A drilling tool for use in a wellbore comprises a first collar having a first bore extending from a first send to a second end and an internal thread disposed on the bore at the second end. The drilling tool also comprises a second collar having a second bore extending from a third end to a fourth end and an external thread disposed on the third end. The third end is coupled to the second end of the first collar. A first set of components is housed within the first bore and a second set of components is housed on a sidewall of the second collar formed between the second bore and an outer surface of the second collar.

Aspects of the subject technology relate to a sensor for a downhole tool. The downhole tool can include a collar and a sensor. The sensor can be secured to the collar for measuring one or more operational characteristics of the downhole tool during operation of the downhole tool. The sensor can include a substrate. The sensor can also include a plurality of strain gauges disposed on the substrate. The plurality of strain gauges can be configured to measure axial strains and torsional strains on the collar for measuring the one or more operational characteristics of the downhole tool.

Aspects of the subject technology relate to a sensor for a downhole tool. The downhole tool can include a collar and a sensor. The sensor can be secured to the collar for measuring one or more operational characteristics of the downhole tool during operation of the downhole tool. The sensor can include a substrate. The sensor can also include a plurality of strain gauges disposed on the substrate. The plurality of strain gauges can be configured to measure axial strains and torsional strains on the collar for measuring the one or more operational characteristics of the downhole tool.

Some embodiments disclosed herein are directed to a tubular member including a central axis, a first end, a second end opposite the first end, an upset region between and axially spaced from the first end and the second end, and a first outer diameter axially spaced midway between the first end and the upset region. The upset region includes a second diameter which is larger than the first diameter, does not include a weld joint, and includes redistributed material from the tubular member.

A downhole tool body includes an outer surface having at least one O-ring gland. The at least one O-ring gland includes a first contour having a first radius greater than about 0.035″ (R0.89 mm) and a second contour having a second radius greater than about 0.035″ (R0.89 mm). A backup ring is arranged in the O-ring gland. The backup ring includes a gland contour having a radius that is complimentary to the first radius.

An apparatus for reducing torque in a drill string includes a clamp assembly having a first clamp segment and a second clamp segment, the first and second clamp segments each including two circumferential ends, the two circumferential ends of the first clamp segment being configured to be connected to the two circumferential ends of the second clamp segment so as to secure the clamp assembly around an oilfield tubular and prevent the clamp assembly from rotating relative to the oilfield tubular. An outer diameter surface of each of the first and second clamp segments is generally continuous in an axial direction. The apparatus also includes an outer sleeve positioned around the clamp assembly, wherein the clamp assembly is configured to rotate with the oilfield tubular and with respect to the outer sleeve.

An apparatus for reducing torque in a drill string includes a clamp assembly having a first clamp segment and a second clamp segment, the first and second clamp segments each including two circumferential ends, the two circumferential ends of the first clamp segment being configured to be connected to the two circumferential ends of the second clamp segment so as to secure the clamp assembly around an oilfield tubular and prevent the clamp assembly from rotating relative to the oilfield tubular. An outer diameter surface of each of the first and second clamp segments is generally continuous in an axial direction. The apparatus also includes an outer sleeve positioned around the clamp assembly, wherein the clamp assembly is configured to rotate with the oilfield tubular and with respect to the outer sleeve.

A system for manufacturing a tubular member includes a mandrel configured to be inserted within a throughbore of the tubular member to engage with an inner diameter of the throughbore. In addition, the system includes a die assembly comprising a cavity. The die assembly is configured to be disposed about an outer surface of the tubular member such that a central portion of the tubular member is aligned with the cavity. Further, the system includes a ram configured to apply a load to the tubular member along a central axis of the tubular member to expand the central portion of the outer surface of the tubular member into the cavity to form an upset region along the tubular member.

Systems and methods of the present disclosure relate to dampening downhole vibrations with an electroactive polymer (EAP). A downhole tool comprises a collar; an electronic control unit (ECU); a vibration sensor in communication with the ECU; a voltage source in communication with the ECU; and the EAP disposed along portions of the collar, the EAP in communication with the ECU, wherein the ECU is configured to apply voltage to the EAP based on signals received from the vibration sensor.

Systems and methods of the present disclosure relate to dampening downhole vibrations with an electroactive polymer (EAP). A downhole tool comprises a collar; an electronic control unit (ECU); a vibration sensor in communication with the ECU; a voltage source in communication with the ECU; and the EAP disposed along portions of the collar, the EAP in communication with the ECU, wherein the ECU is configured to apply voltage to the EAP based on signals received from the vibration sensor.