Abstract: Pad force is one of the major parameters in some drilling systems, such as a RSS, that affect steering decisions during drilling. The disclosure recognizes that the pad force can change during drilling due to, for example, unintentional leaking through a pad seal that has been damaged due to the wear and tear of drilling. With a decrease in the pad force, the steering capability of the drilling tool can be compromised. As such, the disclosure provides a method and system that determines pad force information in real time for controlling drilling. The pad force information can be determined based on sensor data, component data, and drilling data. An estimated pad force is one example of the pad force information that can be calculated and used to direct a drilling operation.

Abstract: The disclosure provides for a bottom hole assembly that comprises a housing and a caliper arm. The caliper arm is pivotally coupled to the housing at a hinge disposed within the housing, wherein the caliper arm is operable to rotate about the hinge between a first position within the housing and a second position external to the housing. The bottom hole assembly further comprises a linear actuator coupled to the caliper arm and operable to extend the caliper arm to the second position, wherein the caliper arm is biased to remain in the second position in contact with a borehole wall. The bottom hole assembly further comprises a sensor disposed within the housing and operable to monitor a position of the caliper arm.

Abstract: The disclosure provides for a bottom hole assembly that comprises a housing and a caliper arm. The caliper arm is pivotally coupled to the housing at a hinge disposed within the housing, wherein the caliper arm is operable to rotate about the hinge between a first position within the housing and a second position external to the housing. The bottom hole assembly further comprises a linear actuator coupled to the caliper arm and operable to extend the caliper arm to the second position, wherein the caliper arm is biased to remain in the second position in contact with a borehole wall. The bottom hole assembly further comprises a sensor disposed within the housing and operable to monitor a position of the caliper arm.

Abstract: Pad force is one of the major parameters in some drilling systems, such as a RSS, that affect steering decisions during drilling. The disclosure recognizes that the pad force can change during drilling due to, for example, unintentional leaking through a pad seal that has been damaged due to the wear and tear of drilling. With a decrease in the pad force, the steering capability of the drilling tool can be compromised. As such, the disclosure provides a method and system that determines pad force information in real time for controlling drilling. The pad force information can be determined based on sensor data, component data, and drilling data. An estimated pad force is one example of the pad force information that can be calculated and used to direct a drilling operation.

Abstract: A drilling system for drilling a wellbore using drilling fluid includes a drillstring, a drill bit coupled to the drillstring, and a mud motor coupled to the drillstring and operable to rotate the drill bit by rotating a driveshaft with a bore. The drilling system also includes a bearing assembly that includes a bypass fluid flowpath through the bearings for drilling fluid to divert from the bore. A choke assembly positioned in the bypass fluid flowpath restricts flow of the diverted drilling fluid such that some diverted drilling fluid flows into an annulus in the wellbore outside of the bearing assembly through an unsealed annulus port and some of diverted drilling fluid is recaptured through a return flowline. The drilling system also includes a rotary steerable system operable to push the drill bit in a desired direction using pads extendable with the drilling fluid.

Abstract: A drilling system for drilling a wellbore using drilling fluid includes a drillstring, a drill bit coupled to the drillstring, and a mud motor coupled to the drillstring and operable to rotate the drill bit by rotating a driveshaft with a bore. The drilling system also includes a bearing assembly that includes a bypass fluid flowpath through the bearings for drilling fluid to divert from the bore. A choke assembly positioned in the bypass fluid flowpath restricts flow of the diverted drilling fluid such that some diverted drilling fluid flows into an annulus in the wellbore outside of the bearing assembly through an unsealed annulus port and some of diverted drilling fluid is recaptured through a return flowline. The drilling system also includes a rotary steerable system operable to push the drill bit in a desired direction using pads extendable with the drilling fluid.

Abstract: A system for an adjustably flexible downhole tool includes first and second connector ends each configured to connect to adjacent downhole tools and a shaft extending between the first and second connector ends. The shaft is configured to bend in response to passing through curved portions of a wellbore. The adjustably flexible downhole tool also includes an outer sleeve disposed around at least a portion of the shaft and extending from the first connector end in a direction toward the second connector end and at least one adjustable member configured to move axially, with respect to the shaft, from a first position to a second position to increase bending stiffness and/or torsional stiffness of the adjustably flexible downhole tool. The at least one adjustable member at least partially restrains bending of the shaft in the second position.

Abstract: An example slip-ring interface may include a first section and a second section rotationally independent from the first section. At least one conductor path between the first section and the second section may be selectively associated with and dedicated to the transmission of signals with a first signal type. At least one conductor path between the first section and the second section may be selectively associated with and dedicated to the transmission of signals with a second signal type. If error conditions occur, the signal types associated with one or more of the conductor paths may be changed so that signals of both the first and second signal types are transmitted across the interface.

Abstract: A mixing system for an exhaust system includes a first mixing device having a plurality of first auger blades and an inlet having a first cross-sectional area. A second mixing device is separate and downstream from the first mixing device and includes a second auger blade. The second mixing device includes an inlet having a second cross-sectional area greater than the first cross-sectional area. A flow path longitudinal centerline of the first mixing device extends at an angle to a flow path longitudinal centerline of the second mixing device. A flow path longitudinal centerline of the first mixing device intersects the second auger blade. The first mixing device is disposed within a first portion of an exhaust pipe and the second mixing device is disposed in a second portion of the exhaust pipe. The second portion has a larger cross-sectional area than the first portion.

Abstract: A mixing system for an exhaust system includes a first mixing device having a plurality of first auger blades and an inlet having a first cross-sectional area. A second mixing device is separate and downstream from the first mixing device and includes a second auger blade. The second mixing device includes an inlet having a second cross-sectional area greater than the first cross-sectional area. A flow path longitudinal centerline of the first mixing device extends at an angle to a flow path longitudinal centerline of the second mixing device. A flow path longitudinal centerline of the first mixing device intersects the second auger blade. The first mixing device is disposed within a first portion of an exhaust pipe and the second mixing device is disposed in a second portion of the exhaust pipe. The second portion has a larger cross-sectional area than the first portion.

Abstract: A mixing system for an exhaust aftertreatment system includes a first mixing device having a plurality of first auger blades and an inlet having a first cross-sectional area. A second mixing device is separate and downstream from the first mixing device and includes a second auger blade. The second mixing device includes an inlet having a second cross-sectional area greater than the first cross-sectional area. A plurality of flow paths created by the first mixing device are recombined into a single flow path between the first and second mixing devices. A longitudinal center line of the first mixing device is offset from a longitudinal center line of the second mixing device.

Abstract: A downhole assembly including a turbine to be disposed within a wellbore and a rotating array. The rotating array includes magnetic material and is coupled to the turbine. The downhole assembly also includes a magnetostrictive material coupled to the rotating array to strain the magnetostrictive material to induce an electric current in a conductor coupled to the magnetostrictive material.

Abstract: An example slip-ring interface may include a first section and a second section rotationally independent from the first section. At least one conductor path between the first section and the second section may be selectively associated with and dedicated to the transmission of signals with a first signal type. At least one conductor path between the first section and the second section may be selectively associated with and dedicated to the transmission of signals with a second signal type. If error conditions occur, the signal types associated with one or more of the conductor paths may be changed so that signals of both the first and second signal types are transmitted across the interface.

Abstract: A mixing system for an exhaust aftertreatment system includes a first mixing device having a plurality of first auger blades and an inlet having a first cross-sectional area. A second mixing device is separate and downstream from the first mixing device and includes a second auger blade. The second mixing device includes an inlet having a second cross-sectional area greater than the first cross-sectional area. A plurality of flow paths created by the first mixing device are recombined into a single flow path between the first and second mixing devices. A longitudinal center line of the first mixing device is offset from a longitudinal center line of the second mixing device.

Abstract: A downhole assembly including a turbine to be disposed within a wellbore and a rotating array. The rotating array includes magnetic material and is coupled to the turbine. The downhole assembly also includes a magnetostrictive material coupled to the rotating array to strain the magnetostrictive material to induce an electric current in a conductor coupled to the magnetostrictive material.

Abstract: A downhole assembly including a turbine to be disposed within a wellbore and a rotating array. The rotating array includes magnetic material and is coupled to the turbine. The downhole assembly also includes a magnetostrictive material coupled to the rotating array to strain the magnetostrictive material to induce an electric current in a conductor coupled to the magnetostrictive material.

Abstract: A downhole assembly including a turbine to be disposed within a wellbore and a rotating array. The rotating array includes magnetic material and is coupled to the turbine. The downhole assembly also includes a magnetostrictive material coupled to the rotating array to strain the magnetostrictive material to induce an electric current in a conductor coupled to the magnetostrictive material.

Abstract: A downhole assembly including a turbine to be disposed within a wellbore and a rotating array. The rotating array includes magnetic material and is coupled to the turbine. The downhole assembly also includes a magnetostrictive material coupled to the rotating array to strain the magnetostrictive material to induce an electric current in a conductor coupled to the magnetostrictive material.

Abstract: A downhole assembly including a turbine to be disposed within a wellbore and a rotating array. The rotating array includes magnetic material and is coupled to the turbine. The downhole assembly also includes a magnetostrictive material coupled to the rotating array to strain the magnetostrictive material to induce an electric current in a conductor coupled to the magnetostrictive material.

Abstract: This application relates to various methods and apparatus for rapidly obtaining accurate formation property data from a drilled earthen borehole. Quickly obtaining accurate formation property data, including formation fluid pressure, is vital to beneficially describing the various formations being intersected. For example, methods are disclosed for collecting numerous property values with a minimum of downhole tools, correcting and calibrating downhole measurements and sensors, and developing complete formation predictors and models by acquiring a diverse set of direct formation measurements, such as formation fluid pressure and temperature. Also disclosed are various methods of using of accurately and quickly obtained formation property data.