Abstract: A method includes determining a rotational position of a crankshaft in a multiplex pump from one or more sensors disposed on the crankshaft, determining a position of each of a plurality of pistons along a corresponding pump bore in relation to a total stroke length of each piston and a connecting rod length, calculating an individual theoretical displaced volume of fluid for each of the pump bores in the multiplex pump based on the rotational position of the crankshaft, and summing the individual theoretical displaced volumes to determine a total theoretical pumped volume by the multiplex pump. A calibration method includes determination of the multiplex pump efficiency versus speed and discharge pressure, and the effect of pump leakage and valve closing delay on the pump efficiency. Verification of the pump performance and efficiency may be controlled during pumping to insure the validity of the last calibration data set.

Abstract: Apparatus and methods pertaining to a moveable well construction apparatus to be electrically energized via an electrical power transmission path extending between a stationary power source and the moveable well construction apparatus. The path comprises cables and connectors. A system comprises a detector operable for generating information indicative of whether the path is properly installed. The system permits the path to be electrically energized when the detector-generated information indicates the path is properly installed, and prevents the path from being electrically energized when the detector-generated information indicates the path is not properly installed.

Abstract: Electrical power transmission for well constriction apparatus via a rotatable spool positioned at and affixed to a moveable well construction apparatus at a wellsite and an electrical power cable at least partially wound on the rotatable spool and connected to stationary equipment at an end of the electrical power cable distal from the rotatable spool.

Abstract: The present disclosure introduces apparatus and related methods pertaining to a first electrical power cable, a second electrical power cable, and a set of breakers. The first and second electrical power cables each extend a variable distance between a static system at a wellsite and a movable system at the wellsite. The breakers are operable to select either of the first and second electrical power cables to couple electrical power from a stationary electrical power source at the static system to a load at the movable system.

Abstract: Apparatus and methods pertaining to a moveable well construction apparatus to be electrically energized via an electrical power transmission path extending between a stationary power source and the moveable well construction apparatus. The path comprises cables and connectors. A system comprises a detector operable for generating information indicative of whether the path is properly installed. The system permits the path to be electrically energized when the detector-generated information indicates the path is properly installed, and prevents the path from being electrically energized when the detector-generated information indicates the path is not properly installed.

Abstract: Apparatus and methods pertaining to a moveable well construction apparatus to be electrically energized via an electrical power transmission path extending between a stationary power source and the moveable well construction apparatus. The path comprises cables and connectors. A system comprises a detector operable for generating information indicative of whether the path is properly installed. The system permits the path to be electrically energized when the detector-generated information indicates the path is properly installed, and prevents the path from being electrically energized when the detector-generated information indicates the path is not properly installed.

Abstract: The present disclosure introduces apparatus and related methods pertaining to a first electrical power cable, a second electrical power cable, and a set of breakers. The first and second electrical power cables each extend a variable distance between a static system at a wellsite and a movable system at the wellsite. The breakers are operable to select either of the first and second electrical power cables to couple electrical power from a stationary electrical power source at the static system to a load at the movable system.

Abstract: An underreamer for increasing a diameter of a wellbore. The underreamer may include a body having an axial bore extending at least partially therethrough. An electromagnetic activation system may be disposed at least partially within the bore of the body. A valve may be disposed within the bore of the body and coupled to the electromagnetic activation system. The valve may include a mobile element and a static element. The mobile element may be coupled to the electromagnetic activation system and move from a first position where the mobile element obstructs fluid flow through the valve to a second position where the mobile element permits fluid flow through the valve. A cutter block may be movably coupled to the body and move radially-outward as the mobile element moves from the first position to the second position.

Abstract: A drill rig system for drilling a wellbore in the earth, the drill rig system comprising: a drill rig comprising: a substructure supporting a rig floor and a mast extending vertically above the rig floor; a top drive supported by a line spooled between a crown block and a travelling block, a carriage that is guided by the guide rails on the mast, wherein the carriage at least one arm that extends/retracts to position the top drive farther/closer to the mast; a theodolite and/or laser ranging systems positioned to reflect a laser beam off a reflector associated with the top drive to determine the top drive's position relative to a well axis; and a controller of the at least one arm based on the top drive position determined by the theodolite and/or laser ranging systems.

Abstract: A system for determining a location of a drill pipe joint deployed in a bore includes at least one magnetometer deployed on the bore. A processor is in electronic communication with the magnetometer and is configured to process magnetic field measurements made by the magnetometer to determine at least one of an axial position and a lateral position of the drill pipe joint.

Abstract: A system for offline suspension of a tubular including a first well having a first wellbore and a cellar formed at the surface of the first well with a rig movable from the first well to a second well. Additionally, a tubular string extending into the first well and a tubular support structure above the cellar of the first well, wherein the tubular support structure supports a weight of the tubular string such that the tubular is suspended from the tubular support structure independent from the rig and through a securing equipment configured to secure the first well.

Abstract: Systems and methods disclosed herein are directed to drilling rigs and, more specifically, to controlling the rotation of a drill string assembly to limit effects of irregular rotary movements form an AC induction motor driven by an inverter, associated with operation of a drilling rig. The systems and methods obtain rotational conditions of the rotary drilling system driven by a motor. Additionally, the systems and methods continuously generate, in response to a change in the rotational conditions, a supplied power to the motor at a frequency selected on relation of torque versus speed for the motor based on a virtual drive characteristic. The systems and methods can determine of the virtual drive characteristic to optimize coupling between the motor system and the rotational drilling system, as well as minimizing the effect of resonance and total noise.

Abstract: A pressure control device may include a body having a central axis extending therefrom; at least one rotatable seal within the body, the rotatable seal configured to seal against a tubular extending through the pressure control device along the central axis and rotate within the body with the tubular; at least one coil within the body wrapped at least once around the central axis, wherein the at least one coil is configured to send characteristics of the tubular to a controller; an outlet to divert fluid from an annulus, wherein the outlet being located axially below the at least one rotatable seal, wherein the controller is configured to control the at least one rotatable seal and its engagement against the tubular based on the characteristics of the tubular received by the controller.

Abstract: Embodiments disclosed provide a pump assembly including a first pump for delivering at least one fluid. The first pump may include a first inlet coupled to the first pump for delivering at least one first fluid to the first pump, a second inlet coupled to the first pump for delivering at least one second fluid to the first pump, a first discharge coupled to the first pump for delivering the at least one first fluid at a first pressure, and a second discharge coupled to the first pump for delivering the at least one second fluid at a second pressure. In some embodiments, the first discharge and the second discharge are isolated from each other.

Abstract: Devices and methods for well logging using a wear-resistant electrode are provided. A downhole device may include a drill collar and a first electrode mounted on the drill collar. Further, the first electrode may include a wear-resistant face. The first electrode may be movably coupled within the drill collar, and the first electrode may be configured to extend and retract into a wellbore to maintain contact with a wall of the wellbore. Furthermore, the first electrode may be configured to measure impedance of a geological formation.

Abstract: A system for determining a location of a drill pipe joint deployed in a bore includes at least one magnetometer deployed on the bore. A processor is in electronic communication with the magnetometer and is configured to process magnetic field measurements made by the magnetometer to determine at least one of an axial position and a lateral position of the drill pipe joint.

Abstract: Devices and methods for well logging using a wear resistant electrode are provided. A downhole device may include a drill bit, a gauge pad mounted on the drill bit, and a first electrode mounted in the gauge pad. An insulating polycrystalline diamond (PCD) material may surround at least a portion of the first electrode. Additionally, the first electrode may include an electrically conductive wear resistant contact point that maintains constant contact with a wall of a wellbore. Additionally, the first electrode may measure an impedance of a geological formation during a drilling operation.

Abstract: A submersible electrical machine includes a first magnetic package spaced axially from a second magnetic package, a first stator displaced axially from the first magnetic package by a first air gap, a second stator displaced axially from the second magnetic package by a second air gap. The electrical machine can be operated as a generator or as a motor. When operating as a generator, a turbine can rotate the magnetic packages relative to the stators in response to fluid flowing axially across the electrical machine.

Abstract: An intelligent drilling riser telemetry system includes a mud pulse telemetry transmitter deployed in a drill string. At least one annular pressure sensor is deployed on a drilling riser and is configured to sense mud pulse telemetry signals in an annular region thereof. A surface processor is in electronic communication with the annular pressure sensor via an electrical transmission line that extends along a length of the drilling riser from the annular pressure sensor to the drilling rig. The processor is configured to decode a transmitted mud pulse telemetry signal.

Abstract: A system for determining a location and a diameter of a pipe deployed in a bore includes a plurality of circumferentially spaced acoustic transmitters and a plurality of circumferentially spaced acoustic receivers deployed in a wall of the bore. A processor is configured to identify and process received acoustic waveforms that are reflected by the pipe to compute the location and the diameter of the pipe. The system may include a drill string deployed in a drilling riser.