An actuator of a downhole tool used in oil and gas exploration and production operations is operable to actuate a first implement in a first direction. A biasing device of the downhole tool is operable to actuate the first implement in a second direction, opposite the first direction. A dampener of the downhole tool is operable to slow an actuation speed of the first implement in the first direction, the second direction, or both. Actuating the first implement in the first direction also actuates a second implement of a flow control device (“FCD”) of the downhole tool, to which the first implement is connected, in the first direction, placing the FCD in a first (e.g., open) configuration. Actuating the first implement in the second direction also actuates the second implement of the FCD in the second direction, placing the FCD in a second (e.g., closed) configuration.

A safety valve includes a housing having a bore, a flow tube, and a valve closure member. The flow tube resides in the bore, is configured to move telescopically within the bore, and is adapted to shift the valve closure member between a closed position and an open position. The safety valve also includes an annular section between an inner surface of the housing and an outer surface of the flow tube, and means for preventing fluid flowing through the bore from entering the annular section.

A drill pipe string conveyed retrievable plug system has a central through bore. The plug system includes a drill pipe string; a control section; a running tool with a connector at a lower end of a drill pipe string with the control section, and a top connector on a mechanical plug section with a bridge plug. The mechanical plug section includes a mandrel with the through bore, a ball valve arranged for closing the through bore, and a packer sleeve on the mandrel with slips and a packer element. The control section includes an electric supply, an electric control unit, and sensors connected to the electric control unit. The mechanical plug section includes a motor controlled by the electrical control unit. The motor is arranged to turn a selector ring to a selected first rotational position so as for allowing a piston sleeve to slide to an axial first stop position in order for opening to fluid channels through the mandrel from the through bore to the packer sleeve. The pressure in the through bore can be set to the pressure of the packer sleeve in a surrounding casing.

A rupture disc assembly and a float tool incorporating the rupture disc assembly is disclosed. The rupture disc assembly may include a rupture disc assembly comprising a rupture disc, an upper tubular portion and a lower tubular portion, and a securing mechanism for holding the rupture disc between the upper and lower tubular portions. A float tool for creating a buoyant chamber in a casing string may include the rupture disc assembly and a sealing device for sealing the lower end of the casing string, the buoyant, sealed chamber may be created there between. In operation, applied fluid pressure causes the rupture disc to move downward. The rupture disc may be shattered by contact with a surface on the lower tubular portion. Full casing internal diameter may be restored in the region where the rupture disc formerly sealed the casing.

Valve assemblies for reciprocating downhole pumps are provided. The valve assembly may comprise: a flow cage comprising a housing and a tubular insert; an annular valve seat positioned below the tubular insert; and an elongated sealing member positioned above the annular valve seat and at least partially received into the tubular insert. In some embodiments, the elongated sealing member may be more stable and may more securely engage the valve seat compared to spherical valve balls. Related methods are also provided.

Valve assemblies for reciprocating downhole pumps are provided. The valve assembly may comprise: a flow cage comprising a housing and a tubular insert; an annular valve seat positioned below the tubular insert; and an elongated sealing member positioned above the annular valve seat and at least partially received into the tubular insert. In some embodiments, the elongated sealing member may be more stable and may more securely engage the valve seat compared to spherical valve balls. Related methods are also provided.

Provided, in one aspect, is a downhole torque limiter, comprising a tubular housing; a pipe positioned within the tubular housing, the pipe transitioning from a larger inside diameter (ID.sub.L) to a smaller inside diameter (ID.sub.S), thereby forming a venturi profile having a first pressure zone (Z.sub.1) and a second pressure zone (Z.sub.2); a tubular valve plate radially positioned between the tubular housing and the pipe and rotationally fixed with the pipe; a lower sub rotationally fixed relative to the tubular housing and rotationally coupled to the tubular valve plate via a clutch mechanism; and a valve assembly positioned within a longitudinal opening extending along at least a portion of a sidewall of the tubular valve plate, the valve assembly configured to be activated by a pressure drop created by fluid flowing through the venturi profile.

A system includes a compression spring having a latch sleeve, a piston rod including a groove section, and a ratchet assembly that progressively moves the piston rod in a downward direction. A latch collet on the latch sleeve sits on the groove section of the piston rod in a first position of the system. The latch collet locks a spring force of the compression spring as the ratchet assembly progressively moves the piston rod in the downward direction. The latch collet becomes unsupported from the groove section when the piston rod has progressively moved a predetermined distance, causing the compression spring to release and provide a push force that actuates a hydraulic valve from the first position to a second position.

An aggregate MRC well includes a plurality of maximum reservoir contact (MRC) wells, a plurality of independently operated flow control or completion units installed in each of the plurality of MRC wells, a plurality of pressure regimes corresponding to the plurality of MRC wells, and a single production string connecting each of the plurality of MRC wells. The method includes providing a plurality of maximum reservoir contact (MRC) wells forming an aggregate MRC well, providing a plurality of independently operated flow control valves in each of the plurality of MRC wells, providing a plurality of pressure regimes corresponding to the plurality of MRC wells, and providing a single production string connecting each of the plurality of MRC wells.

Methods for determining phase fractions of a downhole fluid via thermal properties of the fluids are provided. In one embodiment, a method includes measuring a temperature of a fluid flowing through a completion string downhole in a well and heating a resistive element of a thermal detector at a position along the completion string downhole in the well by applying power to the resistive element such that heat from the resistive element is transmitted to the fluid flowing by the position. The method also includes determining, via the thermal detector, a flow velocity of the fluid through the completion string and multiple thermal properties of the fluid, and using the determined flow velocity and the multiple thermal properties to determine phase fractions of the fluid. Additional systems, devices, and methods are also disclosed.