Abstract: A method and system for drilling a wellbore. A method for drilling a wellbore includes: generating a library of defined patterns, each of the defined patterns corresponding to an operational behavior of drilling equipment used to drill the wellbore; collecting, during operation of the drilling equipment, measurements from sensors coupled to the drilling equipment; characterizing the measurements as correlating to one of the defined patterns; detecting the one of the defined patterns in the measurements; extracting a feature from the measurements; determining a condition of the drilling equipment by comparing a value of the feature to a threshold derived from the one of the defined patterns; and activating an actuator coupled to the drilling equipment to adjust operation of the drilling equipment based on the condition.

Abstract: A smart manifold for frac operations may include a support structure and a fluid management system arranged on the support structure. The fluid management system may be configured for receiving low-pressure frac fluid from a fluid processing system, delivering the low-pressure fluid to a plurality of pressurization units, receiving high-pressure fluid from the plurality of pressurization units, and delivering the high-pressure fluid to a well head. The smart manifold may also include a power management system arranged on the support structure. The power management system may be configured for receiving power for frac operations and for delivering power to each of the plurality of pressurization units.

Abstract: Reaming tools for reaming a borehole and related systems and methods are described herein. In an embodiment, the tool includes a body having a central axis, and a plurality of blades. Each of the plurality of blades includes an uphole section that extends in a first helical direction, a downhole section that extends in a second helical direction that is opposite the first helical direction, and an arcuate central section that continuously extends from the uphole section to the downhole section. The plurality of blades are eccentric about the central axis such that the reaming tool is configured to pass axially through a first diameter and is configured to ream a borehole to a second diameter that is greater than the first diameter when the tool is rotated about the central axis in a cutting direction.

Abstract: A friction reduction system includes a housing including a central axis and a central passage, a valve disposed in the housing and including a first valve body and a second valve body wherein the first valve body is permitted to rotate relative to the second valve body, and a mandrel coupled to the second valve body and permitted to travel axially relative to the housing, wherein a first net pressure force is applied against the mandrel that corresponds to a drilling fluid pressure of a drilling fluid in response to flowing the drilling fluid through the valve and transitioning the valve from a closed configuration to an open configuration, and wherein a second net pressure force is applied against the mandrel that corresponds to a wellbore fluid pressure in response to flowing the drilling fluid through the valve and transitioning the valve from the open configuration to the closed configuration.

Abstract: An actuator includes housing having a reciprocation axis, drive gear configured to couple to the motor, and electromagnetic clutch configured to couple to the motor and coupled to the drive gear. The clutch engages first and second clutch plates responsive to being powered and disengages the clutch plates responsive to not being powered. Actuator includes a ball screw including a nut and a threaded shaft. The nut is coupled to the drive gear and rotation of the drive gear induces rotation of the nut about the reciprocation axis. Rotation of the nut induces motion of the threaded shaft along the reciprocation axis. Actuator includes a fluid damper having a piston coupled to the threaded shaft and disposed within a chamber containing a fluid. Piston includes a port that couples a first chamber portion to a second chamber portion. A brake assembly limits rotation of the nut responsive to the assembly being engaged.

Abstract: A power swivel is disclosed that is configured to rotate tubular string and drill bit to form or extend a subterranean borehole. In an embodiment, the power swivel includes a motor, a gear box coupled to the motor, and a lubrication system coupled to the gear box. The lubrication system includes a pump disposed within the gear box, the pump including an outlet. In addition, the lubrication system includes a recirculation line fluidly coupled to the outlet of the pump. Further, the lubrication system includes a first injector fluidly coupled to the recirculation line. The injector is configured to deliver lubricant to one of a bearing and a gear disposed within the gear box.

Abstract: A valve for a well system including a valve housing including a first housing port, a second housing port, and a bore, a piston received in the bore and including a first end, a second end, and an annular flange including a first annular surface and a second annular surface both of which are in fluid communication with the second housing port, a piston seal disposed in the outer surface of the piston and in sealing engagement with an inner surface of the bore, and a cage assembly that includes a cage including a bore, a first cage port, a second cage port, and a third cage port, and a spool disposed in the cage and coupled to the piston, the spool including a throughbore.

Abstract: An electronics module or “puck” is positioned in a recess formed in the outer surface of a downhole tool. The puck body includes a flange segment having a first outer diameter, and an adjacent seal-engaging segment having an outer diameter that is less than the outer diameter of the flange segment. An annular seal is disposed about the seal-engaging segment and seals between the puck and the perimeter wall of the recess. A cover ring is disposed over an intermediate segment of the puck body, capturing the seal between the cover and the flange segment. A retainer ring is employed to selectively engage and disengage the perimeter wall of the recess, retaining the puck, seal and covering ring in the recess. A method for installation and removal of the puck is disclosed.

Abstract: An apparatus for separating solids from solids laden drilling fluid is provided. The apparatus includes a shale shaker and a screen assembly. The shale shaker includes a base and a basket isolated from the base, a flow tray arranged in the basket for directing screened drilling fluid. The screen assembly includes at least one layer of screening material, a screen support having a perimeter with at least one support point within the perimeter, wherein the flow tray includes at least one raised portion to support the screen assembly. In some versions the shale shaker has a basket having side supports and at least one intermediate support arranged between the side supports. The screen assembly includes a screen support supporting at least one layer of screening material.

Abstract: A method for cooling drilling mud includes controlling operation of a first closed-loop cooling system to cool a flow of drilling mud when a first temperature of the flow of drilling mud exceeds a first predetermined mud set point temperature, and controlling operation of a second closed-loop cooling system to further cool the flow of drilling mud when a second temperature of the flow of drilling mud that has been cooled by the first closed-loop cooling system exceeds a second predetermined mud set point temperature.

Abstract: Reaming tools for reaming a borehole and related systems and methods are described herein. In an embodiment, the tool includes a body having a central axis, and a plurality of blades. Each of the plurality of blades includes an uphole section that extends in a first helical direction, a downhole section that extends in a second helical direction that is opposite the first helical direction, and an arcuate central section that continuously extends from the uphole section to the downhole section. The plurality of blades are eccentric about the central axis such that the reaming tool is configured to pass axially through a first diameter and is configured to ream a borehole to a second diameter that is greater than the first diameter when the tool is rotated about the central axis in a cutting direction.

Abstract: A tower crane for assembling a wind turbine includes a boom assembly including a boom and a hoisting block coupled to the boom, an extendable tower assembly including a plurality of tower sections, and a transport assembly including a central support frame coupled to the tower assembly, a self-propelled transporter configured to transport the tower crane, and a diagonal brace extending between the central support frame and the transporter, wherein the diagonal brace includes a linear actuator configured to selectably extend and retract the diagonal brace.

Abstract: A pipe handling system for handling drill pipe may include a lifting system configured for handling a load of a pipe stand and a pipe handling robot configured for manipulating a position of the pipe stand. The robot may include an end effector configured for engaging the pipe stand. The system may also include a controller configured for controlling the pipe handling robot to maintain the end effector in substantial alignment with the pipe stand using a vector constraint.

Abstract: Embodiments relate generally to preventing wear to a nominal thickness of a wall of a drill pipe during a downhole operation. A drill pipe may include a first tool joint; a second tool joint; and a tubular section between the first tool joint and the second tool joint, wherein the tubular section comprises a wall with an overall thickness comprising a nominal thickness and a secondary thickness, wherein the secondary thickness is outer to the nominal thickness and is configured to abrade against a wall of the wellbore, thereby reducing the secondary thickness and maintaining the nominal thickness, wherein an ID of each tool joint is less than an ID of the tubular section to accommodate for threaded connectors.

Abstract: A valve for a well system including a valve housing including a first housing port, a second housing port, and a bore, a piston received in the bore and including a first end, a second end, and an annular flange including a first annular surface and a second annular surface both of which are in fluid communication with the second housing port, a piston seal disposed in the outer surface of the piston and in sealing engagement with an inner surface of the bore, and a cage assembly that includes a cage including a bore, a first cage port, a second cage port, and a third cage port, and a spool disposed in the cage and coupled to the piston, the spool including a throughbore.

Abstract: A system for manufacturing a tubular member includes a mandrel configured to be inserted within a throughbore of the tubular member to engage with an inner diameter of the throughbore. In addition, the system includes a die assembly comprising a cavity. The die assembly is configured to be disposed about an outer surface of the tubular member such that a central portion of the tubular member is aligned with the cavity. Further, the system includes a ram configured to apply a load to the tubular member along a central axis of the tubular member to expand the central portion of the outer surface of the tubular member into the cavity to form an upset region along the tubular member.

Abstract: A method includes receiving a drill bit design, which specifies design parameters related to a plurality of cutter elements of the drill bit. The method also includes estimating a thermal impact value for the cutter elements based on the design parameters and one or more drilling parameters, and estimating a cooling capacity value for the cutter elements based on the design and one or more cooling parameters. Finally, the method includes presenting the thermal impact values or the cooling capacity values together or individually on a per cutter element basis or as a function of a geometrical or physical property of the cutter elements.

Abstract: A progressing cavity device includes a stator including a first end, a second end, and an inner surface formed from a metallic material that extends between the first end and the second end, and a rotor rotatably disposed in the stator, the stator including a first end, a second end, and an outer surface formed from a metallic material that extends between the first end and the second end, wherein the outer surface of the rotor contacts the inner surface of the stator, wherein the inner surface of the stator includes a conical taper extending between the first end and the second end, wherein the outer surface of the rotor includes a conical taper extending between the first end and the second end.

Abstract: A drill pipe speed sensor includes a roller head assembly including an incremental encoder, a roller to contact a drill pipe, and first and second rotating members. The first rotating member is coupled to the roller, the second rotating member is coupled to the incremental encoder, and the first rotating member is coupled to the second rotating member. The sensor also includes a pivot assembly having mounting plates, pivotal arms, first and second mounting members, and a biasing member. The first and second mounting members extend between the mounting plates, which are parallel to each other. The biasing member contacts the mounting members and extends between the mounting members, and the biasing member is parallel to the mounting plates. The pivotal arms extend from the mounting plates to the roller head assembly and pivot relative to the mounting plates, and the first mounting member is coupled to two pivotal arms.

Abstract: A well system includes a well platform including a rig floor, a first rig floor robot and a second rig floor robot positioned on the rig floor, wherein the first rig floor robot is configured to guide a lower end of a pipe stand towards a setback position on the rig floor and the second rig floor robot is configured to guide a first pipe joint of the pipe stand into a first mouse hole formed in the rig floor, a mast extending from the rig floor, a racking board coupled to the mast, the racking board configured to secure an upper end of the pipe stand between a pair of finger boards of the racking board, a racking board robot positioned on the racking board and configured to position the upper end of the pipe stand between the pair of finger boards.