Abstract: A binder used for manufacturing a composite product is prepared by combining i) Maillard reactants selected from: reducing sugar reactant(s) and nitrogen-containing reactant(s); curable reaction product(s) of reducing sugar reactant(s) and nitrogen-containing reactant(s); and combinations thereof; and ii) a resin; reactants of a resin; and combinations thereof.

Abstract: A binder used for manufacturing a composite product is prepared by combining i) Maillard reactants selected from: reducing sugar reactant(s) and nitrogen-containing reactant(s); curable reaction product(s) of reducing sugar reactant(s) and nitrogen-containing reactant(s); and combinations thereof; and ii) a resin; reactants of a resin; and combinations thereof.

Abstract: A method for configuring a bottom hole assembly (BHA) includes receiving bending moment values for the BHA, curvature values and drilling conditions for a wellbore, and processing the bending moment values to create a representation of the curvature of the drilled wellbore. Processing the bending moment values includes selecting a set of curvature values in a specified range for a selected location, calculating a bending moment value for each curvature value, and determining an actual wellbore curvature at the location by matching the received bending moment value to one of the calculated bending moment values. The method further includes generating a representation of an actual path of the wellbore using selected curvature values at a plurality of wellbore locations, comparing the actual path of the wellbore with a planned path of the wellbore; and based on the comparison, determining a configuration of the BHA to drill a next wellbore.

Abstract: A stabilizer for use in a wellbore may include a downhole tubular configured to couple to a downhole conveyance in a wellbore, as well as two or more helical blades extending radially outward from the downhole tubular. The two or more helical blades are oriented about the downhole tubular to form respective flow paths between adjacent blades. Further, each blade of the two or more helical blades may include a line-of-sight face and a gauge ramp. The line-of-sight face is formed adjacent a leading inner blade wall of the blade at a lower end of the blade and is angularly offset from the leading inner blade wall. The gauge ramp extends from an outer surface of the downhole tubular toward an outer blade surface of the blade proximate the lower end of the blade.

Abstract: Provided is a stabilizer for use in a wellbore. The stabilizer, in one example, includes a downhole tubular coupleable to a downhole conveyance in a wellbore. In accordance with this example, the stabilizer additionally includes two or more helical wellbore stabilizing elements extending radially outward from the downhole component, the two or more helical wellbore stabilizing elements shaped such that an annular flow area between leading edges of adjacent helical wellbore stabilizing elements and between trailing edges of adjacent helical wellbore stabilizing elements is variable along at least a portion of a length (L) of the two or more helical wellbore stabilizing elements, and such that an unobstructed axial flow path exists between the adjacent helical wellbore stabilizing elements along the length (L).

Abstract: A resonant receiver for electromagnetic telemetry of wellbore-related data can be used to improve signal reception for transmitting or receiving low-amplitude downhole signals that include noise. A system can comprise a surface assembly with an antenna for wirelessly communicating signals with equipment positioned downhole in a wellbore. The surface assembly can comprise an amplifier and a tank circuit operable to resonate at a resonant frequency to pass a received signal at the resonant frequency to the amplifier while also shunting noise outside of the resonant frequency to ground. In some embodiments, a downhole transceiver in wireless communication with the surface assembly can comprise a similar tank circuit and amplifier.

Abstract: A method for configuring a bottom hole assembly (BHA) includes receiving bending moment values for the BHA, curvature values and drilling conditions for a wellbore, and processing the bending moment values to create a representation of the curvature of the drilled wellbore. Processing the bending moment values includes selecting a set of curvature values in a specified range for a selected location, calculating a bending moment value for each curvature value, and determining an actual wellbore curvature at the location by matching the received bending moment value to one of the calculated bending moment values. The method further includes generating a representation of an actual path of the wellbore using selected curvature values at a plurality of wellbore locations, comparing the actual path of the wellbore with a planned path of the wellbore; and based on the comparison, determining a configuration of the BHA to drill a next wellbore.

Abstract: A binder used for manufacturing a composite product is prepared by combining i) Maillard reactants selected from: reducing sugar reactant(s) and nitrogen-containing reactant(s); curable reaction product(s) of reducing sugar reactant(s) and nitrogen-containing reactant(s); and combinations thereof; and ii) a resin; reactants of a resin; and combinations thereof.

Abstract: A resonant receiver for electromagnetic telemetry of wellbore-related data can be used to improve signal reception for transmitting or receiving low-amplitude downhole signals that include noise. A system can comprise a surface assembly with an antenna for wirelessly communicating signals with equipment positioned downhole in a wellbore. The surface assembly can comprise an amplifier and a tank circuit operable to resonate at a resonant frequency to pass a received signal at the resonant frequency to the amplifier while also shunting noise outside of the resonant frequency to ground. In some embodiments, a downhole transceiver in wireless communication with the surface assembly can comprise a similar tank circuit and amplifier.

Abstract: In some embodiments, a method includes performing a directional drilling operation using a drill string having a drilling motor and cutting structures that include a drill bit and a reamer. The method includes receiving data from one or more sensors, wherein at least one of the one or more sensors output data related to at least one performance attribute associated with load monitoring between the drill bit and the reamer. The load monitoring is distributed between the drill bit and the reamer by the drilling motor. The at least one performance attribute comprises a differentiation of distribution of at least one of a weight and a torque applied to each of the drill bit and the reamer. The method includes displaying the data related to the at least one performance attribute associated with the load monitoring in a graphical and numerical representation on a graphical user interface screen.

Abstract: An electrical generator positionable downhole in a well bore includes a tubular housing having a first longitudinal end and a second longitudinal end, the housing having an internal passageway with a plurality of layers. The layers comprise at least a first protective layer, a second protective layer, and an electrically conductive layer positioned between the first and second protective layers. The layers define an internal cavity. A shaft with magnetic inserts is movably positioned in the internal cavity. Electrical current is generated when the shaft is moved. Alternatively, the device may be supplied with electrical power and used as a downhole motor.

Abstract: A progressing cavity drilling motor positionable in a wellbore includes a tubular housing, a stator having a collection of helical lobes, and a rotor having a collection of helical lobes. The rotor orbits about the central longitudinal axis of the stator. A bearing assembly is coupled to an end of the housing and is disposed around an end of the rotor. The bearing assembly includes a bearing housing disposed concentrically in the stator housing, an outer bearing disposed concentrically in the bearing housing, and an inner bearing disposed on the first cylindrical end of the rotor. The inner bearing has a central axis aligned with the central axis of the rotor and is positioned in the outer bearing such that the inner bearing orbits around the central longitudinal axis of the stator when the rotor is rotated in the stator.

Abstract: An electrical connector assembly positionable in a wellbore includes a flexible conductor, a first hanger ring connected to a first end of the flexible conductor, a first hanger ring landing shelf in an outer housing, a second hanger ring positioned on a second end of the flexible conductor, and a second hanger ring landing shelf in the housing.

Abstract: In some embodiments, a method includes performing a directional drilling operation using a drill string having a drilling motor and cutting structures that include a drill bit and a reamer. The method includes receiving data from one or more sensors, wherein at least one of the one or more sensors output data related to at least one performance attribute associated with load monitoring between the drill bit and the reamer. The load monitoring is distributed between the drill bit and the reamer by the drilling motor. The at least one performance attribute comprises a differentiation of distribution of at least one of a weight and a torque applied to each of the drill bit and the reamer. The method includes displaying the data related to the at least one performance attribute associated with the load monitoring in a graphical and numerical representation on a graphical user interface screen.

Abstract: A method includes performing a directional drilling operation. The method also includes receiving data from one or more sensors, wherein at least one of the one or more sensors output data related to a performance attribute of a downhole component that is from a group consisting of a downhole drilling motor and a rotary steerable tool. The downhole component comprises part of a drill string that is used to perform the directional drilling operation. The performance attribute is selected from a group consisting of rotations per unit of time of the downhole component, operating differential pressure across the downhole component and torque output of the downhole component. The method also includes displaying the data in a graphical and numerical representation on a graphical user interface screen.

Abstract: An apparatus includes acoustic equipment and an enclosure to support the acoustic equipment. The enclosure includes a front cover member, a middle cover member, a back cover member, and a hinge to connect the front cover member to the back cover member. The hinge enables the movement of the front cover member and the back cover member between an open position and a closed position. The middle cover member is disposed between the front cover member and the back cover member, with the middle cover member being connected to the hinge to enable movement of the middle cover member and the back cover member between an open position and a closed position. The enclosure further includes a first latch configured to releasably secure the middle cover member to the back cover member, and a second latch configured to releasably secure the front cover member to the back cover member.