Abstract: An actuation device comprises a housing, and a plurality of permanent magnets disposed about the housing. The plurality of permanent magnets is configured to selectively transition between a first position and a second position. The plurality of permanent magnets is configured to provide a stronger magnetic field strength outside the housing than inside the housing in the first position, and wherein the plurality of permanent magnets is configured to provide a stronger magnetic field strength inside the housing than outside the housing in the second.

Abstract: A method of actuating a downhole component comprises positioning a magnetic positioning tool adjacent an actuable component within a wellbore, where the magnetic positioning tool comprises a plurality of magnets arranged in a first position, transitioning the plurality of magnets from the first position to a second position, detecting the plurality of magnets using a sensor associated with the actuable component, generating a signal indicative of the plurality of magnets being in the second position, and actuating the actuable component within the wellbore in response to the signal.

Abstract: A method and apparatus that includes an elongated base pipe having an external surface at least partially defining an external region and an internal surface at least partially defining an internal region; and a pressure maintenance device disposed in the base pipe and comprising: a flow path that extends between the internal region and the external region; and a valve having a gas charged chamber, the valve allowing the flow of a fluid from the internal region to the external region through the first flow path when a pressure differential between a pressure associated with the internal region and a pressure associated with the gas charged chamber is less than a maximum pressure threshold and when a pressure differential between the external region and the pressure associated with the gas charged chamber is greater than a minimum pressure threshold.

Abstract: In accordance with embodiments of the present disclosure, a travel joint includes a tube disposed at one end of the travel joint and a mandrel disposed at an opposite end of the travel joint. The mandrel is partially disposed in a hollow portion of the tube, and the tube and the mandrel are axially slidable relative to each other to extend or compress the travel joint. The travel joint also may include a housing coupled to the tube and disposed around the mandrel and a locking mechanism between the housing and the mandrel disposed in a position to selectively lock the mandrel and the tube in an axial position relative to each other to partially compress the travel joint. In some embodiments, the travel joint may include a fluid brake having a fluid chamber disposed between the mandrel and the tube to dampen axial movement between the mandrel and tube.

Abstract: A multiple control line travel joint is disclosed having at least one non-coiled, fluid control line and at least one internal control line, such as a hydraulic, electrical, or fiber optic control line. The fluid control line can include an upper control line that enters the travel joint at a top port and a lower control line that exits out a bottom port of the travel joint. The top port and bottom port can be fluidly coupled through a sealed chamber in the travel joint. The second control line can be coiled within the sealed chamber. As the travel joint expands and contracts, the sealed chamber expands and contracts while remaining sealed, maintaining sealed fluid coupling between the top port and the bottom port.

Abstract: Assemblies and methods of use are disclosed for determining a position of a body within a tubing section. A signal generator coupled to the body is operable to generate a pressure wave in response to detecting a detectable portion of the tubing section when the body is moved relative to the tubing section.

Abstract: A method and apparatus that includes positioning a completion string that has an internal passageway and that has an external surface that at least partially defines an external region within a wellbore; isolating a zone of the external region from a wellbore hydrostatic pressure; measuring a pressure within the external region of the isolated zone; determining whether the pressure within the external region of the isolated zone is within a predetermined pressure range; and operating a valve that controls a flow of a fluid through a flow path from the internal region to the external region of the isolated zone when the pressure within the external region is outside of the predetermined pressure range.

Abstract: A system includes a downhole tool assembly extendable within a wellbore. A running tool axially interposes the downhole tool assembly and the conveyance and includes an elongate body providing an interior and one or more radial protrusions. A connection sub is disposed about the body and provides a releasable connection engageable with the downhole tool assembly. A torque sleeve is disposed about the body and at least a portion of the connection sub. A connection sub piston interposes the body and the connection sub and is axially movable between a supported position, where the connection sub piston radially supports the connection sub, and an unsupported position, where at least a portion of the connection sub is radially unsupported by the connection sub piston. Increasing pressure within an annulus between the running tool and the wellbore moves the connection sub piston from the supported position to the unsupported position.

Abstract: A wellbore system can include a completion assembly having a completion string. The system can also include a service string that can be positioned within an inner diameter of the completion string. A location-sensing component can be positioned on the completion string or the service string. A communication link communicatively coupled with the location-sensing component can transmit signals representing a stimuli detected by the location-sensing component. A stimuli-producing device can output the stimuli that is detected by the location-sensing component. A stimuli-producing device can be positioned on the other of the completion string or the service string.

Abstract: A well packer includes an expandable member carried on a mandrel, the mandrel including a groove formed on at least a portion of an outer radial surface of the mandrel; a back-up assembly carried on the mandrel adjacent the expandable member; and a fold back assembly carried on the mandrel adjacent the back-up assembly, the fold back assembly including a snap ring carried on the mandrel and adapted to move into the groove and adjust the expandable member into an expanded position in substantially sealing contact with a tubular.

Abstract: A sensing system comprises at least one gauge disposed in a wellbore, a sensing link coupled to the at least one gauge, and a debris barrier coupled to the sensing link. The debris barrier comprises a housing coupled to the sensing link, and a barrier element configured to reduce the transport of particulates from the wellbore into the sensing link.

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 example wellbore system includes a wellbore at least partially lined with casing and having an upper control line extending on an exterior of the casing and conveying one or more first communication media, a casing nipple provided on the casing and defining a nipple profile, an upper control line connector coupled to the casing nipple and communicably coupled to the upper control line, a connector assembly arranged on a wellbore tubing extendable within the wellbore and defining an anchor profile engageble with the nipple profile, and a lower control line connector coupled to the connector assembly and communicably coupled to a lower control line extending along the wellbore tubing and conveying one or more second communication media, wherein the one or more first and second communication media are communicably coupled by radially expanding and rotating the lower control line connector with respect to the upper control line connector and thereby mating the upper and lower control line connectors.

Abstract: A well treatment for treating a well includes discrete stop loss elements to seal a fluid loss opening of a well. The discrete stop loss elements include polymer resistive to deformation with an initial stiffness in response to an initial strain rate of the polymer to produce a specified initial pressure signal and deformable with a subsequent, lower stiffness in response to a subsequent, lower strain rate of the polymer to produce a subsequent, different specified pressure signal.

Abstract: A well system includes a drop plug element and an internal plug seat in an internal flow path of a well tubing. At least one of the plug seat or the drop plug element includes a polymer that is deformable, having a first stiffness when subjected to a first strain rate, to allow the drop plug element to pass through the plug seat. The polymer resists deformation, having a second, higher stiffness when subjected to a second, higher strain rate, to resist allowing the plug element to pass through the plug seat and to seal the plug element and plug seat.

Abstract: A wellbore cementing plug includes a plug element including a polymer. The polymer is deformable at a first stiffness when subjected to a first strain rate to allow the plug element to pass through a wellbore while sealing against passage of cement past the plug element. The polymer resists deformation at a second, higher stiffness when subjected to a second, higher strain rate to resist allowing the plug element to pass through the wellbore while sealing against passage of cement past the plug element.

Abstract: A telescoping joint is provided with one or more control lines and is usable for landing a subsea tubing hanger. The telescoping joint can include an inner mandrel, an outer mandrel, a seal between the inner mandrel and the outer mandrel, and a coiling chamber. The outer mandrel is controllably releasable from the inner mandrel by a release mechanism. The seal is sealably engaged with the outer mandrel for continuously sealing an inner area defined by the inner mandrel from a wellbore environment exterior to the telescoping joint as the outer mandrel axially moves relative to the inner mandrel. A control line is coiled in the coiling chamber and the coiling chamber is axially positioned between the release mechanism and the seal.

Abstract: Video of an above ground effect of a subterranean event is received. The subterranean event is identified using Eulerian video magnification of the received video.

Abstract: Video of an effect on equipment of an event is received. The event is identified using Eulerian video magnification of the received video.

Abstract: Z An example control line connector includes an expandable housing having a helical body that defines one or more windings and a helical shroud disposed about the one or more windings, wherein a helical conduit chamber is defined between the helical body and the helical shroud, a matable connector at least partially disposed within the expandable housing and providing a mating face that faces tangentially with respect to the expandable housing so as to angularly mate with an opposing matable connector, and a splitter block coupled to the expandable housing and conveying one or more communication media into the helical conduit chamber to communicate with the matable connector.