A method for calibrating a unit controller with a managing process determining a position of a decoupler mechanism on the pumping unit. The managing process can calibrate the unit controller with a dual pump mode in response to determining the decoupler mechanism is in a coupled position. The managing process can calibrate the unit controller with a single pump mode in response to determining the decoupler mechanism is in a decoupled position with the pumping unit operating with the first fluid end coupled to the power end and the second fluid end decoupled from the power end. The system controller can pump a wellbore treatment fluid in accordance with the pumping unit in i) the dual pump mode or ii) the single pump mode.

A mule shoe or UBHO sub with internal flow control is provided. The device has a fluid flow controlling interior surface feature which produces a predictable fluid flow. Specifically, the device, which is an elongated hollow cylinder, has internal “rifling” to produce a swirling flow pattern within the device. This flow pattern reduces turbulence within the sub, and prevents washing out of the pin during heavy fluid flow.

A tool, e.g. a downhole tool, utilizes at least one actuator which may be actuated rapidly between positions during operation of the tool. The actuator is moved via flow of an actuating fluid controlled by a main valve which, in turn, is controlled via a pilot valve. The pilot valve is operated to selectively control flow of the actuating fluid to the main valve so as to shift the main valve between desired operational positions.

A piston for use in a rotary steerable system includes a body formed from a first material. A sealing surface extends around the circumferential wall of the body. The sealing surface is formed from a plurality of layers of a second material. The second material is harder than the first material. The piston can be within a downhole piston assembly that also includes a housing, and the piston being longitudinally movable in a bore in the housing. A method for producing a piston includes preparing a piston formed from a first material, with the piston including a first end. A sealing surface is applied to the piston using laser cladding, with the sealing surface including a second material harder than the first material. The sealing surface is finished to a sealing surface diameter.

A method of servicing a wellbore includes introducing a fluid into a wellbore, the wellbore having particulate matter disposed therein and entraining at least a portion of the particulate matter within the fluid. The fluid includes a polymer having at least one hydrophobic monomer and at least one hydrophilic monomer. The fluid is also included within an analytical tool within a coiled tubing system for performing operations in a wellbore. The fluid is also included within a formation-tester tool.

A method of drilling a wellbore that traverses a formation, the method comprising the steps of inserting a one-stage drilling tool into the wellbore, the one-stage drilling tool comprising a laser head configured to produce a drilling beam, a completion sheath configured to line the wellbore, and a centralizer configured to support the completion sheath within the wellbore, operating the laser head to produce the drilling beam, wherein the drilling beam comprises a laser, wherein the drilling beam has a divergent shape comprising a base at a distance from a front end of the laser head and an apex proximate to the front end of the laser head, wherein a diameter of the base of the drilling beam is greater than a diameter of the one-stage drilling tool, and drilling the formation with the drilling beam, wherein the laser of the drilling beam is operable to sublimate the formation.

Control valves can allow for a steering assembly of a drill string. An exemplary control valve can include a first valve element including a first orifice, the first valve element being movable by actuation by a motor, and a second valve element including an orifice, wherein flow passing through the first valve element orifice passes through the second orifice and into a flow channel to be in fluid communication with a piston bore to exert pressure against a piston movable within the piston bore, the piston being coupled to a steering pad for applying force against the wellbore wall to steer a direction of the drill string. The first valve element is movable with respect to the second valve element to change flow through the first valve element orifice and the second valve element orifice to modify fluid pressure within the flow channel that is exerted against the piston.

A rotary steerable tool for directional drilling includes a tool body including a flowbore for flowing pressurized fluid therethrough and a plurality of extendable members movably coupled to the tool body for selectively engaging a borehole wall, each extendable member including a piston for moving the extend-able member to an extended position. The tool further includes a pressurized fluid supply flow path to provide fluid pressure from the flowbore to the pistons, and a plurality of linear actuators, each independently actuatable to control fluid pressure from the pressurized fluid supply flow path to a respective piston.

Control valves can allow for a steering assembly of a drill string. An exemplary control valve can include a first valve element including a first orifice, the first valve element being movable by actuation by a motor, and a second valve element including an orifice, wherein flow passing through the first valve element orifice passes through the second orifice and into a flow channel to be in fluid communication with a piston bore to exert pressure against a piston movable within the piston bore, the piston being coupled to a steering pad for applying force against the wellbore wall to steer a direction of the drill string. The first valve element is movable with respect to the second valve element to change flow through the first valve element orifice and the second valve element orifice to modify fluid pressure within the flow channel that is exerted against the piston.

A method of drilling a wellbore that traverses a formation, the method comprising the steps of inserting a one-stage drilling tool into the wellbore. The one-stage drilling tool comprising a laser head configured to produce a drilling beam, a completion sheath configured to line the wellbore, and a centralizer configured to support the completion sheath within the wellbore. Operating the laser head to produce the drilling beam that comprises a laser. The drilling beam has a divergent shape comprising a base at a distance from a front end of the laser head and an apex proximate to the front end of the laser head, wherein a diameter of the base of the drilling beam is greater than a diameter of the one-stage drilling tool. And drilling the formation with the drilling beam, wherein the laser of the drilling beam is operable to sublimate the formation.