Abstract: A particle impact drill bit for a well system includes a central axis, a longitudinal first end, a longitudinal second end opposite the first end, and a feed passage extending into the drill bit from the first end, a pilot section located at the second end, the pilot section including one or more converging nozzles in fluid communication with the feed passage, and a reamer section located between the first end and the second end and including one or more reamer blades extending radially outwards from the central axis of the drill bit, and wherein the reamer section defines a maximum width of the drill bit.

Abstract: A drill bit for drilling a borehole in an earthen formation has a central axis and a cutting direction of rotation. The bit includes a bit body configured to rotate about the axis in the cutting direction of rotation. The bit body includes a bit face. The bit also includes a blade extending radially along the bit face. In addition, the bit includes a first cutter element mounted to a cutter-supporting surface of the blade and a second cutter element mounted to the cutter-supporting surface of the blade. The first cutter element has a central axis and includes a first forward-facing cutting face including a first cutting tip distal the cutter supporting surface and a first planar surface extending radially from the first cutting tip toward the central axis of the first cutter element. The first planar surface is oriented at a first effective backrake angle measured between the cutter supporting surface and a surface vector of the first planar surface.

Abstract: A cutter element for a drill bit includes a base portion having a central axis, a first end, and a second end. In addition, the cutter element includes a cutting layer fixably mounted to the first end of the base portion. The cutting layer includes a cutting face distal the base portion. The cutting face includes a first planar surface and a second planar surface that is circumferentially-spaced from the first planar surface. Each planar surface is positioned at an outer periphery of the cutting face adjacent the radially outer surface of the cutting layer. The cutting face also includes a saddle surface including a crown and a pair of lateral side surfaces that slope down and away from the crown toward the radially outer cylindrical surface of the cutting layer. The crown extends from the first planar surface to the second planar surface.

Abstract: Embodiments disclosed herein are directed to a flow pulsing system including a rotor, a stator, a dart which is configured to releasably couple with the rotor, and a nozzle releasably coupled to the rotor which is configured to control a fluid flow through the rotor. In some embodiments, the system uses a screen disposed therein which includes an inner bore in fluid communication with a plurality of lobe cavities along the rotor. In some embodiments, the system uses a stationary valve and an oscillating valve having a plurality of oscillating valve ports which are in fluid communication with the plurality of lobe cavities.

Abstract: A nozzle for distributing drilling fluid from a drill bit has a central axis and includes a first end, a second end, and a radially inner surface extending axially from the first end to the second end. The radially inner surface defines a flow passage extending from the first end to the second end. The flow passage has a central axis, an inlet at the first end, an outlet at the second end, a first section extending from the inlet, and a second section extending from the outlet to the first section. In addition, the nozzle includes a side outlet extending radially from the radially outer surface to the radially inner surface. The side outlet extends axially from the second end and is contiguous with the outlet. The second section of the flow passage at least partially overlaps with the side outlet. The first section of the flow passage is curved as viewed in a cross-section of the nozzle taken in a reference plane containing the central axis of the nozzle and bisecting the side outlet.

Abstract: A method for increasing an amplitude of reciprocal axial extensions and contractions of a shock tool configured to induce axial oscillations in a drillstring during drilling operations includes (a) selecting the shock tool. The shock tool has a central axis and an axial length. The shock tool includes an outer housing, a mandrel telescopically disposed within the outer housing, and a first annular piston fixably coupled to the mandrel. The shock tool has a first amplitude of reciprocal axial extension and contraction at a pressure differential between a first fluid pressure in the outer housing and a second fluid pressure outside the outer housing. In addition, the method includes (b) fixably coupling a second annular piston to the mandrel of the shock tool and increasing the axial length of the shock tool after (a). The second annular piston is axially spaced from the first annular piston.

Abstract: An insert for a drill bit includes a base portion. In addition, the insert includes a formation engaging portion extending from the base portion. The formation engaging portion has a longitudinal axis and includes a first end, a second end opposite the first end, a first lateral side extending from the first end to the second end, and a second lateral side extending from the first end to the second end, and an elongate crown extending longitudinally from the first end to the second end and laterally from the first lateral side to the second lateral side. The first lateral side comprises a first curved surface having a first radius of curvature in top view of the insert and the second lateral side includes a second curved surface having a second radius of curvature in top view of the insert. The first radius of curvature of the first curved surface is different than the second radius of curvature of the second curved surface.

Abstract: A cutter element for a drill bit includes a base portion having a central axis, a first end, a second end, and a radially outer surface extending axially from the first end to the second end. In addition, the cutter element includes a cutting layer fixably mounted to the first end of the base portion. The cutting layer includes a cutting face distal the base portion and a radially outer surface extending axially from the cutting face to the radially outer surface of the base portion. The cutting face includes a planar central region centered relative to the central axis and disposed in a plane oriented perpendicular to the central axis. Further, the cutting face includes a plurality of circumferentially-spaced cutting regions disposed about the planar central region. Still further, the cutting face includes a plurality of circumferentially-spaced relief regions disposed about the planar central region.

Abstract: A bend adjustment assembly for a downhole mud motor includes a driveshaft housing, a driveshaft rotatably disposed in the driveshaft housing, a bearing mandrel coupled to the driveshaft, wherein the bend adjustment assembly includes a first position that provides a first deflection angle between a longitudinal axis of the driveshaft housing and a longitudinal axis of the bearing mandrel, a second position that provides a second deflection angle, and a third position that provides a third deflection angle, and an actuator assembly configured to shift the bend adjustment assembly between the first position, the second position, and the third position in response to a change in at least one of flowrate of a drilling fluid supplied to the downhole mud motor, pressure of the drilling fluid supplied to the downhole mud motor, and relative rotation between the driveshaft housing and the bearing mandrel.

Abstract: An insert for a drill bit includes a base portion having a central axis and a formation engaging portion. The formation engaging portion includes an elongate peaked ridge, a first flanking surface extending from the peaked ridge, and a second flanking surface extending from the peaked ridge. The first flanking surface is defined by a first curve rotated about a first axis and the second flanking surface is defined by a second curve rotated about a second axis. The first axis and the second axis are disposed in a reference plane that bisects the base portion and contains the central axis of the base portion. The first axis is disposed at a first radius measured in the reference plane and the second axis is disposed at a second radius measured in the reference plane. The first radius is different from the second radius.

Abstract: A shock tool for reciprocating a drillstring includes an outer housing. The outer housing has a central axis, a first end, a second end opposite the first end, and a passage extending axially from the first end to the second end. In addition, the shock tool includes a mandrel assembly coaxially disposed in the passage of the outer housing and configured to move axially relative to the outer housing. The mandrel assembly has a first end axially spaced from the outer housing, a second end disposed in the outer housing, and a passage extending axially from the first end of the mandrel assembly to the second end of the mandrel assembly. The mandrel assembly includes a mandrel and a first annular piston fixably coupled to the mandrel. The first annular piston is disposed at the second end of the mandrel assembly and sealingly engages the outer housing.

Abstract: A downhole motor for directional drilling includes a driveshaft assembly including a driveshaft housing and a driveshaft rotatably disposed within the driveshaft housing, a bearing assembly including a bearing housing and a bearing mandrel rotatably disposed within the bearing housing, wherein the bearing mandrel is configured to couple with a drill bit, a bend adjustment assembly including a first position that provides a first deflection angle between a longitudinal axis of the driveshaft housing and a longitudinal axis of the bearing mandrel, and a second position that provides a second deflection angle between the longitudinal axis of the driveshaft housing and the longitudinal axis of the bearing mandrel that is different from the first deflection angle, and one or more hydraulic pumps configured to actuate the bend adjustment assembly between the first position and the second position.

Abstract: A method for forming a seal boot includes forming a stack of discrete, non-intertwined layers by layering a sheet of elastomeric material with a fabric; rolling the stack to form a tube; installing the tube within a mold; closing the mold; and heating the mold and the installed tube.

Abstract: A cutter element includes a base portion having a central axis, a first end, and a second end. In addition, the cutter element includes a cutting layer fixably mounted to the first end of the base portion. The cutting layer includes a cutting face distal. The cutting face includes a planar central region centered relative to the central axis and disposed in a plane oriented perpendicular to the central axis. The cutting face also includes a plurality of circumferentially-spaced cutting regions disposed about the planar central region. Each cutting region extends from the planar central region to the radially outer surface of the cutting layer. Each cutting region slopes axially toward the base portion moving radially outward from the planar central region to the radially outer surface of the cutting layer. Further, the cutting face includes a plurality of circumferentially-spaced relief regions disposed about the planar central region.

Abstract: Apparatus and method for drilling a wellbore using non-synchronous oscillators. An apparatus for drilling a wellbore includes a tubing string and a bottom hole assembly coupled to the tubing string. The bottom hole assembly includes a first oscillator and a second oscillator. The first oscillator is configured to restrict fluid flow and induce pressure pulses in the tubing string at a first frequency. The second oscillator is configured to restrict fluid flow and induce pressure pulses in the tubing string at a second frequency. The first frequency is different from the second frequency.

Abstract: Some embodiments include a sensor assembly comprising a sensor to be carried by a movable component movably positionable about a tool body of a downhole tool. The sensor is to take wellsite measurements and the downhole tool is positionable in a wellbore. The sensor assembly further includes electronics positionable in the movable component. The electronics are to electrically connect to the sensor to receive the wellsite measurements from the sensor, and the wellsite measurements are usable to determine wellsite parameters.

Abstract: A downhole motor for directional drilling includes a driveshaft assembly including a driveshaft housing and a driveshaft rotatably disposed within the driveshaft housing, a bearing assembly including a bearing housing and a bearing mandrel rotatably disposed within the bearing housing, wherein the bearing mandrel is configured to couple with a drill bit, a bend adjustment assembly configured to adjust a bend setting of the downhole motor, and an electronics package coupled to the driveshaft assembly, wherein the electronics package is configured to receive data from sensors of the downhole motor.

Abstract: Systems, methods, computer-readable media having computer programs, and electronic interfaces to detect and mitigate drill cuttings build-up in borehole drilling for hydrocarbon wells are provided. Embodiments include determining annular pressure at downhole sensors when pumping a drilling fluid into the borehole. Then one or more measures of a decrease in pressure in the borehole between a first sensor and a second sensor that is attributable to build-up of drill cuttings between the first sensor and the second sensor can be determined. Portions of effective density of the drilling fluid that are attributable to build-up of drill cuttings between the sensors also can be determined. Drill cuttings and fluid flow in an interval of the borehole between the first sensor and the second sensor can be analyzed. Whether drill cuttings limit fluid flow in an interval of the borehole between the first sensor and the second sensor then can be determined.

Abstract: A cutter element for a drill bit includes a base portion having a central axis, a first end, and a second end. In addition, the cutter element includes a cutting layer fixably mounted to the first end of the base portion. The cutting layer includes a cutting face distal the base portion. The cutting face includes an elongate raised ridge having a first end at a radially outer surface of the cutting layer and a second end at the radially outer surface of the cutting layer. The raised ridge defines a maximum height of the cutter element measured axially from the second end of the base portion to the cutting face. The cutting face also includes a first planar lateral side surface and a second planar lateral side surface. Each planar lateral side surface extends from the raised ridge to the radially outer surface of the cutting layer.

Abstract: A nozzle for distributing drilling fluid from a drill bit has a central axis and includes a first end, a second end, and a radially inner surface extending axially from the first end to the second end. The radially inner surface defines a flow passage extending from the first end to the second end. The flow passage has a central axis, an inlet at the first end, an outlet at the second end, a first section extending from the inlet, and a second section extending from the outlet to the first section. In addition, the nozzle includes a side outlet extending radially from the radially outer surface to the radially inner surface. The side outlet extends axially from the second end and is contiguous with the outlet. The second section of the flow passage at least partially overlaps with the side outlet. The first section of the flow passage is curved as viewed in a cross-section of the nozzle taken in a reference plane containing the central axis of the nozzle and bisecting the side outlet.