Abstract: Provided, in one aspect, is a downhole tool. The downhole tool, according to this aspect, may include a helically wound structure having first and second ends, as well as a first member coupled to the first end and a second member coupled to the second end. In accordance with this aspect, the first and second members are rotatable or linearly translatable with respect to each other to move the helically wound structure between a radially retracted state having at least one coils and a radially deployed state.

Abstract: A centralizing perforating gun for perforating a tubular in a wellbore include a gun housing, perforating charges positioned within the gun housing and detonatable to perforate the tubular, and a centralizing system. The centralizing system includes an extendable member configured to move between a retracted position and an extended position. The extendable member is configured to engage a surface of the tubular in the extended position, thereby biasing the centralizing perforating gun away from the surface of the tubular.

Abstract: A system includes a pipe string; a wireline cable run through the pipe string; and a downhole tool for formation testing, wherein the downhole tool comprises, an upper assembly, an impeller unit connected to a downhole end of the upper assembly, wherein the impeller unit comprises a first impeller coupled to a second impeller by a shaft, a first flowline having a first end that is open to the formation, a packer unit that isolates a portion of a borehole surrounding the first end of the first flowline from the rest of the borehole, and a tool string connected to the first flowline, wherein the tool string hydraulically connects the packing device to the upper assembly.

Abstract: A formation tester consists of an upper assembly, an impeller unit, a straddle packer unit, and an inverted reservoir description tool string. The upper assembly seals off the wireline cable at the rig and connects the wireline cable to the formation tester. The impeller unit includes an upper turbine which converts hydraulic power from circulation of drilling mud into mechanical power. The mechanical power is used to drive a lower impeller which is capable of pumping formation fluids at high flow rates. The straddle packer unit isolates a portion of the formation tester which is open to the borehole to allow entry and exit of formation fluids through the formation tester. The inverted reservoir description tool string contains a combination of formation description modules which are inverted from traditional reservoir description tool modules to allow fluid flow paths to bypass electrical components.

Abstract: Embodiments may take the form of a perforating gun of modular assembly. The perforating gun may include at least one centralizing member at an interface between a loading tube and a carrier. Among modular components, the gun may also include an initiator assembly module that is electrically coupled to a modular feedthrough with a connector. The insert and the centralizing member may enhance axial cohesiveness of the modular gun. A shock absorbing mount may be located within the carrier and may receiving the initiator assembly module to provide added axial cohesiveness to the modular gun.

Abstract: A centralizing perforating gun for perforating a tubular in a wellbore include a gun housing, perforating charges positioned within the gun housing and detonatable to perforate the tubular, and a centralizing system. The centralizing system includes an extendable member configured to move between a retracted position and an extended position. The extendable member is configured to engage a surface of the tubular in the extended position, thereby biasing the centralizing perforating gun away from the surface of the tubular.

Abstract: A centralizing perforating gun for perforating a tubular in a wellbore include a gun housing, perforating charges positioned within the gun housing and detonatable to perforate the tubular, and a centralizing system. The centralizing system includes an extendable member configured to move between a retracted position and an extended position. The extendable member is configured to engage a surface of the tubular in the extended position, thereby biasing the centralizing perforating gun away from the surface of the tubular.

Abstract: Systems and methods are provided for transmitting information to and from a downhole tool for detonation at a specified location. Perforating systems and methods may use a digital slickline unit and a telemetry module to autonomously operate within a wellbore. A well system may comprise: a downhole perforating system comprising: at least one perforating gun; a setting tool; and a control unit coupled to the at least one perforating gun and the setting tool in a tool string for conveyance downhole, wherein the control unit comprises a battery pack, electronics, at least one sensor, wherein the electronics are operable to send one or more actuation signals to the at least one perforating gun and the setting tool.

Abstract: A formation tester consists of an upper assembly, an impeller unit, a straddle packer unit, and an inverted reservoir description tool string. The upper assembly seals off the wireline cable at the rig and connects the wireline cable to the formation tester. The impeller unit includes an upper turbine which converts hydraulic power from circulation of drilling mud into mechanical power. The mechanical power is used to drive a lower impeller which is capable of pumping formation fluids at high flow rates. The straddle packer unit isolates a portion of the formation tester which is open to the borehole to allow entry and exit of formation fluids through the formation tester. The inverted reservoir description tool string contains a combination of formation description modules which are inverted from traditional reservoir description tool modules to allow fluid flow paths to bypass electrical components.

Abstract: This disclosure relates generally to downhole tools and, more particularly, embodiments related to incorporation of a pumpdown relief valve into a downhole tool that is responsive to changes in differential fluid pressure along a downhole tool. Disclosed is a system for pumpdown regulation in a wellbore. The system may include a downhole tool having a tool body with a tool head that is attachable to a line, the line being attached to a point at a surface of the wellbore. The system may further include a pumpdown relief valve coupled to the tool body that is operable to allow fluid to bypass the downhole tool in direct response to a differential fluid pressure across a length of the downhole tool.

Abstract: A centralizing perforating gun for perforating a tubular in a wellbore include a gun housing, perforating charges positioned within the gun housing and detonatable to perforate the tubular, and a centralizing system. The centralizing system includes an extendable member configured to move between a retracted position and an extended position. The extendable member is configured to engage a surface of the tubular in the extended position, thereby biasing the centralizing perforating gun away from the surface of the tubular.

Abstract: Provided, in one aspect, is a downhole tool. The downhole tool, according to this aspect, may include a helically wound structure having first and second ends, as well as a first member coupled to the first end and a second member coupled to the second end. In accordance with this aspect, the first and second members are rotatable or linearly translatable with respect to each other to move the helically wound structure between a radially retracted state having at least one coils and a radially deployed state.

Abstract: A caliper tool for measuring a shape of a wellbore may include a sensor assembly and a movable measurement component including a hub and a measurement arm extending from the hub, and a magnetically-permeable target coupled to the hub and configured to rotate with the hub upon movement of the measurement arm. A sensor assembly includes primary coil and one or more secondary coils spaced apart from the primary coil, wherein output signals from the secondary coils facilitates measurement of the shape of the wellbore.

Abstract: A technique employs the use of oscillations downhole to facilitate a desired functionality of a downhole tool. According to this technique, a tool is initially conveyed downhole and operated to perform a function that relates to a downhole application. The operational efficiency of the tool is improved by creating oscillating forces which vibrate the tool to achieve a desired result, e.g. freeing the tool from a stuck position.

Abstract: This disclosure relates generally to downhole tools and, more particularly, embodiments related to incorporation of a pumpdown relief valve into a downhole tool that is responsive to changes in differential fluid pressure along a downhole tool. Disclosed is a system for pumpdown regulation in a wellbore. The system may include a downhole tool having a tool body with a tool head that is attachable to a line, the line being attached to a point at a surface of the wellbore. The system may further include a pumpdown relief valve coupled to the tool body that is operable to allow fluid to bypass the downhole tool in direct response to a differential fluid pressure across a length of the downhole tool.

Abstract: Apparatus and method of sensing tension downhole, such as a tension sensing tool for coupling between opposing first and second portions of a tool string conveyable within a wellbore. The tension sensing tool may include a tension-bearing member, a load cell connected along the tension-bearing member and operable to generate information indicative of tension applied to the tension sensing tool, and electronic equipment communicatively connected with the load cell. The electronic equipment may be operable to record the information generated by the load cell and/or transmit the information generated by the load cell to a wellsite surface from which the wellbore extends.

Abstract: Systems and methods are provided for transmitting information to and from a downhole tool for detonation at a specified location. Perforating systems and methods may use a digital slickline unit and a telemetry module to autonomously operate within a wellbore. A well system may comprise: a downhole perforating system comprising: at least one perforating gun; a setting tool; and a control unit coupled to the at least one perforating gun and the setting tool in a tool string for conveyance downhole, wherein the control unit comprises a battery pack, electronics, at least one sensor, wherein the electronics are operable to send one or more actuation signals to the at least one perforating gun and the setting tool.

Abstract: Apparatus and method of sensing tension downhole, such as a measurement tool for coupling between opposing first and second portions of a tool string conveyable within a wellbore. The measurement tool may include a tension-bearing member, a load cell connected along the tension-bearing member and operable to generate information indicative of tension applied to the measurement tool, and electronic equipment communicatively connected with the load cell. The electronic equipment may be operable to record the information generated by the load cell and/or transmit the information generated by the load cell to a wellsite surface from which the wellbore extends.

Abstract: A caliper tool for measuring a shape of a wellbore may include a sensor assembly and a movable measurement component including a hub and a measurement arm extending from the hub, and a magnetically-permeable target coupled to the hub and configured to rotate with the hub upon movement of the measurement arm. A sensor assembly includes primary coil and one or more secondary coils spaced apart from the primary coil, wherein output signals from the secondary coils facilitates measurement of the shape of the wellbore.

Abstract: An apparatus having a tension sensing tool for coupling between opposing portions of a downhole tool string. The tension sensing tool includes a load cell (206) connected along a tension-bearing member (234) of the tension sensing tool and operable to generate information indicative of tension applied to the tension sensing tool. The tension sensing tool further comprises a processing device (204) operable to receive the information indicative of the tension and output the information indicative of the tension to a wellsite surface. The apparatus further comprises a perforating tool for coupling within the tool string and operable to perforate at least a portion of a subterranean formation surrounding a wellbore.