapted for being propelled by a fluid.

Abstract: For a free falling well tool sub having one or more pipe bore centering cages, a collapsible material cone secured inside of the centering cage half length with the cone base opening in the downhole direction restricts the rate of pipe bore fluid flow past the cone and thereby restricts the descent rate of the tool. The rate of descent may be regulated with fluid flow by-pass apertures in the sub. A collapsible material cone in a bore centering cage having a base opening in the up-hole direction may be used as piston to drive the tool sub along horizontal segments of a deviated well bore. Both cones may be used separately or together.

Abstract: A hydrocarbon extractor (HE) evaluator system includes a central controller and an HE evaluator model that includes a hierarchical equipment model of heterogeneous HE type, subtype, and property, a plurality of rules arrangeable as a hierarchical equipment rule set, and as a hierarchical well feature rule set, a rules engine, the hierarchical well feature rule set formatted for a multi-factor comparison by the rules engine between heterogeneous HE types from disparate sources applied to the hierarchical equipment model. The rules engine configured to apply rules using class structure and one or more categories to an extracted portion of the hierarchical equipment model to generate results displayable to a user for determination of an HE type suitable for a particular well. A method for evaluating HE types and a non-transitory computer-readable medium containing instructions for a processor to perform the method are also disclosed.

Abstract: The present invention relates especially to a radially expandable tubular metallic element (2) which comprises on its external face (211) at least a series of annular sealing lips (5) made of elastically deformable material, these lips being spaced in pairs, the transversal cross section of each lip (5) having an end face (51) and two lateral walls (52, 53), characterized in that said lips (5) are in a non-metallic material and are inclined in the same direction, relative to said external face (211), that is, each of the lateral walls (52, 53) of each lip (5) forms a non-zero angle (?; ?) relative to a radial plane (PR) of said element.

Abstract: A downhole tool having a flapper valve assembly for controlling the backflow of fluid into a tubing string that includes at least one flapper. The downhole tool also includes a deformable element that maintains the at least one flapper in an open position after the deformable portion is deformed. A downhole tool having a flapper valve assembly for controlling the backflow of fluid into a tubing string that includes at least one flapper. The downhole tool also includes a sleeve slidably disposed within at least a portion of the flapper valve assembly and the downhole tool. The downhole tool includes a deformable and dissolvable seat disposed uphole and adjacent to the sleeve and a dissolvable fluid blocking member to engage with the seat to shift the sleeve from first position to a second position within the downhole tool. Methods of using these downhole tools are provided.

Abstract: Certain aspects are directed to self-assembling packers that seal an annulus in a downhole wellbore. In one aspect, the packer is formed from a magnetorheological fluid, which may be a carrier fluid formed from a polymer precursor and magnetically responsive particles. The fluid is allowed to be shaped by a magnetic field provided by one or more magnets exerting a radially extending magnetic field from a tubing section used to place the packer.

Abstract: Disclosed is a sliding sleeve assembly that includes a sliding sleeve sub coupled to a work string extended within a wellbore, the sliding sleeve sub having one or more ports defined therein that enable fluid communication between an interior and an exterior of the work string, a sliding sleeve arranged within the sliding sleeve sub and movable between a closed position, where the sliding sleeve occludes the one or more ports, and an open position, where the sliding sleeve has moved to expose the one or more ports, a sleeve profile defined on an inner surface of the sliding sleeve, a wellbore dart having a body and a plurality of collet fingers extending longitudinally from the body, and a dart profile defined on an outer surface of the plurality of collet fingers, the dart profile being configured to selectively mate with the sleeve profile.

Abstract: A method for casing a subsea wellbore includes running a tieback casing string into the subsea wellbore using a workstring including first, second, and third wiper plugs. The method further includes: launching a first release plug or tag into the workstring; pumping cement slurry into the workstring, thereby driving the first release plug or tag along the workstring; after pumping the cement slurry, launching a second release plug or tag into the workstring; and pumping chaser fluid into the workstring, thereby driving the release plugs or tags and cement slurry through the workstring. The release plugs or tags engage and release the respective wiper plugs from the workstring. The first wiper plug or release plug ruptures, thereby allowing the cement slurry to flow therethrough. The method further includes: stabbing the tieback casing string into a liner string; and retrieving the workstring, the workstring still including the third wiper plug.

Abstract: A detonating restriction plug element and method in a wellbore casing. The element includes a hollow passage in the restriction plug element that receives a detonating assembly coupled to a mechanical restraining element, and a space for containing a reactive fluid. The mechanical restraining element undergoes a change in shape for a pre-determined time delay due to a chemical reaction when the reactive fluid in the space such as wellbore fluids comes in contact with the restraining element. A firing pin in the detonating assembly is released when the restraining elements changes shape and releases the restraint on the firing pin. The firing pin contacts a detonator in the detonating assembly and causes a detonating event such that the restriction plug element fragments.

Abstract: A downhole tool for treating a zone adjacent a wellbore, comprising a body having at least two separable portions, the portions operable to open and close a fluid path through the tool, and at least one manipulator, like a spring-loaded finger, to establish a fluid path between an interior and exterior of the wellbore, thereby permitting a zone adjacent the wellbore to be treated. In another embodiment a method is disclosed for treating a zone of interest adjacent a wellbore.

Abstract: An improved method and apparatus for dropping a ball, plug or dart during oil and gas well operations (e.g., cementing operations) employs a specially configured tool body assembly having valving members (e.g., safety or kelly values) and valving members holding plugs, balls, or darts to be dropped. In one embodiment, the ball(s), dart(s) or plug(s) are contained in a sliding sleeve that shifts position responsive to valve rotation. An optional indicator indicates to a user or operator that a ball or plug has passed a selected one of the valving members. A transmitter (or transceiver) provides an ability to generate a wireless signal that is received by receivers (or transceivers) on the tool body assembly. Each receiver (or transceiver) controls an electrical actuator that engages a valving member or the indicator. Wireless signals can be used to open or close a valve or to reset a “tripped” indicator.

Abstract: The present invention relates methods and apparatus for lining a wellbore. In one aspect, a drilling assembly having an earth removal member and a wellbore lining conduit is manipulated to advance into the earth. The drilling assembly includes a first fluid flow path and a second fluid flow path. Fluid is flowed through the first fluid flow path, and at least a portion of which may return through the second fluid flow path. In one embodiment, the drilling assembly is provided with a third fluid flow path. After drilling has been completed, wellbore lining conduit may be cemented in the wellbore.

Abstract: A flow control system for use with a subterranean well can include a flow chamber through which a fluid composition flows, and a closure device which is biased toward a closed position in which the closure device prevents flow through the flow chamber. The closure device can be displaced to the closed position in response to an increase in a ratio of undesired fluid to desired fluid in the fluid composition. A structure can prevent the closure device from being displaced to the closed position. The fluid composition can flow through the structure to an outlet of the flow chamber.

Abstract: Improved cementing plugs and methods of using these cementing plugs in subterranean wells are disclosed. A cementing plug comprises a hollow mandrel and one or more wiper elements coupled to the mandrel. A nose is coupled to the hollow mandrel and is movable between a retracted position and an extended position. A portion of the nose is positioned within the mandrel when in the retracted position. This portion of the nose is positioned outside the mandrel when in the extended position.

Abstract: Certain aspects are directed to downhole power delivery tools using hydrostatic pressure within the wellbore. In one aspect, a downhole power delivery tool is provided that can be disposed in a wellbore through a fluid-producing formation. The downhole power delivery tool includes a body defining an inlet proximate to a chamber in the body, an actuation mechanism in the body and adjacent to the inlet, and a piston proximate to the chamber. The actuation mechanism can allow communication of hydrostatic pressure via the inlet to the chamber from an annulus external to the body in response to an actuation force being applied to the actuation mechanism. The hydrostatic pressure communicated to the chamber applies a first force to the piston. The piston applies a second force to a rod movable relative to the body in response to the first force being applied to the piston.

Abstract: A downhole tool for opening a travelling valve assembly of a downhole pump is disposed with the travelling valve assembly within a pump barrel, and includes a substantially cylindrical housing and a piston. The housing defines an axial bore extending from a bottom opening for fluid communication with the pump barrel, a radial port for fluid communication between the axial bore and the pump barrel, and a channel formed in the outer surface of the housing for fluid communication between the radial port and the travelling valve assembly. The piston occludes the axial bore above the radial port, and in response to an upward pressure exerted by a production fluid below the piston, slides upwardly within the axial bore to engage and open a valve member of the travelling valve assembly.

Abstract: An improved method and apparatus for dropping a ball, plug or dart during oil and gas well operations (e.g., cementing operations) employs a specially configured tool body assembly having valving members (e.g., safety or kelly values) and valving members holding plugs, balls, or darts to be dropped. In one embodiment, the ball(s), dart(s) or plug(s) are contained in a sliding sleeve that shifts position responsive to valve rotation. An optional indicator indicates to a user or operator that a ball or plug has passed a selected one of the valving members. A transmitter (or transceiver) provides an ability to generate a wireless signal that is received by receivers (or transceivers) on the tool body assembly. Each receiver (or transceiver) controls an electrical actuator that engages a valving member or the indicator. Wireless signals can be used to open or close a valve or to reset a “tripped” indicator.

Abstract: An expandable downhole tool for use in an oil well, including a flexible member rolled into a helix and comprising first and second lateral edges on opposing lateral ends of the member. The flexible member is selectively changeable between a compressed configuration wherein the transverse cross-section of the flexible member has a first diameter, and an expanded configuration wherein the transverse cross-section of the flexible member has a second diameter, the second diameter larger than the first diameter.

Abstract: The present invention provides an apparatus and method for testing a wellbore, and to an apparatus and method to efficiently and effectively test the annular seal of a tubular string positioned within a wellbore. More specifically, the cement seal between a casing string and a wellbore is tested to assure there is no contamination of groundwater or between different geologic formations. An additional aspect of the present invention is to provide a testing assembly comprising a frangible body and a tool body, the tool body providing a passageway to the annular seal when the frangible body is drilled out. In one particular embodiment, the frangible body initially forms an encapsulated bore that aligns with the passageway.

Abstract: An apparatus for installing cement plugs into a well, comprising a protective sleeve having one end adapted to be attached to the end of a drill pipe and arranged to carry a cementing plug around its outer surface such that a dart passing through the drill pipe can pass through the sleeve and engage only on formations on the plug to withdraw it from the end of the sleeve.

Abstract: A downhole tool and method of operation thereof is provided. The downhole tool may be configured to permit fluid communication between a combined flowbore of the casing string and the downhole tool and the subterranean formation or wellbore, or both, after a pressure test has been completed, a second threshold pressure is reached or applied, and a third threshold pressure has been applied to the downhole tool.

Abstract: A downhole tool for use in a well. A pumpable plug is used to urge bottom hole assemblies to a desired location in a well. The pumpable plug has a diameter greater than the maximum outer diameter of the casing in which the bottom hole assembly is to be located.

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

Abstract: An apparatus for use in launching cement plugs in a well cementing operation, comprising: —a cylinder (104) having ports (106) defined in a portion of the wall thereof; —a piston (108) slideably received in the bore of the cylinder below the ports; and —an actuator (110) extending from the piston through the cylinder and operable by the piston for launching a plug from the apparatus into the well; wherein the apparatus further comprises an elongate sleeve valve member located in the cylinder above the piston, the sleeve valve member (112) comprising at least one ball seat (114a-114c) for receiving a ball to block the interior of the cylinder, sleeve ports formed in the sleeve above the ball seat, and a spacer (118) extending between the ball seat and the piston.

Abstract: A wellbore cleaning tool for removing irregularities along the inner surface of a wellbore tubular may include a top sub, a cutting assembly, and a bottom sub. The tool is operable to remove irregularities, such as debris, burrs, and jagged edges, along the inside of the wellbore tubular, and thereby provide a clean, inner surface finish. The tool may be actuated into a retracted position, an extended position, and/or a deactivated position.

Abstract: A pipe in pipe piston thrust system comprises a plurality of piston assemblies configured to sealingly engage a wellbore, a pump configured to transfer a fluid into the wellbore, and a by-pass disposed between a plurality of annuli formed by the plurality of piston assemblies. The by-pass allows for selective communication of the fluid between the plurality of annuli.

Abstract: A downhole tool for use in a well. The tool has a packer assembly and a pumpable plug associated with the packer assembly. The pumpable plug has a diameter greater than the maximum outer diameter of the packer assembly. The pumpable plug may be pumped through a casing having a diameter larger than that for which the packer assembly is designed and will urge the packer assembly through the large diameter casing into a smaller diameter casing for which the packer assembly is designed.

Abstract: A cement head used for performing cementing jobs in downhole operations is provided. The cement head includes wireless signaling means, an integrated energy supply, activating means for pneumatic operated valves in cement head, and controller means for controlling said energy supply for activation of at least one valve based on received signals through the wireless signaling means.

Abstract: Methods and apparatus are presented for a hybrid downhole force generator (DFG) using a stroke amplifier driven by hydrostatic pressure for a low-force, long-stroke portion of setting a downhole tool and a DFG powered shaft for a high-force, short-stroke portion of setting the tool. The stroke amplifier has a piston slidable in a housing, movable in response to hydrostatic pressure. The DFG powered shaft is connected to the piston via one-way slips which allow relative motion of the piston and shaft in one direction. The amplifier housing is connected to the DFG housing. In use, the DFG shaft is powered by a power supply, such as an electric motor, etc. The shaft is powered to shear a shearing mechanism, freeing the piston to move in response to the hydrostatic pressure.

Abstract: An improved method and apparatus for dropping a ball, plug or dart during oil and gas well operations (e.g., cementing operations) employs a specially configured tool body assembly having valving members (e.g., safety or kelly valves) and valving members holding plugs, balls, or darts to be dropped. A transmitter (or transceiver) provides an ability to generate a wireless signal that is received by receivers (or transceivers) on the tool body assembly. Each receiver (or transceiver) controls an electrical actuator that engages a valving member. Wireless signals can be used to open or close a selected valving member.

Abstract: Various systems and methods for cementing plug tracking using distributed strain sensing include a downhole cementing apparatus that includes a distributed strain sensor with an optical cable and a first downhole cementing plug coupled to a fixed point on the optical cable. The apparatus further includes a second downhole cementing plug slidably coupled to the optical cable between the first downhole cementing plug and a sensing end of the optical cable. The second downhole cementing plug causes a detectable feature in a strain profile along the optical cable's length that indicates a position of the second downhole cementing plug.