A single use setting tool and associated method for actuating a tool in a wellbore may include an inner piston having a piston proximal end, a piston distal end, and a piston annular wall that defines a piston cavity. The setting tool may include a gas-generating power charge positioned within the piston cavity. The power charge may extend along a longitudinal axis from a proximal end to a distal end and have at least two different widths along its length. The power charge may further include a tapered portion. The setting tool may further include a piston extension connected to the piston distal end. The inner piston may further include a shear element groove circumferentially extending in an outer surface of the inner piston, for receiving a shear element.

A system used downhole in tubing is operable with pressure communicated via at least one control line. The system includes a tool and a stinger. The tool disposed with the tubing has a tool bore for passage of tubing flow. The tool has an operator movable between operable states, and the operator has a tool key disposed in the bore. The stinger removably disposed in the tubing is configured to insert into the tool bore. The stinger has an actuator in communication with the at least one control line. Actuated by the control line, a stinger key disposed on the stinger is movable with the actuator between positions. In this way, the stinger key is configured to engage the tool key and is configured to move the tool's operator at least from the one state to another.

A liner hanger running system including a liner hanger having a body including a wall defined by an outer surface and an inner surface. The body includes an opening that extends through the outer surface and the inner surface. A piston housing including a wall portion defined by an outer surface portion and an inner surface portion is spaced from the outer surface of the body to define a piston Chamber exposed to the opening. A piston is arranged in the piston chamber. A liner hanger running tool including a dog key extends into the opening and engages the piston. The dog key is selectively shiftable relative to the liner hanger to release the piston and expose the opening to a setting pressure.

A single-use pressure-controlled actuator for downhole well tools or mechanisms is provided. The actuator is configured for control of activation/deactivation by agency of wellbore fluid pressure (e.g., pressure levels of drilling fluid or drilling mud in the wellbore). The actuator is further configured for hydraulic actuation by agency of the wellbore fluid. The actuator comprises a plunger displaceably mounted on a sealed cylinder body, with a non-reclosable frangible device closing off wellbore fluid access to an interior of the cylinder body. The frangible device is configured for automatic in response to exposure of wellbore fluid pressures exceeding a predetermined activation threshold. Failure of the frangible device causes exposure of the plunger to the wellbore fluid, resulting in actuated movement of the plunger by hydraulic action of the wellbore fluid.

A method and apparatus are disclosed that use a control line to expand a piston that shears pins to disconnect a latching system for wellbore operations.

A downhole tool position adjustment assembly for locating a tool downhole comprising a mandrel coupled to a housing via an extend-retract mechanism. A controller communicatively connected to the extend-retract mechanism, wherein an application executing within the controller, is configured to control the extend-retract mechanism. A communication system, communicatively coupled to the controller, is configured to receive a command signal from an operator at a surface location. The extend-retract mechanism moves the mandrel relative to the housing in response to a control signal received from the controller in response to the command signal received by the communication system.

A setting tool assembly configured to couple with a part of a workstring, the assembly having an inner housing coupled with one or more other components. A trigger device is coupled with a movable piston. During run-in, the piston is in a first position. Upon activation, the trigger device undergoes an altering event whereby the piston moves to a second position as a result of a pressure acting thereon.

A gas operated setting tool comprising a piston rod and an outer tool assembly having a hollow interior within which the piston rod is disposed coaxially. The outer tool assembly comprises a top cap connected to the cylinder's upper end and a bottom connector connected to the cylinder's lower end. The piston rod comprises an upper section to which a firing head attaches and a lower section to which a setting adapter attaches. The piston section's exterior surface fits within and is sealed against the cylinder's interior surface. The piston rod has a hollow power charge chamber and port holes that open into the bottom connector's upper surface. A shear ring engages a counterpart surface feature to prevents axial movement of the outer tool assembly relative to the piston rod until the power charge has fired and sheared the shear ring.

A mill including a housing having a fluid bypass pathway, a milling feature at a longitudinal end of the housing, a chamber defined by the housing, and a piston disposed in communication with the chamber, the piston defining a fluid passageway initially aligned with the fluid bypass pathway, the piston responsive to pump pressure to move toward the milling feature, the movement misaligning the fluid passageway with the fluid bypass pathway.

A liner string for a wellbore includes a liner hanger assembly (LHA) and a liner hanger deployment assembly (LHDA) releasably attached to the LHA. The LHDA includes a central bore and a running tool moveable from a locked position to an unlocked position, the running tool including a flow path in communication with the central bore. The liner string further includes a chamber disposed between the LHDA and LHA, wherein the chamber is in selective fluid communication with the flow path. Wherein, when the flow path is closed, the chamber is isolated from the central bore, and when the flow path is open, the flow path provides fluid communication between central bore and chamber.