A stage tool comprises a body with a tubular wall, defining an outer surface and an inner surface. Fluid ports, such as cement circulation ports, extend through the tubular wall. The stage tool further comprises a primary closing sleeve. The primary closing sleeve may be movable along the outer surface of the tubular wall for closing the ports when the treatment of the wellbore stage ends. A secondary closing sleeve may be movable along the inner surface of the tubular wall for closing the port in case of failure of the primary closing sleeve or for redundancy. The primary closing sleeve may be actuated by an internal member joined to the primary closing sleeve by a crosslink and movable on the inner surface. The internal member and the secondary closing sleeve may move along different surfaces on the internal wall to avoid interference.

A degradable seat arrangement consisting of a pusher; a cone having a tapered face; and a seal having a seal deformation face configured to contact the tapered face. A method for creating a seat in a borehole.

A dissolvable untethered object for use inside a well fluid includes an internal cavity and a fluid entry point. The internal cavity contains a gas. The fluid entry point is closed and selectively openable so that the internal cavity can be filled with the well fluid flowing through the fluid entry point. A dissolving rate of the dissolvable untethered object is modified after contact of the well fluid inside the internal cavity with the dissolvable untethered object.

Downhole completion system (100) arranged in a borehole, comprising a production casing (2) having an axial extension with an opening (4) for providing fluid communication between the borehole and the inside of the casing, a sleeve (5) arranged at least partly movably along or rotatably around the axial extension for opening, choking or closing the fluid communication and a sleeve control (7) for moving the sleeve (5) to open, choke or close the opening (4), wherein the sleeve control comprises a first part having at least one member (9) engaging the profile, a second part having a fixation unit (11) fixating the sleeve control in the casing, an actuator (12) for moving the first part in relation to the second part, a power supply (14), such as a battery, supplying power to the actuator (12), and a first communication module (15) for receiving control signals from surface.

Embodiments disclosed herein describe fracturing methods and systems, wherein pressure differentials and fluid flow rates may be utilized to stimulate multiple zones, sleeves, or ports with the same tool.

A packer for use in a wellbore includes a packer mandrel. First and second pistons are slidably disposed about the packer mandrel defining first and second chambers therewith. A first activation assembly initially prevents movement of the first piston. A second activation assembly initially prevents movement of the second piston. A seal assembly is disposed about the packer mandrel between the first and second pistons such that actuation of the first activation assembly allows a force generated by a pressure difference between the wellbore and the first chamber to shift the first piston in a first direction toward the seal assembly to radially expand the seal assembly and actuation of the second activation assembly allows a force generated by a pressure difference between the wellbore and the second chamber to shift the second piston in a second direction toward the seal assembly to radially expand the seal assembly.

A multi-zone well test system, that can flow test multiple zones within a subterranean formation and without the use of a rig. The system includes an inflow control tool that is ball actuated, a top diverter sub, a zonal isolation packer, a bottom diverter sub, and a dual-conduit tubing system. An advantage of the test system is that the subs and packers can be individually actuated without a surface operated control system.

A shear tester for in-situ determination of rock formation geomechanical properties is provided. The tester has a radially expandable cylindrical membrane, a metal sheath covering at least a portion of the outer surface of the membrane, at least one stud fixed on the sheath, at least one cone fixed on each of the at least one stud, and a piston operable to apply an upward axial force on the metal sheath. A device for the same use comprises the shear tester and a pressuremeter. A method of using the shear tester comprises applying a normal force to the formation by expanding the membrane until at least one of the at least one cone penetrates the rock formation and applying an upward axial force to the at least one of the at least one cone by operating the piston until at least a portion of the rock formation shears.

An electric submersible pumping system for use in pumping fluids from a wellbore includes a motor, a pump driven by the motor, and a fluid expansion module connected to the motor. The fluid expansion module includes a piston seal housing and a piston assembly contained within the piston seal housing. The piston assembly includes a piston body having an exterior surface, a plurality of seals connected to the exterior surface of the piston body and a pressure equalization system. The pressure equalization system reduces a pressure differential between fluid in an annular space between the plurality of seals and fluid surrounding the first piston assembly.

A zonal isolation device conveyed into the wellbore with a propped flapper valve. The zonal isolation device comprises a deformable sealing element and a support ring movably disposed within the inner bore of the sealing element. A flapper valve coupled to the support ring is configured to engage a sealing surface of support ring. The flapper valve blocks fluid flow through the zonal isolation device in a fully closed position, allows unrestricted fluid flow through the zonal isolation device in a fully open position, and allows restricted fluid flow through the zonal isolation device when held by a propping component in an intermediate or partially open position. The zonal isolation device is anchored to the wellbore by an anchoring assembly engaged with a wedge coupled to the downhole end of the sealing element.