A linear electrical contact slip structure for conducting electricity between two regions of a tool string while deployed within a wellbore. The linear electrical contact slip maintains an electrical connection between a piston structure and a collar structure, where either structure can be a stroker section or a stator section, and where the electrical connection is maintained when the stoker section is either stationary or in motion. The electrical connections between the piston and collar are grouped along the interior hollow surface of the collar, corresponding to contacts on the exterior of the piston head. The piston and collar are configured to prevent relative rotational motion, but to allow relative linear motion, by use of projections from the piston that match grooves in the collar.

A tubular member for a drill pipe comprising an elongated tubular body with a first end and a second end, the first and second ends including, respectively, a box tool joint section and a pin tool joint segment, the box tool joint segment being connected to the tubular body with at least a weld neck, wherein the nominal outer diameter of the tubular member is greater than the nominal pipe body outer diameter specified under American Petroleum Institute standard API Specification 5DP for a basis tubular member, and the nominal outer diameter of the tubular member is equal to or less than the weld neck diameter limitation specified under API Specification 5DP for a basis tubular member.

A poppet valve having an elongated tubular housing and an internal bore. A flange extends within the internal bore supporting an interior tubular member. The interior tubular member itself has a central aperture and an inwardly protruding lip extending into the central aperture. A stem having collet fingers may be partially received in the central aperture of the interior tubular member. The collet fingers have a protrusion which is engagable with the inwardly protruding lip. A biasing element is provided biasing the stem toward a first position. An elastomeric seal may be disposed around the stem. When the stem is in a first position the elastomeric seal forms a fluid tight seal preventing fluid flow through the internal bore, and wherein upon application of a predetermined fluid pressure the stem transitions from the first position to a second position, whereby fluid flow is permitted through the internal bore.

A tubular string for a subterranean well comprises a first string that is located in the well and that can access or traverse horizons of interest, such as during drilling, completion, or workover. A second tubular string is assembled above this first tubular string and is selected so that only this second tubular string normally traverses a blow out preventer during periods when there is an elevated risk that the blow out preventer will be actuated. The second tubular string is made of a more easily shearable material than the first tubular string, such as a titanium alloy, an aluminum alloy, or a composite material. A third or further tubular strings may be assembled above the second tubular string, such as in subsea applications.

A tubular string for a subterranean well comprises a first string that is located in the well and that can access or traverse horizons of interest, such as during drilling, completion, or workover. A second tubular string is assembled above this first tubular string and is selected so that only this second tubular string normally traverses a blow out preventer during periods when there is an elevated risk that the blow out preventer will be actuated. The second tubular string is made of a more easily shearable material than the first tubular string, such as a titanium alloy, an aluminum alloy, or a composite material. A third or further tubular strings may be assembled above the second tubular string, such as in subsea applications.

Methods and apparatus identify downhole equipment and correlate input data with the equipment to improve planning and/or inventory operations. For some embodiments, oilfield equipment or tubular goods such as drill pipe include a shaped recess along an outer circumference for receiving a tag cartridge by shrink fitting. Once tagged, detector system configurations at pipe yards may facilitate logging the presence and location of each drill pipe and correlating specific data, such as inspection data, to each drill pipe. Further, this correlation populates a database utilized to achieve other business functions such as forecasting number of additional drill pipe needed to purchase, invoicing customers according to actual tracked wear/use of the drill pipe being returned, and providing well or job specific drill string population using known history pipe joints.

A coating having a gradient composite structure, applied to a substrate, which may be a disposable tool. The gradient composite comprises a bonding component and an erosion and/or corrosion resistant component. When applied to a disposable tool, such as a ball and seat assembly in a downhole environment, the coating enhances the performance of disintegrable materials used in such tools. The coating may be configured to expire at the end of a selected duration, allowing the underlying material to disintegrate.

A downhole system and method is disclosed for sealing an inflow control device installed in a subterranean formation along a length of production tubing adjacent a productive zone of the subterranean formation. The system includes a truss structure radially expandable between a contracted configuration and an expanded configuration and a sealing structure disposed radially external to the truss structure. The truss structure and the sealing structure are set in their expanded configurations so that the sealing structure is put into engagement with the inflow control device so as to restrict the flow of fluids from the subterranean formation into the production tubing at the location of the inflow control device.

A riser having a riser body having an interior surface, an exterior surface, and two spaced-apart ends, at least one identification assembly on the riser body, the identification assembly having an assembly body and a wave energizable apparatus in the body, the assembly body having an interior surface, an exterior surface, and a channel therethrough in which is positioned part of the riser body, the assembly body releasably secured on the riser body, and the wave energizable apparatus positioned within the assembly body. This abstract is provided to comply with the rules requiring an abstract which will allow a searcher or other reader to quickly ascertain the subject matter of the technical disclosure and is submitted with the understanding that it will not be used to interpret or limit the scope or meaning of the claims, 37 C.F.R. 1.72(b).

A flow management system includes an adjustable compactor configured for attachment to a wall surface of a conduit and being adjustable between an extended configuration and a reference configuration, an electric actuator in fluid communication with the adjustable compactor, and a control module. The control module is configured to control the electric actuator to flow a current to the adjustable compactor to generate an electric field that causes extension of the adjustable compactor for compacting a flow blockage within the conduit to create a channel adjacent the flow blockage and to terminate a flow of the current to remove the electric field at the adjustable compactor to cause the adjustable compactor to return to the reference configuration for opening the channel to a fluid flow within the conduit.