Abstract: An actuation device for actuating a target sleeve valve assembly of a plurality of sleeve valve assemblies in a wellbore tubing string is provided. The device comprises a housing and a catch structure. The catch structure is actuatable between an inactive state and an activated state. In the inactive state, the device may travel through non-target sleeve valve assemblies. In the activated state, the device may be seated in the target sleeve valve assembly. The apparatus has a first sensor operable for detecting a first detectable feature associated with each non-target sleeve valve assembly, and a second sensor operable for detecting a second detectable feature associated with each non-target sleeve valve assembly. The device further includes a controller that increases a sleeve valve assembly count value responsive to detection of the first and second detectable features within a predetermined time window.

Abstract: A device for actuating a downhole tool includes a housing having a surface structure on an external surface thereof. The surface structure has an inactive state and an activated state. In the inactive state, the device can travel through seat structures mounted in a well tubing and will experience a physical impact having an impact level exceeding a threshold level when passing through each one of the seat structures. In the activated state, the device can seat in a selected seat in the well tubing. A sensor is enclosed in the housing and configured to generate a signal in response to the physical impact. A controller in the housing communicates with the impact sensor and monitors the physical impacts; and activates the surface structure based on the monitored physical impacts.

Abstract: Assemblies and methods are provided for a sleeve assembly for controlling communication with a downhole formation having a sleeve housing with one or more flow ports slidably retaining a sleeve, the sleeve having one or more treatment ports. The sleeve is configured to slide between an uphole closed position, in which the one or more flow ports are blocked by the sleeve, and a downhole open position in which the one or more flow ports are at least partially aligned with the one or more treatment ports. The one or more treatment ports may have inset members.

Abstract: The present disclosure is generally directed to a bottom hole assembly. The bottom hole assembly may include a by-pass valve assembly and a shifting tool assembly positioned downhole from the by-pass valve assembly. The bottom hole assembly may used to hydraulically fracture a wellbore and shift a well tool from a first position to a second position within the wellbore.

Abstract: The present disclosure is generally directed to a bottom hole assembly. The bottom hole assembly may include a by-pass valve assembly and a shifting tool assembly positioned downhole from the by-pass valve assembly. The bottom hole assembly may used to hydraulically fracture a wellbore and shift a well tool from a first position to a second position within the wellbore.

Abstract: Methods and apparatus of pressure activated completion tools for hydraulic fracturing and related processes are provided. In some embodiments, the hydraulic fracturing apparatuses for well testing and accessing subterranean formations can include a tubular body to be fluidly connected in-line with a completion string, a pressure storage mechanism to store pressure when exposed to hydraulic pressure, and a movable inner shift sleeve operable to slide along the inside of the tubular body from a first position to a second position when exposed to the stored pressure. The tubular body can have flow-port(s) that are blocked when the movable inner sleeve is in the first position and opened when the movable inner sleeve slides to the second position. Uses of such apparatuses can include fracing, toe intervention, and pressure testing of wells.

Abstract: A device for actuating a downhole tool includes a housing having a surface structure on an external surface thereof. The surface structure has an inactive state and an activated state. In the inactive state, the device can travel through seat structures mounted in a well tubing and will experience a physical impact having an impact level exceeding a threshold level when passing through each one of the seat structures. In the activated state, the device can seat in a selected seat in the well tubing. A sensor is enclosed in the housing and configured to generate a signal in response to the physical impact. A controller in the housing communicates with the impact sensor and monitors the physical impacts; and activates the surface structure based on the monitored physical impacts.

Abstract: The present disclosure is generally directed to a bottom hole assembly. The bottom hole assembly may include a by-pass valve assembly and a shifting tool assembly positioned downhole from the by-pass valve assembly. The bottom hole assembly may used to hydraulically fracture a wellbore and shift a well tool from a first position to a second position within the wellbore.

Abstract: A riser pipe system for releasably securing a rotating flow control device internally within a riser string for use in offshore drilling can include a riser pipe section, a removable latch assembly for releasably securing the RFCD, and optionally, a removable seal assembly for sealing against the RFCD. The latch and seal assemblies are disposed within the riser pipe section and axially restrained by at least one removable retaining member. The latch assembly and seal assembly may be hydraulically or pneumatically actuated together or separately.

Abstract: Methods and apparatus of pressure activated completion tools for hydraulic fracturing and related processes are provided. In some embodiments, the hydraulic fracturing apparatuses for well testing and accessing subterranean formations can include a tubular body to be fluidly connected in-line with a completion string, a pressure storage mechanism to store pressure when exposed to hydraulic pressure, and a movable inner shift sleeve operable to slide along the inside of the tubular body from a first position to a second position when exposed to the stored pressure. The tubular body can have flow-port(s) that are blocked when the movable inner sleeve is in the first position and opened when the movable inner sleeve slides to the second position. Uses of such apparatuses can include fracing, toe intervention, and pressure testing of wells.

Abstract: A stripping element for rotary flow control diverters used in the oil and gas industry can include a stiffening member formed of a first harder material than a deformable member formed of a second softer material over-molded to the stiffening member. The stiffening member can include apertures that provide for the second softer material of the deformable member to be displaced through the apertures when a pipe of a drill is displaced through the stripping element. The stiffening member can include multiple members that stiffen the deformable member to prevent the deformable member from bending into the stripping element when a pipe of a drill is displaced through the stripping element. The multiple members can be displaced out in a direction away from the pipe of the drill when the pipe of the drill is displaced through the stripping element to prevent the stripping element from being compromised.

Abstract: A stripping element for rotary flow control diverters used in the oil and gas industry can include a stiffening member formed of a first harder material than a deformable member formed of a second softer material over-molded to the stiffening member. The stiffening member can include apertures that provide for the second softer material of the deformable member to be displaced through the apertures when a pipe of a drill is displaced through the stripping element. The stiffening member can include multiple members that stiffen the deformable member to prevent the deformable member from bending into the stripping element when a pipe of a drill is displaced through the stripping element. The multiple members can be displaced out in a direction away from the pipe of the drill when the pipe of the drill is displaced through the stripping element to prevent the stripping element from being compromised.

Abstract: A riser pipe system for releasably securing a rotating flow control device internally within a riser string for use in offshore drilling can include a riser pipe section, a removable latch assembly for releasably securing the RFCD, and optionally, a removable seal assembly for sealing against the RFCD. The latch and seal assemblies are disposed within the riser pipe section and axially restrained by at least one removable retaining member. The latch assembly and seal assembly may be hydraulically or pneumatically actuated together or separately.