An interchangeable module configured to be used in an integrated perforating gun and setting tool system, the interchangeable module having a body having a chamber, a first electrical connection located at a first end of the chamber, and a second electrical connection located at a second end of the chamber. The first end is opposite to the second end. An addressable switch located inside the chamber, the addressable switch has a digital address. A connection unit located inside the chamber and configured to electrically connect the addressable switch to an initiating device. The interchangeable module is configured to be used (1) between a first gun cluster and a second gun cluster and (2) between a distal gun cluster and a setting tool, and the first and second electrical connections are electrically connected to the addressable switch.

A frac dart includes a body having an outer surface and an end including at least one opening. A cutter support is mounted at the end adjacent the at least one opening. A cutter is moveably mounted at the cutter support. A counter support is slideably mounted on the outer surface, and a counter is arranged between the counter support and the cutter support. The cutter is operable to sever a portion of the counter.

A method includes disposing an intervention service tool within a tubular. The intervention service tool includes an anchoring system, a shifting system, and a linear actuator system. The tubular includes a shifting profile geometry disposed within the tubular at a first location. The anchoring system, the shifting system, and/or the linear actuator system is actuated. Shifter system pressure, linear actuator system force/pressure, and displacement of the shifting system is measured. A known graph of the shifting profile geometry is compared to one or more of a measured pressure, a measured force, or a measured displacement. A position of a key disposed on the shifting system is determined relative to the shifting profile. The shifting profile geometry is engaged with the key based on the position of the key. The shifting profile geometry is positioned at a second location that is different from the first location.

A method includes disposing an intervention service tool within a tubular. The intervention service tool includes an anchoring system, a shifting system, and a linear actuator system. The tubular includes a shifting profile geometry disposed within the tubular at a first location. The anchoring system, the shifting system, and/or the linear actuator system is actuated. Shifter system pressure, linear actuator system force/pressure, and displacement of the shifting system is measured. A known graph of the shifting profile geometry is compared to one or more of a measured pressure, a measured force, or a measured displacement. A position of a key disposed on the shifting system is determined relative to the shifting profile. The shifting profile geometry is engaged with the key based on the position of the key. The shifting profile geometry is positioned at a second location that is different from the first location.

A mechanical service tool that may include one or more anchors, a cutter, a communication and control system, and one or more sensors, as well as methods for operating the mechanical service tool, are provided. The one or more anchors may extend radially from the mechanical service tool and the cutter may move relative to the mechanical service tool. The cutter may include a drilling bit. The communication and control system may obtain remote commands that control the cutter, the one or more anchors, or both. The one or more sensors may detect operational conditions of the mechanical service tool and may be operatively coupled to the communication and control system.

A method and apparatus for casing recovery for well abandonment. A string is run-in, the string including a hydraulic jack (18), an anchor (28), a casing spear (20), a downhole flow pulsing device (22) and a pressure drop sub (24). The casing spear grips an upper end of the length of casing to be pulled. The anchor is set in casing of a greater diameter above the length of cut casing. Fluid pumped through the string and through the pressure drop sub will increase fluid pressure at the hydraulic jack to a first fluid pressure (78). Fluid pumped through the downhole flow pulsing device will vary the fluid flow superimposing a cyclic pressure (82) on the first pressure (78), causing oscillation of an inner mandrel (30) of the hydraulic jack. The jack moves the oscillating inner mandrel upwards relative to the anchor to pull the length of casing.

A method and apparatus for casing recovery for well abandonment. A string is run-in, the string including a hydraulic jack (18), an anchor (28), a casing spear (20), a downhole flow pulsing device (22) and a pressure drop sub (24). The casing spear grips an upper end of the length of casing to be pulled. The anchor is set in casing of a greater diameter above the length of cut casing. Fluid pumped through the string and through the pressure drop sub will increase fluid pressure at the hydraulic jack to a first fluid pressure (78). Fluid pumped through the downhole flow pulsing device will vary the fluid flow superimposing a cyclic pressure (82) on the first pressure (78), causing oscillation of an inner mandrel (30) of the hydraulic jack. The jack moves the oscillating inner mandrel upwards relative to the anchor to pull the length of casing.

A method of dislodging a tubular string or well equipment connected to the tubular string can include connecting a dislodging tool in the tubular string, so that a flow passage of the dislodging tool extends through the tubular string, deploying a plug into the dislodging tool, applying a pressure differential across the plug, thereby displacing the plug through a seat of the dislodging tool, and dislodging the tubular string or the component in response to the displacing. A dislodging system can include a dislodging tool connected as part of a tubular string, the dislodging tool including a flow passage and a seat configured to sealingly engage a plug deployed into the tubular string, and at least one of a jarring force, load, impact, shock wave, elastic strain release and pressure pulse being generated in the tubular string in response to displacement of the plug through the seat.

An integrated logging instrument for coring and sampling includes a downhole main body and a ground system. The downhole main body is connected with the ground system through a long cable. The downhole main body includes a coring and sampling mechanism, a power mechanism and an energy storage mechanism. The coring and sampling mechanism includes a coring assembly for drilling cores and a pushing and setting assembly for downhole fixation. The power mechanism is arranged at an upper end of the coring and sampling mechanism, and includes a motor, a piston structure and a pump body. The piston structure and the pump body are respectively arranged at two output ends of the motor. The piston structure is arranged to provide suction power. The pump body is arranged to provide hydraulic power. The energy storage mechanism is arranged at a lower end of the coring and sampling mechanism.

Disclosed is a downhole tool and method of use. The tool has a sleeve assembly slideable within the tool body under the action of a hydraulic pressure differential. The sleeve assembly has a control collar portion and a first hydraulic reservoir is defined between a first end of the control collar portion and the body, and a second hydraulic reservoir is defined between a second end of the control collar portion and the body. A bleed conduit extending between the first and second hydraulic reservoirs and an electromechanical control valve across the bleed conduit is used to regulate fluid flow along the bleed conduit. The electromechanical control valve may communicate with sensors, by which control systems are transmitted to the control valve.