A wellbore downhole tool, comprising: a nozzle assembly, the nozzle assembly includes a nozzle including: a cylindrically-shaped tube with a substantially uniform outer diameter across substantially an entire height of the nozzle, at least one retaining body opening located in an outer wall of the nozzle; a holding body including: a conduit, the conduit sized to fit the nozzle there-through, an alignment opening extending from an outer surface of the holding body to the conduit; and a retaining body sized to fit within the alignment opening of the holding body and to contact the retaining body opening of the nozzle when the nozzle is inserted in the conduit such that the cylindrically-shaped tube of the nozzle cannot rotate or move further in or out of the conduit. A method of assembling the wellbore downhole tool is also described.

An apparatus performs a method for cleaning a wellbore. The apparatus is a jet sub including an engine, a flow diverter and mixing throat. The engine propels a driving fluid at a first end of the jet sub towards a second end of the jet sub along a longitudinal axis of the jet sub. The flow diverter redirects the driving fluid by a redirection angle that is an obtuse angle. The mixing throat receives a mixed fluid including the driving fluid from the flow diverter and induced fluid drawn into the mixing throat by the driving fluid. The mixed fluid is injected into an annulus of the wellbore at the obtuse angle.

An uphole end for a compression-set straddle packer has a multicomponent mandrel and a multicomponent sliding sleeve that reciprocates within a limited range on the multicomponent mandrel. A bias element constantly resists relative movement between the multicomponent mandrel and the multicomponent sliding sleeve.

Cleanout tools and related methods of operation. At least some of the example embodiments are cleanout tools including a tool body that defines an internal annular channel, a joiner coupled to the tool body, a sleeve telescoped within the joiner and tool body, and a ball disposed within the annular channel. The ball held within the annular channel by the sleeve, and the ball configured to move along the annular channel under force of fluid pumped into the cleanout tool. The ball creates a pulsing of fluid streams exiting the tool body. Moreover, in some example systems the fluid streams created by the tool body intersect the inside diameter of a casing at non-perpendicular angles.

The invention relates to a method of conducting a perf wash cement (“P/W/C”) abandonment job in an offshore oil or gas well annulus, in particular the washing or cementing operation using a rotating head with nozzles dispensing wash fluid or cement at pressure. A new design of bottom hole assembly is proposed in which the cementing tool has a relatively large diameter in order to optimize pressure whilst the wash tool has a relatively small diameter. The wash process, for a number of reasons, appears to be less sensitive to tool diameter and making the wash tool smaller reduces the overall risk of stuck pipe.

A jet flow adjustment method for rotary steerable downhole release relates to a technical field of downhole drilling equipment for oil wells, which includes steps of: defining a diversion ratio p of a jet nozzle (2) by a ground control system according to a cleaning requirement of a cuttings bed; and sending the diversion ratio p of the jet nozzle (2) to a control unit of a downhole rotary steerable system; and determining an opening area s of the jet nozzle (2) by the control unit of the downhole rotary steerable system according to the diversion ratio p of the jet nozzle (2) and an equivalent channel area S of a drilling tool, wherein a calculation formula is: s=p*S/(1−p); controlling an adjustable bypass valve (3) by the control unit of the downhole rotary steerable system according to the calculated opening area s of the jet nozzle (2), so as to control an overlapping area between sector holes (9) of a rotor end (7) and a stator end (8), thereby opening the jet nozzle (2) for release. The present invention has simple control and strong release ability, which can effectively solve the jamming problem of the rotary steerable downhole tool.

A method for lateral drilling into a subterranean formation whereby a shoe is positioned in a well casing, the shoe defining a passageway extending from an upper opening in the shoe through the shoe to a side opening in the shoe. A rod and casing mill assembly are inserted into the well casing and through the passageway in the shoe until a casing mill end of the casing mill assembly substantially abuts the well casing. The rod and casing mill assembly are rotated until the casing mill end substantially forms a perforation in the well casing. An internally rotating nozzle is attached to an end of a hose and is pushed through the passageway and the perforation into the subterranean formation, and fluid is ejected from tangential jets into the subterranean formation for impinging upon and eroding the subterranean formation.

An apparatus for controlling a flow of fluid downhole comprises a removable fluid nozzle in fluid communication with a production tubular disposed in a borehole penetrating the earth. The removable fluid nozzle is configured for bi-directional flow, wherein a pressure drop of fluid flow in one direction is greater than the pressure drop of fluid flow in the other direction.

There is disclosed herein a method and apparatus for using rupture pins to selectively open jets on a jet perforating tool. Rupture pins inserted in jets within a jet perforating tool are configured to rupture at pre-designed thresholds, thereby opening the jet to begin a perforating job, or to circulate fluid through the tool. Also disclosed are systems and methods for holding the rupture pins within the tool prior to rupture.

A wellbore downhole tool, comprising: a nozzle assembly, the nozzle assembly includes a nozzle including: a cylindrically-shaped tube with a substantially uniform outer diameter across substantially an entire height of the nozzle, at least one retaining body opening located in an outer wall of the nozzle; a holding body including: a conduit, the conduit sized to fit the nozzle there-through, an alignment opening extending from an outer surface of the holding body to the conduit; and a retaining body sized to fit within the alignment opening of the holding body and to contact the retaining body opening of the nozzle when the nozzle is inserted in the conduit such that the cylindrically-shaped tube of the nozzle cannot rotate or move further in or out of the conduit. A method of assembling the wellbore downhole tool is also described.