Abstract: A tool health manager may receive surface contextual data of the downhole drilling system. A tool health manager may receive downhole contextual data of the downhole drilling system, the downhole contextual data including downhole operating data for a downhole tool. A tool health manager may synchronize the downhole contextual data with the surface contextual data to generate synchronized data. A tool health manager may prepare a historical comparison between historical data and the synchronized data. A tool health manager may, based on the historical comparison, generate a tool health status of the downhole tool.

Abstract: A method for evaluating a subterranean wellbore includes rotating a drill string in the subterranean wellbore. The drill string includes a rotary steerable tool, a steerable drill bit, or other rotary steering tool with at least one pad configured to extend radially outward from a tool body and engage a wall of the wellbore. Radial displacements of the pad are measured while rotating and processed to compute a curvature of the wellbore.

Abstract: A tool health manager may receive surface contextual data of the downhole drilling system. A tool health manager may receive downhole contextual data of the downhole drilling system, the downhole contextual data including downhole operating data for a downhole tool. A tool health manager may synchronize the downhole contextual data with the surface contextual data to generate synchronized data. A tool health manager may prepare a historical comparison between historical data and the synchronized data. A tool health manager may, based on the historical comparison, generate a tool health status of the downhole tool.

Abstract: A method for evaluating a subterranean wellbore includes rotating a drill string in the subterranean wellbore. The drill string includes a rotary steerable tool, a steerable drill bit, or other rotary steering tool with at least one pad configured to extend radially outward from a tool body and engage a wall of the wellbore. Radial displacements of the pad are measured while rotating and processed to compute a curvature of the wellbore.

Abstract: A wear resistant part includes a first material including a structure having a surface feature. The first material is capable of maintaining its structure at a temperature from about 1000° C. to about 1500° C. (e.g., upon exposure to the temperature or upon being heated to reach the temperature). The wear resistant part also includes a second material formed into a shape extending partially around the structure of the first material while exposing the surface feature of the first material. The shape of the second material is formed by a matrix infiltration at a temperature from about 1000° C. to about 1500° C.

Abstract: A wear resistant part includes a first material including a structure having a surface feature. The first material is capable of maintaining its structure at a temperature from about 1000° C. to about 1500° C. (e.g., upon exposure to the temperature or upon being heated to reach the temperature). The wear resistant part also includes a second material formed into a shape extending partially around the structure of the first material while exposing the surface feature of the first material. The shape of the second material is formed by a matrix infiltration at a temperature from about 1000° C. to about 1500° C.

Abstract: A fluidic modulator in accordance to an aspect includes a body forming a flow aperture between an inlet and an outlet, the flow aperture providing a constriction to a fluid flowing axially from the inlet to the outlet, and a moveable element having a shaft portion disposed through the body and a tip end selectively positionable in the flow aperture to alter the flow aperture.

Abstract: A fluidic modulator having a body forming a flow aperture between an inlet and an outlet, the flow aperture having a nominal diameter less than the inlet diameter and the outlet diameter whereby the flow aperture provides a constriction to a fluid flowing axially from the inlet to the outlet, and a moveable portion operable to alter the flow aperture. To create a modulated pressure pulse the moveable portion may be for example radially shifted in the flow aperture, rotated in the flow aperture, or the rotation of the moveable portion in the flow aperture may be controlled.

Abstract: A well system includes a first fluidic modulator (FM) located at the bottom of the tubular string and a repeater fluidic modulator (FM) located in the tubular string between the first FM and the surface, the repeater FM including a body forming a flow aperture between an inlet and an outlet, the flow aperture providing a constriction to a fluid flowing axially through the tubular string, and a moveable portion operable to alter the flow aperture. To create a modulated pressure pulse the moveable portion may be for example radially shifted in the flow aperture, rotated in the flow aperture, or the rotation of the moveable portion in the flow aperture may be controlled.

Abstract: A fluidic modulator in accordance to an aspect includes a body forming a flow aperture between an inlet and an outlet, the flow aperture providing a constriction to a fluid flowing axially from the inlet to the outlet, and a moveable element having a shaft portion disposed through the body and a tip end selectively positionable in the flow aperture to alter the flow aperture.