Abstract: The system for making or breaking the riser includes a robotic system. The robotic system includes one or more robotic arms configured to be disposed on a spider deck, and one or more riser-connection manipulation tools each having a camera and being configured to manipulate a riser connection, the camera being configured to capture an image of an object, wherein each robotic arm is configured to couple to one riser-connection manipulation tool. Further the system for making or breaking the riser includes a control system. The control system includes a robot controller in communication with the one or more robotic arms and configured to control the one or more robotic arms. The system for making or breaking the riser is configured to analyze the image to determine the location and orientation of the object and transmit the location and orientation of the object to the robot controller.

Abstract: A swivel anchor of a drill string comprises a slip arrangement, comprising a slip body and at least one slip element; upper and lower connections attachable to further components, wherein the slip arrangement is rotatable about a longitudinal axis with respect to the upper and lower connections and a slip joint, comprising upper and lower components, wherein the upper and lower components may move relative to each other parallel with a longitudinal axis, between an open and closed positions, wherein in the open position a longitudinal displacement between the upper and lower components is greater than when the slip joint is in the closed position, and wherein when the slip joint is in the closed position, the swivel anchor length is less than when in the open position.

Abstract: A system includes a processor(s), and a memory coupled to the processor(s) having instructions stored therein. When executed by the processor(s), the instructions cause the processor(s) to perform functions to: apply a treatment for stimulating production to at least a first well in a subterranean formation; determine a flow distribution based on at least one of a first-well measurement or a second-well measurement, the first-well measurement taken at the first well, and the second-well measurement taken at a second well; determine a length of a fracture between the first and second wells, based on the determined flow distribution; determine if the applied treatment at the first well interferes with the second well, based on the determined length of the fracture; and apply a diverting material at the first well if it is determined that the applied treatment interferes with the second well, in order to control well bashing.

Abstract: An all mechanical counter dart including a mandrel, a plurality of shoulder members disposed upon the mandrel and movable from a more downhole portion of the mandrel to a more uphole portion of the mandrel, individual ones of the plurality of shoulder members moving from an inactive position to an active position and back to an inactive position while traversing the mandrel, and an upset on the mandrel supporting the individual ones of the plurality of shoulder members when in the active position.

Abstract: Provided, in one aspect, is a fluid flow device. The fluid flow device, in one aspect, includes a housing having at least one fluid inlet and at least one fluid outlet, and a sleeve positioned within the housing. The fluid flow device according to this aspect additionally include a fluid flow member positioned within the sleeve, wherein the sleeve and fluid flow member are movable with respect to one another to define a first overlap distance and a first fluid flow path length when the housing encounters a first fluid flow pressure, and a second greater overlap distance and a second greater fluid flow path length when the housing encounters a second greater fluid flow pressure, the first fluid flow path length and the second greater fluid flow path length configured to provide a constant flow of the fluid out of the at least one fluid outlet.

Abstract: An apparatus and method for assisting transportation of a tool down a wellbore. The apparatus comprises an elongate body having an exterior surface extending between top and bottom ends, a connector at the bottom end operable to be secured above the tool and at least one passage formed into the exterior surface defining a first flow path having an entrance and an exit oriented towards the top end of the elongate body. The method comprises securing the elongate body to a top end of a tool in a wellbore, directing a flow of fluid down the wellbore to a position above the elongate body, separating the flow of the fluid into an inner portion and an outer portion through radially separated paths and redirecting the inner portion to flow upwards into the outer portion of the flow of the fluid.

Abstract: A tool (1) for manipulating a target with combustion products from a propellant includes a housing (2) defining a chamber (12), at least two propellant sources located within the chamber and spaced apart one from the other, an ignition mechanism for igniting propellant (26) at the propellant sources, and at least one chamber outlet (30) for combustion products from the propellant sources. Methods of manipulating a target using the tool are also described.

Abstract: A technique for remote pairing of pumps and manifold valves at an oilfield. The technique takes advantage of a control unit having remote capability of opening and closing manifold valves. The control unit may also be in simultaneous communication with an individual sensor for each pump. Thus, unique protocols of valve opening and closing at the manifold in conjunction with monitoring of fluid-based detections by the unit may be used to establish pairing between specific pumps and manifold valves. Similarly, the system may also be inspected for leaks at particular locations through unique valve opening and closing sequences in conjunction with fluid monitoring.

Abstract: A system (10) and method (50) of enabling the acquisition of borehole survey data and core orientation data in a single instrument trip in a core drill (12) having a drill string (18) and an inner core barrel assembly (16). The method uses a borehole survey tool 14 that is arranged to at least log its position in three-dimensional space. The borehole survey tool (14) is run down the drill string (12) in which the inner core barrel assembly (16) is installed. The inner core barrel assembly (16) is arranged to either provide or facilitate detection of an indication of tool face of a core sample (24) held in the inner core barrel assembly (16). The indication of tool face is then transferred mechanically or electronically to the visiting borehole survey tool (14).

Abstract: According to some embodiments, an autonomous perforating drone for downhole delivery of a wellbore tool, and associated systems and methods, are disclosed. In an aspect, the wellbore tool may be a plurality of shaped charges that are arranged in a variety of configurations, including helically, in one or more single radial planes, or opposing around a perforating assembly section, and detonated in a top-to-bottom sequence when the autonomous perforating drone reaches a predetermined depth in the wellbore. In another aspect, the shaped charges may be received in shaped charge apertures within a body of a perforating assembly section, wherein the shaped charge apertures are respectively positioned adjacent to at least one of a receiver booster, detonator, and detonating cord for directly initiating the shaped charges.

Abstract: A tool (1) for manipulating a target with combustion products from a propellant, includes a housing (2) defining a chamber (12), a propellant source located within the chamber (12), an ignition mechanism (28) for igniting propellant (26) at the propellant source, and at least one chamber outlet (30) for combustion products from the propellant source. The tool (1) is configured to automatically open the chamber outlet (30) from a closed condition, following ignition of the propellant (26) at the propellant source. Methods of manipulating a target using the tool are also described.

Abstract: The present invention relates to a downhole line separation tool for submerging into a casing in a wellbore, the downhole line separation tool having a first tool end, a second tool end and a tool axis, comprising a tool housing having a first housing part and a second housing part, an electrical motor arranged within the first housing part and powered through a wireline connected to the first tool end, an annular separation element having an element end facing away from the first tool end and being rotatably connected within the second housing part, and a rotatable shaft arranged within the second housing part and rotated by the electrical motor for rotating the annular separation element, wherein the second housing part comprises a sleeve part having a sleeve end, at least part of the annular separation element projecting from the sleeve end further away from the first tool end than the sleeve, the second housing part comprising at least one projecting part extending further away from the first tool end tha

Abstract: Examples of the present disclosure relate to systems and methods for mapping a wellbore for refracturing. More specifically, embodiments are directed towards utilizing downhole pressure data to identify previously untreated clusters, clusters with cross contamination, and clusters with proper zonal isolation with full pressure integrity.

Abstract: An apparatus for drilling curved and straight sections of a wellbore is disclosed that in one non-limiting embodiment includes a drilling assembly configured to include a drill bit at an end thereof that can be rotated by a drive in the drilling assembly and by the rotation of the drilling assembly, and wherein the drilling assembly includes: a deflection device that (i) tilts a section of the drilling assembly within a selected plane when the drilling assembly is substantially rotationally stationary to allow drilling of a curved section of the wellbore by rotating the drill bit by the drive; and (ii) straightens the section of the drilling assembly when the drilling assembly is rotated to allow drilling of a straight section of the wellbore.

Abstract: A downhole valve includes a housing, and a sleeve positioned within the housing. The sleeve has a first axial end, a second axial end, and a seat positioned between the first and second ends. The sleeve defines an opening facing in a radial direction. The sleeve prevents fluid flow in an opposite radial direction, away from the opening. The valve also includes a retaining element coupled to or integral with the sleeve, and a first obstructing member positioned in the sleeve and movable between the seat and the retaining element. In a first position, the first obstructing member engages the seat and prevents fluid flow through the housing. In a second position, the first obstructing member is separated apart from the seat such that at least a portion of the opening is axially between the first obstructing member and the first obstructing member.

Abstract: A deployment system as a rig less docking station with an inline male wet mate-able connectors and power cable and a motor connector with inline female wet mate-able connectors coupled to an electric submersible pump (ESP), the docking station is at the bottom of a string of production tubing and remains in the well for the life of the system while the motor connector is mated to an ESP and lowered into the well by wireline or other suitable deployment method. The rig less deployment system has a lower initial cost, larger through-bore, improved debris tolerance, and the ability for pump-assisted installation and retrieval techniques. Both the moveable female and the static male connector are pressure balanced for temperature and volume variation and the male connector utilizes a heavy dielectric fluid in a reverse labyrinth design to isolate borehole fluid from the electrical connection.

Abstract: A valve useful in an inflow control device for downhole use in an oil and gas well completion equipment is disclosed. The valve may have a flexible canopy that prevents fluid flow between the base pipe and the formation when flow travels in a first direction and permits fluid flow between the base pipe and the formation when flow travels in a second direction.

Abstract: A downhole tool having a mandrel, and a bottom slip disposed around the mandrel. The bottom slip includes a circular body having a one-piece configuration characterized by a plurality of slip segments by at least partial material connectivity therearound. The bottom slip is made of a filament wound composite material, which means the bottom slip has a plurality of layers joined by respective interface layers. An outer slip surface of at least one of the plurality of slip segments is defined in cross-section by a plane P that intersects a longitudinal axis of the downhole tool at an angle a1 when the bottom slip is in an unset position.

Abstract: A downhole motor includes a driveshaft assembly including a driveshaft housing and a driveshaft rotatably disposed within the driveshaft housing, and a bearing assembly including a bearing housing and a bearing mandrel rotatably disposed within the bearing housing, wherein the bearing mandrel is configured to couple with a drill bit, wherein the bearing assembly is configured to provide a first flowpath extending into a central passage of the bearing mandrel from an annulus formed between the bearing mandrel and the bearing housing and a second flowpath separate from the first flowpath, that extends through a bearing of the bearing assembly that is disposed radially between the bearing mandrel and the bearing housing, wherein a plurality of rotary seals are positioned radially between the bearing mandrel and the bearing housing to form an sealed chamber that is spaced from the bearing of the bearing assembly.

Abstract: A device and method for imaging, measuring and identifying multiphase fluid flow in wellbores using phased array Doppler ultrasound. The device includes a radially-configured or ring-shaped ultrasound transducer that when deployed in a well in Doppler mode can measure the velocity of radially flowing fluids in the wellbore and generate a 3D image of radial flow in the wellbore, including flowback into the wellbore after fracturing operations, or flow leaving the wellbore during water injection operations. The ring-shaped ultrasound transducer can also simultaneously operate in a B-mode to generate a B-mode image of the wellbore liner upon which the Doppler image can be overlaid. The device may also include a forward facing ultrasound transducer either instead of or in place of the ring-shaped transducer for obtaining information and images on axial flow in the wellbore in Doppler mode, and the location of phase boundaries and phase locations in B-mode.