Logging downhole exposes components of logging tools, for example, antennas to abrasive and erosive operating conditions. A protective sleeve may disposed about an antenna assembly to protect the antenna assembly for the downhole operating conditions. To permit transmission and receipt of signals by and too the antenna assembly, slots are formed or disposed in the protective sleeve. A non-conductive composite insert is formed in the slots to protect the internal components of the protective sleeve, for example, the antenna assembly, from the operation conditions. A non-conductive composite inner liner is formed in an annulus of the protective sleeve and adheres to the protective sleeve and the non-conductive composite insert. The non-conductive component insert and inner liner allow signals to be transmitted and received by the antenna assembly so that logging operations can be completed without undue delay and the expense of repairing or replacing worn or damaged components.

The disclosure relates to a carriage apparatus for carrying a tool string down a wellbore in a wireline logging, and an orientation apparatus and hole finder device for a wireline logging tool string. In some embodiments the carriage includes a protection structure which extends longitudinally around a wheel of the apparatus to thereby prevent a side of the wheel from contacting a wall of the wellbore. In some embodiments an orientation apparatus and hole finder are arranged so that the orientation apparatus orientates the hole finder device in the wellbore so that a tip of a nose section of the hole finder is elevated above a low side of the wellbore by a height and offset from and above a longitudinal axis of the tool string.

A lateral isolator (200) has a tubular body with an upstream end and a downstream end. The lateral isolator (200) also includes an inner member (210) having a pivot ring (220) disposed within the tubular body. A first elastomeric package (236) is disposed between the tubular body and the inner member (210) longitudinally between the pivot ring (220) and the upstream end. A second elastomeric package (236) is disposed between the tubular body and the inner member (210) longitudinally between the pivot ring (220) and the downstream end.

An elastomer sleeve is applied to a wellbore tubular. The elastomer sleeve, which defines a circumference around longitudinal bore in a longitudinal direction, is brought in an elastically stretched condition by applying a stretching force to the elastomer sleeve. While the elastomer sleeve is kept in the elastically stretched condition, it is moved in the longitudinal direction over the wellbore tubular to a selected position on the wellbore tubular whereby the wellbore tubular extends through the bore. The elastomer sleeve is then snuggly fitted to an outside surface of the wellbore tubular by relaxing the elastically stretching force. The thus prepared wellbore tubular may be lowered into a wellbore in the Earth, and cement may be pumped on the outside of the wellbore tubular to form a cement sheath which fully surrounds the elastomer sleeve.

The present disclosure generally relates to a method for making up a tubular joint. The method includes rotating a first tubular relative to a second tubular to engage the first and second tubulars while measuring a torque between the first and second tubulars, calculating a set point of a relative rotational speed between the first and second tubulars using the measured torque, and using the calculated set point with a closed-loop controller to control the relative rotational speed between the first and second tubulars.

A downhole apparatus (10; 10) for reducing rotational and linear friction between a downhole tool (100; 100) and/or a downhole tool string and the wall of a wellbore (B) includes an annular body portion (12; 12′) configured for location on a mandrel (102; 102′) of the downhole tool (102; 102′) and one or more rib portions (16; 16′) extending radially from the annular body portion (12; 12′), and configured to engage a wall of the wellbore (B), the annular body portion (12; 12′) and the one or more rib portions (16; 16′) are integrally formed. The annular body portion (12; 12′) is elastically reconfigurable between a first configuration in which the annular body portion (12; 12) defines a first inner diameter and a second configuration in which the annular body portion (12; 12′) defines a second inner diameter configuration, the second inner diameter being larger than the first inner diameter. The annular body portion (12; 12′) is elastically or plastically reconfigurable between the second configuration and a third configuration in which the annular body portion (12; 12) defines a third inner diameter, the third inner diameter being smaller than the second inner diameter.

A pipe connector. The connector includes a body with opposed connection portions for connecting two pipes. A protective portion extends along at least a portion of an inside surface intermediate the connection portions. The protective portion includes a protective material that is less abrasive to a rod string than the body. An inside diameter of the connector along at least a portion of the protective portion is equal to or narrower than an inside diameter at other portions of the connector for preferentially contacting the rod string with the protective material over other portions of the body. The connector may include an extended gripping portion for gripping with power tongs, and may further include a reinforced portion for increasing resistance of the pipe connector to deformation when threadedly connected with a tubing joint with the connector.

Logging downhole exposes components of logging tools, for example, antennas to abrasive and erosive operating conditions. A protective sleeve may disposed about an antenna assembly to protect the antenna assembly for the downhole operating conditions. To permit transmission and receipt of signals by and too the antenna assembly, slots are formed or disposed in the protective sleeve. A non-conductive composite insert is formed in the slots to protect the internal components of the protective sleeve, for example, the antenna assembly, from the operation conditions. A non-conductive composite inner liner is formed in an annulus of the protective sleeve and adheres to the protective sleeve and the non-conductive composite insert. The non-conductive component insert and inner liner allow signals to be transmitted and received by the antenna assembly so that logging operations can be completed without undue delay and the expense of repairing or replacing worn or damaged components.

A lateral isolator (200) has a tubular body with an upstream end and a downstream end. The lateral isolator (200) also includes an inner member (210) having a pivot ring (220) disposed within the tubular body. A first elastomeric package (236) is disposed between the tubular body and the inner member (210) longitudinally between the pivot ring (220) and the upstream end. A second elastomeric package (236) is disposed between the tubular body and the inner member (210) longitudinally between the pivot ring (220) and the downstream end.

A modified tubular, particularly a drill pipe (12) has a composite non-rotating drill pipe protector assembly (1) including first and second composite collars (2, 3) provided as cooperating parts positionable around the drill pipe (12) and bondable thereto using bonding agent, a non-rotating composite protector shell (4), provided as cooperating shell parts and an internal polymeric radial bearing (7) which fits within a recess (41) within the non-rotating composite protector shell (4) and has an internal surface (10) configured to provide a plurality of internal fluid flow channels (11). An external surface of the non-rotating composite protector shell (4) has blades (14), spaced apart by fluid flow by-pass channels (24). In use the rotation of the drill pipe facilitates fluid movement within the non-rotating composite protector shell by creating a pumping effect inducing ingress of fluid and through-flow within the internal polymeric radial bearing (7).