Abstract: Multiple layers of a seal can be formed to pressure-seal an open-hole wellbore in a subterranean formation. The seal can include at least one element and a sealing mixture between the element and a container housing for pressure sealing the open-hole wellbore between the element and the container housing and for providing multiple layers of seal in the open-hole wellbore. The seal can be retained by the sealing mixture subsequent to the sealing mixture being released.

Abstract: A well tool includes a first component, a second component having a passage for receiving the first component, and an anchor assembly. The anchor assembly includes at least one anchor positioned on the first component that is received by at least one profile formed on an inner surface defining the passage of the second component. Either or both of the at least one profile and the at least one anchor include a ramp section that has a ramp contour defined by a ramp tangent. The ramp tangent forms an acute angle with a longitudinal axis of the borehole. A related method includes the steps of forming at least one profile in the second component, the at least one profile including a ramped section; disposing at least one anchor in the first component; and lowering the first component relative to the second component until the first anchor and the first profile align the first component and the second component in a predetermined relative alignment.

Abstract: The centralizer also includes a body defining a central bore and a plurality of cavities fluidically coupled to the central bore and an exterior of the body, where the plurality of cavities are located between the central bore and an outer surface of the body. The centralizer also includes a plurality of springs with each housed in one of the plurality of cavities. The centralizer also includes a plurality of pistons with each housed in one of the plurality of cavities and abutting a respective spring in that cavity. The centralizer also includes a centralizer pad pivotally connected to each of the plurality of pistons and extending radially from a longitudinal axis of the body in response to bias from the plurality of springs.

Abstract: A deployable electrical contact device is provided that includes a body portion and a mounting arrangement. The mounting arrangement is controllably deployable from the body portion. The mounting arrangement is configured to retain the device at a position at a metallic well structure by mechanically engaging with a wall surface of the metallic well structure. The mounting arrangement includes electrically conductive pads configured to provide electrical continuity between the engaged metallic well structure and the mounting arrangement. The device is configured such that when deployed an electrical signal path between one or more of the conductive pads and the body portion is established to provide electrical continuity between the metallic well structure and the body portion.

Abstract: A centralizing device is configured to centralize/decentralize an associated tool in a well. The centralizing device includes a body that extends along a longitudinal axis X, the body having a bore that extends from one end to another end of the body; a first piston shaped as a cylinder and provided around a central portion of the body; a second piston shaped as a cylinder and provided around the central portion of the body; a bridge provided around the central portion of the body, between the first and second pistons; and a pair of arms, each arm being attached with one end to a corresponding one of the first and second pistons and with another end to each other. The second piston, the bridge, and the central portion of the body define a sealed chamber, which is sealed from the ambient.

Abstract: A tubular handling assembly includes an elevator and a tubular compensator assembly. The tubular compensator assembly includes a housing; a lift member coupled to the housing; a support member; and an actuator for moving the housing and the lift member relative to the support member and the elevator.

Abstract: A packer assembly (2) for deforming casing (4) is described. Packer assembly (2) comprises a first body portion (8) removably connectable to a second body portion (10). An elastomeric packer element (12) is disposed on the first body portion (8) and is configured to be deformed into an outwardly deployed condition in response to actuation of at least one piston (14) disposed on the second body portion (10). A locking means (16) is disposed on the first body portion (8) and is configured to retain the elastomeric packer element (12) in the outwardly deployed condition after it has deformed casing (4). The first body portion (8) can be disconnected from the second body portion (10) after the elastomeric packer element is deployed to deform casing (4) to enable retrieval of the second body portion (10) from the wellbore.

Abstract: A payload deployment tool is provided. The tool includes a housing having a coupler configured to couple to a fluid delivery conduit; a pressure chamber in communication with the coupler; a plurality of payload chambers in communication with the pressure chamber, each of the payload chambers having an upstream opening and a downstream opening; and a plurality of upstream pressure-rupturable seals respectively covering the upstream openings.

Abstract: A centraliser comprises a mandrel, a first support member, a second support member, and a plurality of arm assemblies connected between the first and second support members. Each arm assembly comprises a first arm pivotally connected to the first support member at a first pivot axis and a second arm pivotally connected to the second support member at a second pivot axis, and the first and second arms pivotally connected together at a third pivot axis. The mandrel comprises a plurality of facets spaced apart around an outer surface of the mandrel to rotationally key the first and/or second support member to the mandrel, and each arm assembly is arranged so that the third pivot axis is located on a first side of a plane coincident with a central axis of the device and the first and second pivot axes are located on an opposite second side of the plane.

Abstract: A system and a method for determining a location of an untethered drone in a wellbore are described herein. The system includes one or more markers to be placed within a wellbore casing where each of the one or more markers is configured to transmit a continuous or periodic signal. The system further includes a first sensor to be transported by the untethered drone where the first sensor is configured to sense an existence of the one or more markers.

Abstract: A system for a wellbore can include a tubing string positioned downhole in a wellbore and a porous gravel pack. The porous gravel pack can be positioned in an annulus defined at least in part by a surface of the tubing string. The porous gravel pack can be made up of a plurality of grains. Each grain can include a core surrounded at least in part by a sheath. The core can comprise an expandable material that can expand in response to coming in contact with a fluid. The sheath can surround the core and can be deformable in response to the core expanding in response being exposed to a fluid.

Abstract: A horizontal directional drilling rig is described. The rig can be entirely electrically powered. The performance (or “health”) and/or the life cycle of individual components of the rig can be electronically monitored. This permits identification of specific individual components that are performing in a substandard manner or are not performing properly or have reached the end of their life cycle. Individual improperly performing components or components at the end of their life cycle can thus be specifically identified. The improperly performing component(s) or components at the end of their life cycle can then be replaced. In some embodiments, when a component is identified as performing improperly, the operation of other, properly functioning components of the rig can be modified accordingly to account for the improperly performing component.

Abstract: A tool for cleaning out the lower end of a cased wellbore having an installed production string. The tool is lowered down the production string until it projects from an end of the production string and into the wellbore. High pressure fluid is then sprayed from the tool's fluid openings into nearby portions of the wellbore. Once cleaning operations are complete, the tool is carried back to the ground surface using subterranean fluid pressure.

Abstract: A downhole sub has a body defined by a wall extending in an axial direction from a first end to a second end. An inner surface of the wall defines a flow path through the downhole sub and an outer surface of the wall defines an outer diameter of the downhole sub. A compartment extends from the outer surface into the wall to having a depth less than a thickness of the wall. A housing may be removably fixed in the compartment. One or more mobile devices may be disposed in the housing. Each of the one or more mobile devices includes a sensor encapsulated in a protective material. A control element may block an opening of the housing, the control element is made of a dissolvable material configured to dissolve at a predetermined depth in a wellbore and release the one or more mobile devices into the wellbore.

Abstract: A method to test or monitor the integrity of a cement barrier, comprising providing an assembly therebelow including: a perforating device; a control mechanism to control the perforating device, a pressure sensor, a wireless communication device and a pressure sensor. The perforating device is activated to perforate casing below the barrier and a pressure test may be conducted. The creation of the perforation(s) below the barrier allows an assessment of the integrity of the barrier across its entire width, and especially its bond to the formation, rather than only a central portion of the barrier. Electromagnetic or acoustic wireless signals are used to retrieve data from below the barrier.

Abstract: Tools for sealing a tubing in a downhole environment. The tools feature top and bottom slip assemblies and a monolithic sealing element. The monolithic sealing element includes a portion that is disposed between the top and bottom slip assemblies as well as portions that encapsulate the slip assemblies. When the tool is actuated from a run-in configuration to a set configuration, the slips move toward each other squeezing the sealing element so that it forms a fluid-tight seal with the tubing. Teeth of the slip assemblies penetrate the portions of the sealing element disposed thereon and bite into the tubing.

Abstract: There are described devices and methods for use, for example, with signaling in a well, e.g. using a well structure of the well. Such signaling may include the communication of power and/or data signals. The devices and methods used may assist with efficient and/or effective communication of such signals. In some examples, there is described deployable devices and methods, e.g. a deployable device for signaling contact in a well, and methods associated therewith.

Abstract: Disclosed are methods and devices for testing downhole connector electrical systems and cable integrity during installation of a permanent completion, including a customized retrievable plug arm assembly connectable to the completion during RIH, the tool mimicking a retrievable ESP, but without motor, and can be employed with or without pressure isolation. Another method employs a slidable starpoint located within the downhole wet mate connector of the completion to provide continuous electrical contact between the phases when no retrievable assembly is in place. When a retrievable assembly is later put in place, the slidable starpoint is moved into a second position that no longer provides electrical contact between the phases. Another method uses fusible links installed between two conductors within the downhole electrical connector system of the completion to provide similar electrical contact between phases, the fusible link configured to melt away once motor current is sent through the conductors.

Abstract: Provided is an anti-rotation system and method of operating a downhole tool. The anti-rotation system, in one embodiment, includes a housing defining a longitudinal axis, and a carriage mounted within the housing, the carriage including at least one anti-rotation blade configured to engage a formation and resist rotation of the housing about the longitudinal axis. The carriage, in accordance with this embodiment, is configured to rotate about a carriage axis and tilt the at least one anti-rotation blade from a first extended position to a second at least partially retracted position.

Abstract: A method for increasing an amplitude of reciprocal axial extensions and contractions of a shock tool configured to induce axial oscillations in a drillstring during drilling operations includes (a) selecting the shock tool. The shock tool has a central axis and an axial length. The shock tool includes an outer housing, a mandrel telescopically disposed within the outer housing, and a first annular piston fixably coupled to the mandrel. The shock tool has a first amplitude of reciprocal axial extension and contraction at a pressure differential between a first fluid pressure in the outer housing and a second fluid pressure outside the outer housing. In addition, the method includes (b) fixably coupling a second annular piston to the mandrel of the shock tool and increasing the axial length of the shock tool after (a). The second annular piston is axially spaced from the first annular piston.