Abstract: The invention relates to variation of concentrations of abrasive particles in a stream of drilling fluid mixed with abrasive particles, passed as an abrasive jet through abrasive nozzle(s) of a drill bit along rotations thereof, to vary the erosive power of the stream along angular sections of the borehole for directional drilling. During subsequent time periods majorities of abrasive particles are alternately deflected into two parallel channels with a different flow resistance. A resulting velocity difference between said majorities makes that the subsequently deflected majorities recombine downstream of the channels, so that high concentration stream portions of the combined majorities are formed which alternate low concentration stream portions. Synchronising the frequency of the stream portions with the rotational velocity of the drill bit results in a consistently higher erosive power of the abrasive jet within a selected angular section of the borehole than outside thereof.

Abstract: A screen assembly, such as a downhole/sand screen assembly, comprising first and second screen portions or screens longitudinally coupled together, wherein there is provided a fluid flow path between the first and second screen portions or screen. Optionally, the first and second sleeves are coupled or connected by a centraliser or further sleeve or screen, and/or optionally by or via first and second support ring.

Abstract: An electric submersible pump (ESP) assembly. The ESP assembly comprises an electric motor; a seal section; a fluid intake; a charge pump assembly located downstream of the fluid intake and having an inlet in fluid communication with an outlet of the fluid intake, having a fluid mover coupled to a drive shaft, and having a fluid reservoir located downstream of the fluid mover; a gas separator assembly located downstream of the charge pump assembly and having an inlet in fluid communication with an outlet of the charge pump assembly; and a production pump assembly located downstream of the gas separator assembly and having an inlet in fluid communication with a liquid phase discharge port of the gas separator assembly.

Abstract: A downhole tool, for removing a restriction in a well tubular metal structure having a wall and an inner diameter, has a tool axis and a tool body having a first part and a second part, an electrical motor arranged in the first part for rotating a rotatable shaft, and a core bit arranged in the second part and having a first end connected with the rotatable shaft and a second end having a cutting edge. The second part of the downhole tool further includes a locator for locating the rim section, the locator being rotable with the core bit until the locator locates the rim section and a threshold value is reached.

Abstract: A downhole tool of this disclosure includes a set/reset ring located adjacent a gauge ring which is opposite at least one sealing member. The set/reset ring is arranged to move between an unset diameter at least equal to the unset diameter of the sealing member and a set diameter at least equal to the set diameter of the sealing member. The set/reset ring is like a coil spring having at least two full turns and, therefore, a 360° face surface when in its unset and set diameters. When a setting mandrel moves toward the sealing member, the sealing member moves to its set diameter and the set/reset ring moves into its set diameter. When the setting mandrel moves away from the sealing member, the sealing member returns to its unset diameter and the set/reset ring returns to its unset diameter.

Abstract: A repairing assembly includes a housing, a packer, and a thermal spray assembly. The housing is attached to a wellbore string disposed within a wellbore with casing. The packer is coupled to the housing. The packer is set on a wall of the wellbore to bound a repair zone defined between the packer and an end of the housing opposite the packer. The housing or the packer includes a fluid channel in fluid communication with the wellbore string or an annulus of the wellbore. The thermal spray assembly is coupled to the housing and sprays a damaged section of the casing with a thermal spray to repair the damaged section. The housing flows an inert gas received from the wellbore string or the annulus of the wellbore and through the fluid channel into the repair zone until an oxygen in the repair zone is substantially removed from the repair zone.

Abstract: A method of recovering casing from a wellbore in which: a logging tool is run to an estimated stuck point of the casing through the central bore of the casing spear and casing cutter; the casing spear is attached to the casing and tension applied so that logging can be performed over a length at an estimated stuck point both with and without tension to provide the verified stuck point; and the casing cutter is positioned relative to this to cut the free casing; and the spear used to remove it. The method can be performed on a single trip. Embodiments include incorporating a packer to circulate fluid during casing cutting; a disconnect, anchor mechanism and motor to allow use of a motor to operate the cutter; and a Down Hole Power Tool with a method of establishing the required force to recover a length of stuck casing.

Abstract: An oil well tool operable to be deployed downhole on a production string including a tubular member having a wall extending from a first end to a second end opposite the first end and the wall forming a plurality of apertures. The oil well tool also includes a mesh screen coupled to an inner surface of the wall of the tubular member and covering the plurality of apertures.

Abstract: A connector for connecting a first wellbore tubular to a second wellbore tubular includes a tubular housing connectable to the second tubular and an internal surface facing an internal bore, and a ramp assembly arranged around the surface having a plurality of elongate ramp arrays and a plurality of elongate channels arranged to separate adjacent ramp arrays. The connector includes a slip body which is insertable into the internal bore having an internal surface with at least one slip tooth for engaging the first tubular, an external surface and a ramp assembly arranged around the external surface having a plurality of elongate ramp arrays which grip the first tubular and a plurality of elongate channels arranged to separate adjacent ramp arrays. The ramp arrays of the slip body are each alignable with a respective channel of the tubular housing. The slip body is rotatable within the tubular housing.

Abstract: A stabilizer can include an outer collar, an inner sleeve, and a locking mechanism. The locking mechanism is changeable between a first mode in which the outer collar is rotationally fixed to the inner sleeve and a second mode in which the outer collar is rotationally isolated relative to the inner sleeve. The stabilizer may include an active or passive system for changing modes. An example passive device may include a magnetic clutch where the detected force overcomes magnetic forces to change mode. The stabilizer can be used to mitigate whirl on a rotating device by switching the rotating device between a rotating mode and a non-rotating mode. In the rotating mode, outer collar may rotate with the inner sleeve. In the non-rotating mode, the outer collar may be rotationally isolated from the inner sleeve.

Abstract: A system includes a flexi-string having a first lateral end, a second lateral end, and an outer diameter. The outer diameter defines an outer circumferential surface, and the outer diameter is smaller than an inner diameter of a casing shoe. The system further includes an anchor disposed on the outer circumferential surface of the first lateral end, where the anchor interacts with the casing shoe, or a last joint of casing, to hold the first lateral end of the flexi-string within the casing shoe. The system also has centralizers located between the first lateral end and the second lateral end of the flexi-string. The centralizers are configured to center the flexi-string within the casing shoe and the washout section. Finally, the system includes a roller guide for lowering the flexi-string inside the casing shoe and to a depth below the washout section of the well.

Abstract: A cutting tool can be used to cut through a tubing string in a wellbore. Metal cuttings are formed during the cutting process. The cutting tool can include a cutting insert with a blade that is rotated around a longitudinal axis of the tool. A nose can include a spiral cutout adjacent to the blade. The spiral cutout can force the metal cuttings down past the outside of the nose and down into the tubing string. The nose can also include a guide on the outside underneath the blade. The guide can also provide a pathway for the metal cuttings to fall past the outside of the nose and down into the tubing string. The spiral cutout and the optional guide can be used to prevent metal cuttings from lodging within the cutting tool and preventing the tool from rotating and cutting.

Abstract: A system includes production tubing, an electric submersible pump, a motor, a shroud, a motor head, and a cable. The production tubing traverses a packer and is disposed within the well. The electric submersible pump is connected to the production tubing and is located up hole from the packer. The motor is located up hole from the packer and is configured to power the electric submersible pump. The shroud encapsulates the motor, isolates the motor from an external environment, and contains a flow of produced fluids coming from the production tubing. The motor head is connected to the production tubing and extends from the external environment into the shroud. The power cable is connected to a section of the motor head that is located outside of the shroud and isolated from the produced fluids by the packer and the shroud.

Abstract: A cable head for attaching a wireline to a downhole tool includes an upper tubular member and a lower tubular member removably attached by a threaded connection. The cable head includes a pack-off assembly disposed within the upper tubular member. The pack-off assembly includes a deformable pack-off element comprising an outer sidewall for sealing against an inner sidewall of the upper tubular member, and an inner sidewall for sealing around the wireline. The pack-off assembly includes a biasing means axially in line with the deformable pack-off element. The pack-off element and the biasing means are axially compressed between an internal shoulder of the upper tubular member and the lower tubular member when the upper and lower tubular members are removably attached by the threaded connection, to enhance the seal of the tubular pack-off element with the inner sidewall of the upper tubular member, and with the wireline.

Abstract: A wireline clean-out tool including a first opening and a second opening at or near a free-end portion. The first opening takes in debris from a wellbore, the second opening ejects fluid into the wellbore. A housing defines a first flow path from the first opening at the free-end portion to an opposite end portion of the housing and a second flow path from the opposite end portion to the second opening at the free-end portion. The flow paths couple with each other at the opposite end portion. A collection chamber is in the first flow path for collecting debris during operation. A progressive cavity pump with hollow rotors is placed inside the housing at a predefined distance from the free-end portion being configured for operating on the first flow path while the hollow rotor forms part of the second flow path.

Abstract: Pumping of wellbore fluid to a surface may have a detrimental effect on the pump performance due to high gas concentrations in the fluid. A pump system that utilizes a helix gas separator provides greater pump efficiency by effectively removing the gas phase of the fluid. The wellbore fluid received at a pump system is directed from an intake to a gas separator that utilizes a stationary auger. The stationary auger induces rotational motion of the wellbore fluid causing the wellbore fluid to separate into a gas phase and a liquid phase. The stationary auger utilizes a tapered diameter and an opening between one or more helixes or vanes to separate a gas phase more efficiently from a liquid phase of a fluid.

Abstract: Systems and methods are provided to facilitate connection of multiple stage completions. A first completion stage is deployed at a wellbore location. Subsequently, the next completion stage is moved downhole into engagement with the first completion stage. The completion stages each have communication lines that are coupled together downhole via a wetmate connection. Debris prevention and removal devices and methods are also provided.

Abstract: An explosive downhole tool includes a housing having an upper housing part on one side of a window section and a lower housing part on an opposite side of the window section. An explosive charge is provided within the housing for at least one of cutting and expanding the wall of the tubular. The outer surface of at least one of the upper and lower housing part is rounded so as to be devoid of corners. The rounded surface eliminates the presence of sharp corners that may catch on restrictions or protrusions in a wellbore so that the downhole tool is more easily conveyable within a wellbore. Another explosive downhole tool includes fins extending from the housing. The fins have a height that decreases in a direction away from the housing. The shape of the fins enables the downhole tool to be more easily conveyable within the wellbore.

Abstract: A shaped charge assembly for selectively expanding a wall of a tubular includes a housing comprising an outer surface facing away from the housing and an opposing inner surface facing an interior of the housing. First and second explosive units each includes a predetermined amount of explosive sufficient to expand, without puncturing, at least a portion of the wall of the tubular to form a protrusion extending outward into an annulus adjacent the wall of the tubular.

Abstract: A system includes an upper connection having a ring shape with an external surface, where upper splines are formed on the external surface and the upper connection is fixed to the upper section. The system also includes a lower connection having a ring shape with an internal surface, where lower splines are formed on the internal surface and the lower splines are configured to mate with the upper splines of the upper connection. Further, the system includes a fishing sub having a first lateral end and a second lateral end, where the first lateral end is fixed to the lower connection by shear pins configured to shear when a pre-determined tension is applied to the system, and the second lateral end is fixed to the lower section. The upper connection is inserted into the lower connection to form an engagement between the upper section and the lower section.