A connector for coiled tubing may include a main body configured for welding to a free end of the coiled tubing and having an internal stem extending distally therefrom. The stem may include a sleeve potion and the connector may include an alignment sleeve arranged on the sleeve portion of the stem and being free to rotate relative to the stem. The alignment sleeve may have a longitudinally extending groove on an outside surface thereof for receiving a longitudinal weld bead on an inside surface of the coiled tubing.
A rotor bearing system configured to operatively couple a progressing cavity machine to an external device can comprise a housing including an inner surface defining a first bore extending through the housing along a central axis, a first bearing arranged on the inner surface, and a shaft member including an outer surface extending between a proximal portion and a distal portion of the shaft member and a second bearing arranged on the outer surface, the second bearing the second bearing configured to contact the first bearing to limit eccentric motion of the driveshaft of the external device and the rotor head of the progressing cavity machine relative to a stator of the progressing cavity machine during rotation of the rotor head, the shaft member, and the driveshaft.
A method for drilling a wellbore includes providing a mud motor connected to a downhole end of a drillstring, wherein a bend adjustment assembly of the mud motor is provided in a first configuration, pumping a drilling fluid at a drilling flowrate from a supply pump into the drillstring whereby a drill bit coupled to the drillstring is rotated to drill into the earthen formation, receiving by a drilling controller an actuation command instructing the drilling controller to shift the bend adjustment assembly from the first configuration to a second configuration, and operating by the drilling controller at least one of the supply pump to provide an actuation drilling fluid flowrate stored in a storage device of the drilling controller, and a rotary system to provide an actuation drillstring rotational speed stored in the storage device.
E21B 44/00 - Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systems; Systems specially adapted for monitoring a plurality of drilling variables or conditions
Various embodiments disclosed relate to a configurable drill fluid containment device. The present disclosure includes a device including a central shell configured to at least partially enclose an end of a drill pipe. The central shell can have two halves, each of the halves having flanges that are configured to attaching one or more extension features to the device. The flanges can be configured to attach extension features at an upper end of the device, a lower end of the device, or both.
A pump monitoring system may include a sensor for monitoring a parameter of a pump system. The sensor may include at least one of an ammeter in electrical communication with an electric motor driving a pump and a torque sensor on a drive shaft that drives a pump. The system may also include a controller in data communication with the sensor to receive sensor data. The controller may be configured to assess the performance of the respective pump in one or more ways. At least one of the one or more ways may include reliance on the sensor data from only one sensor to identify valve or seat wear or failure. Alternatively or additionally, at least one of the one or more ways may identify valve or seat wear or failure without reliance on pump output pressure.
F04B 49/00 - Control of, or safety measures for, machines, pumps, or pumping installations, not otherwise provided for in, or of interest apart from, groups
E21B 41/00 - Equipment or details not covered by groups
F04B 17/03 - Pumps characterised by combination with, or adaptation to, specific driving engines or motors driven by electric motors
F04B 51/00 - Testing machines, pumps, or pumping installations
F16K 25/00 - VALVES; TAPS; COCKS; ACTUATING-FLOATS; DEVICES FOR VENTING OR AERATING - Details relating to contact between valve members and seats
A passive spacer system may include a racking board comprising a slot and a spacer arranged along the slot such that a portion of the spacer impinges on the slot. The spacer may be biased in a neutral position and configured to move to a spacing position due to motion of tubulars into and out of the racking board, which interact with the portion of the spacer that impinges on the slot.
An autonomous along string measurement tool may include a data collection and transmission system having a sensor configured to collect the downhole data, a communication tool configured to transmit the downhole data to the surface, and an operations processor configured for receiving downhole data from the sensor and controlling the communication tool to transmit the downhole data. The system may also include a power bus configured for supplying power to the data collection and transmission system, a power source in selective electrical communication with the power bus, and a power gateway. The power gateway may be configured to control the selective electrical communication between the power source and the power bus based on whether tool conditions are suitable for operation.
E21B 47/024 - Determining slope or direction of devices in the borehole
E21B 47/12 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
E21B 47/13 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling by electromagnetic energy, e.g. of radio frequency range
A friction reduction system disposable in a wellbore includes a first valve member including an inner surface which includes a valve seat; and a second valve member rotatable concentrically about a central axis of the first valve member and including a radial port coverable by the valve seat of the outer valve member, wherein the friction reduction system includes an open configuration that provides a maximum flow area through a valve of the friction reduction system including the second valve member and the first valve member, wherein the friction reduction system includes a closed configuration that provides a minimum flow area through the valve which is less than the maximum flow area, and wherein the friction reduction system is configured to generate a pressure pulse in a fluid flowing through the friction reduction system in response to the friction reduction system transitioning from the open configuration to the closed configuration.
A drilling fluid conditioning system for a well system includes a return conduit configured to receive drilling fluid recirculated from a wellbore of the well system, a drilling fluid pre-chilling system in fluid communication with and downstream from the return conduit, wherein the drilling fluid pre-chilling system includes a cooler configured to transfer heat from the drilling fluid to a heat sink, and a solids control system in fluid communication with and downstream from the drilling fluid pre-chilling system, wherein the solids control system is configured to separate at least some solids from the drilling fluid.
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. The second cutter element has a central axis and comprises a second forward-facing cutting face including a second cutting tip distal the cutter supporting surface and a second planar surface extending radially from the second cutting tip toward the central axis of the second cutter element. The second planar surface is oriented at a second effective backrake angle measured between the cutter supporting surface and a surface vector of the second planar surface. The second effective backrake angle is greater than the first effective backrake angle.
E21B 10/43 - Rotary drag type drill bits with teeth, blades or like cutting elements, e.g. fork-type bits, fish tail bits characterised by the arrangement of teeth or other cutting elements
E21B 10/55 - Drill bits characterised by wear resisting parts, e.g. diamond inserts the bit being of the rotary drag type, e.g. fork-type bits with preformed cutting elements
E21B 10/567 - Button-type inserts with preformed cutting elements mounted on a distinct support, e.g. polycrystalline inserts
A guide mechanism may include a first jaw and a second jaw pivotably coupled to the first jaw. The jaws may include a guide having a bottom pocket for seating arrangement on a box end of a first tubular and a top funnel for laterally guiding a pin end of a second tubular into the box end. The guide mechanism may also include a linkage system secured to the first and second jaws to control pivoting motion of the jaws. The guide mechanism may also include a bias mechanism coupled to the linkage system and configured to impart a biasing force on the jaws via the linkage system. The biasing force may be adapted to resist opening of the jaws such that opening of the jaws occurs when a lateral force is applied to the guide mechanism that overcomes the biasing force.
An along string measurement tool may include an elongate body configured for loading into a drill string and a sensor array arranged on the body. The sensor array may include a first sensor arranged at a first sensor location on the body and the first sensor may be oriented relative to the body and configured for sensing annular pressures in a wellbore. The sensor array may include a second sensor arranged at a second sensor location on the body and the second sensor location may be spaced longitudinally along the body from the first sensor location by a first distance. The second sensor may be oriented relative to the body and configured for sensing annular pressures in a wellbore.
E21B 47/13 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling by electromagnetic energy, e.g. of radio frequency range
E21B 47/18 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling using acoustic waves through the well fluid
A proppant supply system can include a fluid supply system including a blender configured to receive and mix liquid and proppant to form a proppant slurry, and an electrically driven conveyor configured and arranged for direct and metered delivery of proppant to the blender. The proppant supply system can include a proppant source configured to discharge proppant to the conveyor, and a control system for controlling a speed of the conveyor, to control a rate at which proppant is delivered to the blender.
B01F 35/80 - Forming a predetermined ratio of the substances to be mixed
B01F 35/82 - Forming a predetermined ratio of the substances to be mixed by adding a material to be mixed to a mixture in response to a detected feature, e.g. density, radioactivity, consumed power or colour
A tubular member includes a central axis, a first end, a second end opposite the first end, and an outer surface extending from the first end to the second end. In addition, the tubular member includes a weld overlay disposed on a portion of the outer surface that is axially spaced from the first end and the second end, wherein the weld overlay comprises a plurality of weld beads.
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.
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.
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.
E21B 10/26 - Drill bits with leading portion, i.e. drill bits with a pilot cutter; Drill bits for enlarging the borehole, e.g. reamers
E21B 10/32 - Drill bits with leading portion, i.e. drill bits with a pilot cutter; Drill bits for enlarging the borehole, e.g. reamers with expansible cutting tools
18.
TOOLS AND METHODS FOR REFACING TUBULAR ENDS FORMING A THREADED CONNECTION
A refacing tool includes a feed assembly that holds a first set of cutters positioned for refacing the inner shoulder of a pin or box end of a tubular and a second set of cutters positioned for refacing the outer shoulder of the pin or box end. The axial spacing between the first set of cutters and the second set of cutters is fixed and determined by the geometry of the feed assembly. The refacing tool can simultaneously reface the inner shoulder and the outer shoulder, as well as chamfers.
B23B 3/22 - Turning-machines or devices with rotary tool heads
B23B 5/16 - Turning-machines or devices specially adapted for particular work; Accessories specially adapted therefor for bevelling, chamfering, or deburring the ends of bars or tubes
B23B 5/26 - Turning-machines or devices specially adapted for particular work; Accessories specially adapted therefor for simultaneously turning internal and external surfaces of a body
A horizontal pipe storing and stand building system may include a pipe rack and a horizontal stand building system arranged adjacent to the pipe rack and configured to receive tubulars from the pipe rack and construct pipe stands in a horizontal orientation. The system may also include a delivery system arranged adjacent the horizontal stand building system and opposite the pipe rack. The delivery system may be configured to receive horizontally arranged pipe stands from the horizontal stand building system and deliver them to a drill rig.
E21B 19/09 - Apparatus for feeding the rods or cables; Apparatus for increasing or decreasing the pressure on the drilling tool; Apparatus for counterbalancing the weight of the rods specially adapted for drilling underwater formations from a floating support using heave compensators supporting the drill string
E21B 19/14 - Racks, ramps, troughs or bins, for holding the lengths of rod singly or connected; Handling between storage place and borehole
E21B 19/15 - Racking of rods in horizontal position; Handling between horizontal and vertical position
E21B 19/16 - Connecting or disconnecting pipe couplings or joints
E21B 19/20 - Combined feeding from rack and connecting, e.g. automatically
A decanter centrifuge includes one or more nozzles through which a slurry may be discharged from a feed chamber into a separation zone within a centrifuge bowl. A scroll conveyor may be coaxially aligned in the separation zone within the centrifuge bowl around the circumference of the feed chamber. In the separation zone, the slurry can be separated into at least a light phase and a heavy phase by centrifugal acceleration generated by rotation of the centrifuge bowl, the feed chamber, and/or the scroll conveyor. Each separated phase can discharge from the centrifuge bowl via respective discharge ports. Each nozzle may include a rectangular aperture and differentiated profiles of its leading edge and trailing edge. In some embodiments, the leading edge of the aperture comprises a rounded profile, while the trailing edge comprises an abrupt edge or a less- rounded edge.
A system for separating solids from fluids, the system including a separator having a deck having a feed inlet and a solids outlet and a plurality of screens disposed on the deck. Also, an image sensor disposed proximate the solids outlet, the image sensor to capture images of the separator, and send the captured mages to a remote location for analysis. Additionally, a method of monitoring a separator, the method including capturing an image of the separator and sending the image of the separator to a control module disposed at a remote location. The method also including analyzing the image with the control module to determine a separation property and modifying the operation of the separator based on the determined separation property.
A coupling mechanism for securing a tool to a tool arm may include a housing and an engaging lock. The engaging lock may be arranged within the housing and configured for rotation by the tool arm. Rotation of the engaging lock may drive locking mechanisms partially through the housing to establish a longitudinally secured connection.
A screen assembly for vibratory separation includes a screen having a plurality of raised screen components formed therein, with each of the raised screen components defining a face oriented to oppose a flow direction of the screen assembly. In examples, a screen of the screen assembly is assembled from a plurality of metal cloth layers bonded together. Bonding of the metal cloth layers may be accomplished by a sintering process.
A pipe handling system for handling drill pipe on a drill rig may include a lifting system configured for handling a load of a pipe stand and a first pipe handling robot arranged at or near a drill floor of the drill rig and configured for manipulating a bottom end of the pipe stand between a setback area on the drill floor and well center. The system may also include a second pipe handling robot arranged at or near a racking board of the drill rig and configured for manipulating a top end of the pipe stand between the racking board and well center. The first pipe handling robot may have a base that is supported from a location outside a plan view envelope of the setback area of the drill floor.
A pressure pulse system includes a stator, a rotor rotatably positioned in the stator, and a valve assembly configured to induce a pressure pulse in response to rotation of the rotor within the stator, wherein the valve assembly includes a first valve plate coupled to one of the stator and the rotor and including a flow passage, and a second valve plate coupled to the other of the stator or the rotor to which the first valve plate is not coupled and comprising a first flow passage and a second flow passage that is spaced from the first flow passage, wherein the valve assembly provides a first flowpath and a second flowpath between the flow passage of the first valve plate and the second flow passage of the second valve plate.
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.
E21B 47/01 - Devices for supporting measuring instruments on drill bits, pipes, rods or wirelines; Protecting measuring instruments in boreholes against heat, shock, pressure or the like
E21B 47/14 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling using acoustic waves
G01V 5/10 - Prospecting or detecting by the use of nuclear radiation, e.g. of natural or induced radioactivity specially adapted for well-logging using primary nuclear radiation sources or X-rays using neutron sources
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.
A close coupled processing system may include a fluid processing system for producing frac fluid for frac operations, a fluid distribution system for distributing the frac fluid to a plurality of pressurization units, and a large bore fluid connection connecting the fluid processing system and the fluid distribution system.
A trailer assembly for carrying coiled tubing includes a main beam assembly extending from a forward end of the trailer assembly to a rear end of the trailer assembly. The main beam assembly includes a forward portion that extends from the forward end of the trailer assembly, a rear portion that extends to the rear end of the trailer assembly, and a middle portion connected between the forward portion and the rear portion and configured to transfer load to the forward portion and the rear portion. The middle portion includes an upper beam section, and a lower beam section vertically separated from the upper beam section. The upper beam section is configured to share a load resultant from a bending force experienced by the lower beam section.
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.
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.
F04C 2/107 - Rotary-piston machines or pumps of intermeshing-engagement type, i.e. with engagement of co-operating members similar to that of toothed gearing of internal-axis type with the outer member having more teeth or tooth-equivalents, e.g. rollers, than the inner member with helical teeth
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.
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.
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.
B25J 11/00 - Manipulators not otherwise provided for
E21B 19/06 - Elevators, i.e. rod- or tube-gripping devices
E21B 19/084 - Apparatus for feeding the rods or cables; Apparatus for increasing or decreasing the pressure on the drilling tool; Apparatus for counterbalancing the weight of the rods with flexible drawing means, e.g. cables
E21B 19/087 - Apparatus for feeding the rods or cables; Apparatus for increasing or decreasing the pressure on the drilling tool; Apparatus for counterbalancing the weight of the rods by means of a swinging arm
35.
FLOTATION APPARATUS FOR PROVIDING BUOYANCY TO TUBULAR MEMBERS
A downhole tool includes a housing configured to be connected between two tubular members. The housing includes a chamber and a plug assembly is disposed in the chamber and divides the chamber into an up-hole portion and a downhole portion. The plug assembly includes a glass member having a predetermined residual surface compression, at least a first face, and at least one strength-reducing surface feature on the first face. The strength-reducing surface feature is configured to cause the glass member to disintegrate when the glass member is exposed to a pressure in the up-hole portion of a magnitude that creates a tensile stress on the first face that exceeds the predetermined residual surface compression.
E21B 34/08 - Valve arrangements for boreholes or wells in wells responsive to flow or pressure of the fluid obtained
E21B 29/00 - Cutting or destroying pipes, packers, plugs, or wire lines, located in boreholes or wells, e.g. cutting of damaged pipes, of windows; Deforming of pipes in boreholes or wells; Reconditioning of well casings while in the ground
E21B 29/02 - Cutting or destroying pipes, packers, plugs, or wire lines, located in boreholes or wells, e.g. cutting of damaged pipes, of windows; Deforming of pipes in boreholes or wells; Reconditioning of well casings while in the ground by explosives or by thermal or chemical means
E21B 29/06 - Cutting windows, e.g. directional window cutters for whipstock operations
E21B 29/08 - Cutting or deforming pipes to control fluid flow
E21B 34/06 - Valve arrangements for boreholes or wells in wells
36.
SYSTEMS AND METHODS FOR ELECTRICAL POWER GENERATION
Power generation assemblies and methods relating thereto are disclosed. In an embodiment, the power generation assembly includes a thermoelectric generator, and a conductor configured to conduct electricity generated by the thermoelectric generator to the surface of a subterranean wellbore. The power generation assembly is to circulate a working fluid through a closed loop in the power generation assembly in response to the receipt of geothermal energy within a subterranean formation, to cause the thermoelectric generator to generate electricity.
F03G 7/04 - Mechanical-power-producing mechanisms, not otherwise provided for or using energy sources not otherwise provided for using pressure differences or thermal differences occurring in nature
F28D 15/02 - Heat-exchange apparatus with the intermediate heat-transfer medium in closed tubes passing into or through the conduit walls in which the medium condenses and evaporates, e.g. heat-pipes
A rig control interface includes a plurality of interface systems. Each of the interface systems is configured to manipulate a rig control based on a signal received from an automated rig control system. The interface systems includes a mechanical control interface. The mechanical control interface includes an actuator configured to mechanically move a control handle from a first position to a second position responsive to the signal.
E21B 44/00 - Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systems; Systems specially adapted for monitoring a plurality of drilling variables or conditions
E21B 41/00 - Equipment or details not covered by groups
A rotary steerable drilling assembly for directional drilling includes a driveshaft rotatably disposed in a driveshaft housing, a bend adjustment assembly coupled to the driveshaft housing, a bearing mandrel coupled to the bend adjustment assembly, and a torque control assembly including a rotor configured to couple with a drill string, a stator assembly coupled to the downhole motor, and a torque control actuator assembly configured to control the amount of torque transmitted between the rotor and the stator assembly, wherein the bend adjustment assembly includes a first position providing a first deflection angle between a longitudinal axis of the driveshaft housing and a longitudinal axis of the bearing mandrel, wherein the bend adjustment assembly includes a second position providing a second deflection angle between the longitudinal axis of the driveshaft housing and the longitudinal axis of the bearing mandrel, the second deflection angle being different from the first deflection angle.
An electric rotating machine includes a housing, a stator, and a rotor. The stator is disposed within the housing. The rotor is disposed within the housing and magnetically coupled to the stator. The rotor includes a plurality of permanent magnets attached to an outer surface of the rotor. The magnets are disposed to form a Halbach array, and the magnets are configured to provide a magnet ratio in a range of 0.7 to 0.9.
B60L 15/00 - Methods, circuits or devices for controlling the propulsion of electrically-propelled vehicles, e.g. their traction-motor speed, to achieve a desired performance; Adaptation of control equipment on electrically-propelled vehicles for remote actuation from a stationary place, from alternative parts of the vehicle or from alternative vehicles of the same vehicle train
B60L 15/20 - Methods, circuits or devices for controlling the propulsion of electrically-propelled vehicles, e.g. their traction-motor speed, to achieve a desired performance; Adaptation of control equipment on electrically-propelled vehicles for remote actuation from a stationary place, from alternative parts of the vehicle or from alternative vehicles of the same vehicle train for control of the vehicle or its driving motor to achieve a desired performance, e.g. speed, torque, programmed variation of speed
40.
LUBRICATOR ASSEMBLY AND METHOD FOR SERVICING TUBULAR MEMBERS
A lubricator assembly for servicing a tubular member includes a mounting base, a lubricant housing movably coupled to the mounting base and configured to receive lubricant from a lubricant source, a guide pin slidably disposed in the lubricant housing, a first seal positioned between the guide pin and the lubricant housing and a second seal positioned between the guide pin and the lubricant housing, and a first chamber extending between the first seal and the second seal, wherein the guide pin is configured to direct lubricant disposed in the first chamber against the tubular member in response to the tubular member engaging the guide pin.
Pump assemblies, pumping systems including said pump assemblies, and related methods are disclosed. In an embodiment, the pump assembly includes a frame, a fluid end, and a power end coupled to the frame and the fluid end. In addition, the pump assembly includes a plurality of connectors coupled between the fluid end and the frame. Each of the connectors include an axis, a first connector member, and a second connector member. The first connector member is configured to actuate relative to the second connector member to adjust a total axial length of the connector along the axis.
F04B 53/22 - Arrangements for enabling ready assembly or disassembly
F16M 1/00 - Frames or casings of engines, machines, or apparatus; Frames serving as machinery beds
F16M 1/02 - Frames or casings of engines, machines, or apparatus; Frames serving as machinery beds for reciprocating engines or similar machines
F16M 7/00 - FRAMES, CASINGS OR BEDS OF ENGINES, MACHINES OR APPARATUS, NOT SPECIFIC TO ENGINES, MACHINES OR APPARATUS PROVIDED FOR ELSEWHERE; STANDS; SUPPORTS - Details of attaching or adjusting engine beds, frames, or supporting-legs on foundation or base; Attaching non-moving engine parts, e.g. cylinder blocks
F16M 11/04 - Means for attachment of apparatus; Means allowing adjustment of the apparatus relatively to the stand
42.
PUMP ASSEMBLIES AND PUMPING SYSTEMS INCORPORATING PUMP ASSEMBLIES
A pump assembly (100) includes a power end (109) including an output shaft (118) having an output shaft axis (115). The pump assembly includes a fluid end (60) including a piston (64) configured to reciprocate to pressurize the working fluid. Further, the pump assembly includes a transmission (120) coupled to each of the power end (109) and the fluid end (60). The transmission includes a carriage (150) coupled to the piston and a pivoting arm (144) pivotably coupled to the carriage at a first connection about a first pivot axis (143"). The first pivot axis extends in a perpendicular direction to a direction of the output shaft axis, and rotation of the output shaft about the output shaft axis is configured to cause the pivoting arm to pivot about the first pivot axis at the first connection and to cause the carriage to reciprocate (151).
F04B 23/06 - Combinations of two or more pumps the pumps being all of reciprocating positive-displacement type
E21B 21/00 - Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
F04B 1/14 - Multi-cylinder machines or pumps characterised by number or arrangement of cylinders having cylinder axes coaxial with, or parallel or inclined to, main shaft axis having stationary cylinders
F04B 9/02 - Piston machines or pumps characterised by the driving or driven means to or from their working members the means being mechanical
F04B 15/02 - Pumps adapted to handle specific fluids, e.g. by selection of specific materials for pumps or pump parts the fluids being viscous or non-homogeneous
An end effector (400) for a robotic arm, the end effector (400) comprising: two pipe engaging jaws (404), each jaw comprising an inner contour configured for engaging a pipe section, wherein at least one jaw (404) is a fixed jaw; wherein the end effector (400) is configured to restrict radial movement of the pipe section while permitting axial movement.
E21B 19/087 - Apparatus for feeding the rods or cables; Apparatus for increasing or decreasing the pressure on the drilling tool; Apparatus for counterbalancing the weight of the rods by means of a swinging arm
44.
DEVICES, SYSTEMS, AND METHODS FOR ROBOTIC PIPE HANDLING
A pipe handling system including a lifting system for handling a load of a pipe stand, a pipe handling robot (116a, 116b) configured for engaging with the pipe stand (110) and manipulating a position of the pipe stand (110), and a feedback device configured to provide information about a condition of the pipe stand, the lifting system, or the pipe handling robot (116a, 116b). In some embodiments, the pipe handling robot (116a) may be a first robot configured for engaging with and manipulating a first end of the pipe stand, and the system may include a second pipe handling robot (116b) configured for engaging with and manipulating a second end of the pipe stand (110).
Optimizing performance of an automated control system for drilling may include obtaining instructions to deploy a plurality of event-driven drilling activities comprising a drilling process, obtaining default parameters for a first instance of a first activity of the event-driven drilling activities, deploying the first activity of the drilling activities using the default parameters, comprising performing signal analysis on signal data from one or more sensors utilized for the first activity. Optimizing performance of an automated control system for drilling may also include detecting a trigger for a first instance of a second activity using the default parameters, and determining a trigger signature based on the signal analysis when the trigger for the first instance of the second activity is detected, wherein, when a second instance of the first activity is deployed, the trigger signature is utilized to trigger the deployment of a second instance of the second activity.
E21B 44/00 - Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systems; Systems specially adapted for monitoring a plurality of drilling variables or conditions
A drilling system includes a drill string, a plurality of sensors, and a computing system. The drill string includes a downhole motor. The sensors are coupled to the drill string. The computing system is coupled to the sensors. The computing system is configured to compute, based on measurements provided by the sensors, a motor stall index, and to determine, by comparing the motor stall index to a motor stall threshold, whether the downhole motor has stalled. The computing system is also configured to, responsive to a determination that the downhole motor has stalled, adjust operation of the drill string to restart the downhole motor.
E21B 44/00 - Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systems; Systems specially adapted for monitoring a plurality of drilling variables or conditions
A cutting element (101) for a drill bit (112) includes a PCD cutting face (328) having a ridge (332) that extends away from the periphery towards the center of the cutting face, terminating in a curved, central most ridge end (339). The cutting face further includes a surrounding surface (336) consisting of the entire cutting face except for the ridge. The surrounding surface is free of flats and includes two side regions (330a, 330b) and a ramp region (334) therebetween. The surrounding surface (336) is continuously curved along a curved path that extends from the first side region to the ramp region to the other side region. In profile views, the surrounding surface may be linear moving from the top surface of the ridge to the periphery at every location along the curved path.
E21B 10/42 - Rotary drag type drill bits with teeth, blades or like cutting elements, e.g. fork-type bits, fish tail bits
E21B 10/46 - Drill bits characterised by wear resisting parts, e.g. diamond inserts
E21B 10/54 - Drill bits characterised by wear resisting parts, e.g. diamond inserts the bit being of the rotary drag type, e.g. fork-type bits
E21B 10/55 - Drill bits characterised by wear resisting parts, e.g. diamond inserts the bit being of the rotary drag type, e.g. fork-type bits with preformed cutting elements
Pipelay reel systems and methods for use in laying flexible or rigid pipe (210) or tubing in on and offshore operations. The pipelay reel system has a pipelay reel (202) having a drum (204) arranged between two flanges (206). At least one flange of the reel has a chute (208) configured to receive an adapter (220) coupled to a starting end of the pipe (210) to be spooled on the reel (202). An initiation line (212) coupled to a winch and intersecting the flange chute may be used to position the adapter (220) with respect to a receiving end of the flange chute (208), and the reel may be rotated to pull the adapter down the chute (208) to a latching end of the chute. Moreover, a latch (234) may be used to secure the adapter (220) in the chute (208) such that the pipe (210) may be spooled onto the reel (202).
An overpressure control apparatus is used to control jets of high-pressure fracking fluid or other stimulation fluid released from a treatment flowline in cases of overpressure. The apparatus includes a collection tank and one or more valves, which can all be mounted on or integrated to a skid. The sizes and weights of the collection tank and the skid may help to keep the apparatus on the ground during an overpressure event. The apparatus can be provided with an offline testing system that allows an operator to close off the communication between the apparatus and the treatment flowline, and instead, pump a clean fluid such as water at high-pressure to test the proper functioning of the valve.
F16K 3/02 - Gate valves or sliding valves, i.e. cut-off apparatus with closing members having a sliding movement along the seat for opening and closing with flat sealing faces; Packings therefor
E21B 33/068 - Well heads; Setting-up thereof having provision for introducing objects or fluids into, or removing objects from, wells
E21B 34/02 - Valve arrangements for boreholes or wells in well heads
E21B 34/08 - Valve arrangements for boreholes or wells in wells responsive to flow or pressure of the fluid obtained
E21B 34/16 - Control means therefor being outside the borehole
E21B 43/26 - Methods for stimulating production by forming crevices or fractures
A system includes a string disposed in a wellbore, a first valve coupled to the string, the first valve including a sleeve having an engagement profile with a first coded sequence, a second valve coupled to the string, the second valve including a sleeve having an engagement profile with a second coded sequence that differs from the first coded sequence of the first valve, and a first dart flow transportable through the string, the first dart including a collet finger having a first coded sequence configured to restrict the collet finger from matingly engaging the engagement profile of the first valve while permitting the collet finger to engage the engagement profile of the second valve, wherein the first dart actuates the sleeve of the second valve between first and second positions in response to the collet finger of the first dart matingly engaging the engagement profile of the second valve.
E21B 34/14 - Valve arrangements for boreholes or wells in wells operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools
E21B 34/00 - Valve arrangements for boreholes or wells
E21B 34/06 - Valve arrangements for boreholes or wells in wells
E21B 34/10 - Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole
A reciprocating pump system includes a reciprocating pump including a fluid end configured to receive a suction fluid flow and discharge a discharge fluid flow, and a suction booster assembly coupled to the fluid end, the suction booster assembly including a venturi including a venturi passage, and a jet configured to jet a fluid received from the discharge of the fluid end into the venturi passage, wherein the suction booster assembly is configured such that the jet of the suction booster assembly jetting the fluid into the venturi passage increases the pressure of the suction fluid flow.
A method for optimizing performance of a drilling process by an automated control system for drilling, comprising obtaining a measure of performance for each drilling activity of a set of drilling activities for the drilling process; calculating an activity performance index for each drilling activity by obtaining reference data for each drilling activity, comparing the measures of performance for each drilling activity to the reference data for the particular drilling activity, calculating the activity performance index for each drilling activity based on the comparison; generating a drilling process performance index based on the activity performance indexes; comparing, for each of the drilling activities, a configuration of one or more drilling parameters to a reference configuration of drilling parameters associated with the reference data for the particular drilling activity; and adjusting the configuration of one or more drilling parameters associated with one or more drilling activities based on the comparison.
Automated drilling may include receiving a tool-agnostic request to perform a process, determining one or more activities to complete the process, identifying a controller module associated with a first activity of the one or more activities, and triggering the controller module to initiate the first activity, wherein the controller module identifies and directs one or more drilling tools to initiate the first activity.
E21B 44/00 - Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systems; Systems specially adapted for monitoring a plurality of drilling variables or conditions
Tagging bottom utilizing an automated control system and downhole tools may include determining, by a computer processor, that a drill bit has reached a predetermined distance from a bottom of a wellbore, in response to determining that the bit has reached the predetermined depth, transmitting a rate of penetration set point to reduce a lowering speed of the drill bit, directing the drill bit based on the rate of penetration, determining, by the computer processor, that the rate of penetration is stable, in response to the determining that the rate of penetration has stabilized, automatically taring a surface weight on the drill bit and a differential pressure, and in response to determining that the bit is within a predetermined off bottom range, monitoring for a true bottom based on one or more parameter triggers.
E21B 44/00 - Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systems; Systems specially adapted for monitoring a plurality of drilling variables or conditions
E21B 7/00 - Special methods or apparatus for drilling
E21B 43/26 - Methods for stimulating production by forming crevices or fractures
E21B 44/04 - Automatic control of the tool feed in response to the torque of the drive
E21B 45/00 - Measuring the drilling time or rate of penetration
The present disclosure relates to novel and advantageous devices, systems, and methods for stabilizing a coiled tubing guide extending from a coiled tubing unit. Stabilization of the guide may mitigate movement of the guide from lateral operational forces. The guide may be stabilized by clamping or anchoring a connection point between the guide and the unit, such as between the guide and a coiled tubing injector frame or a tubing guide mount coupled to the coiled tubing injector frame. In general, a clamp or other mechanism may operate to preload the pinned connection with a prescribed force. The direction of the force may be perpendicular, or near perpendicular, to an axis of rotation about which lateral loading on the guide causes moment forces.
An active limiting switch includes a comparator (312) and a power switch (212). The comparator is configured to compare a reference voltage (354) with a sense voltage (352). The sense voltage is representative of a proportional approximation to power in a load (108) being driven by a battery (102). The power switch is configured to be, in response to the reference voltage being less than the sense voltage, in an open state. The power switch is also configured to be, in response to the reference voltage being greater than the sense voltage, in a closed state creating a closed circuit between the battery and the load allowing the battery to provide a first amount of power to the load.
H02H 3/38 - Emergency protective circuit arrangements for automatic disconnection directly responsive to an undesired change from normal electric working condition, with or without subsequent reconnection responsive to phase angle between voltage and current
H02H 9/00 - Emergency protective circuit arrangements for limiting excess current or voltage without disconnection
H02H 9/02 - Emergency protective circuit arrangements for limiting excess current or voltage without disconnection responsive to excess current
H02H 9/04 - Emergency protective circuit arrangements for limiting excess current or voltage without disconnection responsive to excess voltage
A sliding sleeve valve for use in a borehole includes an outer housing including a radial housing slot, a sliding sleeve slidably disposed in the outer housing, the sliding sleeve including a radial sleeve slot and configured to have a first position that restricts fluid communication between the sleeve slot and the housing slot and a second position, spaced from the first position, that permits fluid communication between the sleeve slot and the housing slot, an actuator housing coupled to the outer housing, wherein the actuator housing includes an actuator chamber defined by an inner surface, and wherein the actuator chamber is disposed between an inner surface and an outer surface of the actuator housing, and an actuator assembly disposed in the actuator chamber, wherein the actuator assembly is configured to control movement of the sliding sleeve between the first and second positions.
A system for handling pipes on a drilling rig includes an elevator suspended from a stand transfer vehicle, a top drive or other lifting device of a drilling rig. The system also includes a rig-floor pipe lifting machine (10) including a fork (14) sized to engage a tool-joint (110) of a pipe. A navigation system includes a controller that can be programmed to autonomously drive the rig-floor pipe lifting machine.
A sealing apparatus includes a moveable seal holder with a cavity and includes a seal assembly disposed at least partially m the cavity The seal assembly includes a resilient seal member including a fluid-facing end with a fluid-facing end surface, and the seal assembly includes an actuator plate configured to reciprocate between a first and a second position relative to the protective plate The first actuator plate includes a fluid-facing end surface and a first camming surface The seal assembly further includes a first protective plate disposed between the seal member and the first actuator plate The actuator plate is configured to compress the seal member and to move the fluid-facing end surface of the seal member outward from a resting position when the actuator plate is in the second position
An intermitter valve for controlling the flow rate and/or pressure of a fluid produced from a well drilled into an oil and gas reservoir includes several seals between a seat connected to the valve body and a sleeve connected to a reciprocating stem. An O-ring disposed in an inner groove of the sleeve can be used to intermittently form an elastomer-to-metal seal against the seat. An O-ring disposed in an outer groove of the seat can be used to intermittently form an elastomer-to-metal seal against the sleeve. A surface proximate to the end of the sleeve can be used to intermittently form a metal-to-metal seal against a surface of the seat. The seat and the sleeve can be part of a valve kit for converting a production choke valve into a flow shut-off device.
F16K 17/32 - Excess-flow valves actuated by the difference of pressure between two places in the flow line acting on a servo-mechanism or on a catch-releasing mechanism
A drilling tool includes a pilot bit coupled to an eccentric reamer that has a reaming side and a stabilizing side. A fluid passageway extends between the reamer and the pilot bit, and the tool includes at least one upwardly-directed nozzle in fluid communication with the fluid passageway and positioned on the stabilizing side of the reamer. The reamer may include a plurality of angularly spaced blades on the reaming side that radially extend a first distance, the reamer blades being disposed within a first arcuate segment defined by the two most distant reamer blades. One or more stabilizing blades extend a second distance that is less than the first distance, the stabilization blades being disposed within a second arcuate segment defined by the two most distant reamer blades and that has the angular measure equal to 360 degrees minus the first arcuate segment.
A lifting mast assembly includes telescoping load bearing arms pivotably coupled to a support base and configured to pivot in unison. Each telescoping arm includes a first arm section and an aligned second arm section. The first arm sections are configured to telescope in unison with one another. Likewise, the second arm sections are configured to telescope in unison with one another. Each first arm section may telescope independently of the second arm section with which it is coaxially aligned. A first support member is coupled to each of the first arm sections, and a second support member is coupled to each of the second arm sections. Different loads can be supported on the first and second support members simultaneously.
A shock tool (120) for reciprocating a drillstring (20) includes an outer housing (130) and a mandrel assembly (150) coaxially disposed in the outer housing (130). The outer housing (130) has a radially inner surface (132) including a plurality of circumferentially-spaced splines (134). The mandrel assembly (150) includes a mandrel (160) having a radially outer surface (161) including a plurality of circumferentially-spaced splines (166) and a plurality of circumferentially-spaced troughs (168). Each spline (134) of the outer housing (130) is disposed in one trough (168) of the mandrel (160). Each spline (166) of the mandrel (160) includes a top surface (166e), a first lateral side surface (166g) extending radially from the top surface (166e), a second lateral side surface (166f) oriented parallel to the first lateral side surface (166g), and a bevel (166h) extending from the top surface (166e) to the second lateral side surface (166f). Each spline (166) of the mandrel (160) also includes a pocket (166j) in the second lateral side surface (166f) extending radially from a bottom surface (168a) of a trough (168) to the bevel (166h).
A snubbing jack including a jack assembly including a base plate, a traveling plate, an axis extending through the base plate and the traveling plate, and a plurality of piston-cylinder assemblies, a rotary drive including a rotary base and a hub, wherein the rotary drive is configured to rotate the hub relative to the rotary base, a clamp coupled to the rotary base and configured to grip a first tubular member, a power tongs coupled to the rotary base and configured to grip a second tubular member and to rotate the second tubular relative to the rotary base, and a torque transfer device coupled between the rotary drive and the jack assembly and configured to allow the rotary drive to move axially relative to the base plate and configured to restrict rotation of the rotary drive relative to the jack assembly.
E21B 19/08 - Apparatus for feeding the rods or cables; Apparatus for increasing or decreasing the pressure on the drilling tool; Apparatus for counterbalancing the weight of the rods
E21B 19/06 - Elevators, i.e. rod- or tube-gripping devices
A door assembly for a pressure vessel includes a door, a hub for receiving the door, and an annular seal to seal therebetween. A hinge arm is coupled to the hub and to the door and is pivotable relative to the hub about a hinge axis. A door actuator having an elongate member extending along an actuator axis is spaced-apart from the hinge axis and coupled to the hub and to the hinge arm. The elongate member travels with the hinge arm when the arm pivots relative to the hub, and rotates about the actuator axis.
A tubing hanger for supporting a tubing string from a wellhead includes a unified mandrel having an upper mandrel coupled to an axially aligned lower mandrel by multiple separate connections. The upper mandrel includes an external shoulder, and a lower mandrel includes a threaded segment configured to couple to the tubing string. The first connection is configured to restrain axial movement between the upper and lower mandrel and to transfer toque between the upper mandrel and the lower mandrel in at least a first rotational direction. The second connection is configured to transfer toque between them in at least a second rotational direction opposite the first rotational direction, to prevent the first connection from loosening.
E21B 33/04 - Casing heads; Suspending casings or tubings in well heads
E21B 19/08 - Apparatus for feeding the rods or cables; Apparatus for increasing or decreasing the pressure on the drilling tool; Apparatus for counterbalancing the weight of the rods
E21B 19/16 - Connecting or disconnecting pipe couplings or joints
68.
APPARATUS, SYSTEM, AND METHOD FOR SEPARATING OIL FROM A FLUID MIXTURE
A system and method for extracting oil from a fluid mixture includes a separation vessel having an internal chamber that extends to a chamber elevation, an inlet port, a water outlet port, and an oil outlet port. A liquid storage tank has an inlet port, an upper outlet port located at an upper outlet elevation, and a lower outlet port. A first conduit system interconnects the separation vessel's water outlet port and the tank's inlet port and has a top conduit segment at the upper outlet elevation. A second conduit system interconnects the first conduit system and the tank's inlet port. The second conduit system intersects the first conduit system below the upper outlet elevation and above the chamber elevation. A pump may be employed to transfer fluid from the upper outlet port back to the separation vessel.
A valve retainer assembly and pump including the same. In an embodiment, the valve retainer assembly includes a retainer configured to engage with a suction valve assembly and retain the suction valve assembly within a chamber of a fluid section of a reciprocating pump. The retainer includes a pair of engagement arms extending along a single arm axis, and a connecting member including a coupling aperture. In addition, the valve retainer assembly includes a keeper that further includes a keeper axis, and a connecting shaft. The connecting shaft of the keeper is received within the coupling aperture such that the keeper axis extends in a direction that is perpendicular to the arm axis.
A mast erection system includes a first mast erection apparatus (314) that is adapted to pivotably raise a drilling rig mast (330) of a drilling rig assembly (300) to an intermediate raised position wherein the drilling rig mast (330) is oriented at a first acute angle (370) relative to a horizontal plane (380), and a second mast erection apparatus (320) that is adapted to further pivotably raise the drilling rig mast (330) from the intermediate raised position at the first acute angle (370) to a fully raised position wherein the drilling rig mast (330) is oriented at a second angle (372) relative to the horizontal plane (380) that is greater than the first acute angle (370).
A washpipe assembly for a power swivel and a power swivel incorporating the washpipe assembly. In an embodiment, the washpipe assembly includes a washpipe including a central axis and a radially outermost cylindrical surface. In addition, the washpipe assembly includes a first packing assembly configured to be coupled to a stem of the power swivel. The first packing assembly includes a seal assembly that includes one or more annular seal members each including a body and a contact insert mounted to the body, the contact insert engaging and forming a dynamic seal with the radially outermost cylindrical surface of the washpipe.
A system and method for recovering drilling fluid from shaker tailings includes a hopper and a cover that is pivotable between a first position in which the hopper is uncovered and a second position in which the hopper is covered. In the first position, the hopper receives the tailings, which are pumped via a low shear pump to a centrifuge. The drilling fluid extracted in the centrifuge is stored in a holding tank. In the second position, the cover is angled with respect to the direction of gravity so as to divert shaker tailings from being received in the hopper. Some fluid from the holding tank is sprayed into the hopper through nozzles to convey the deposited tailings toward the pump. A level detector senses the level of the mixture in the hopper, and an associated control system controls the pump speed and the cover position to control the operation.
A drilling rig (400) having a detachable, modular cellar arranged beneath a drill floor of the drilling rig. The cellar may be or include a cellar trailer (100) and may be configured to house drilling equipment, such as well head equipment, such as one or more blowout preventers (125). In some embodiments, the cellar trailer may provide work areas, such that the well head equipment may be prepared, tested, or generally operated within the cellar trailer. The cellar trailer may additionally be configured to provide stiffening support to the drill floor in order to mitigate deflection of the drill floor during drilling operations. The stiffening support may be provided by a shear wall (108) extending from the cellar trailer. The cellar trailer may be towable. The cellar trailer may additionally be skiddable and/or walkable.
A fluid separation apparatus includes a hydrocyclone (100) having an orifice (134) therein, a housing (202) disposed in the hydrocyclone and having a bore (204), a piston (240) disposed in the bore (204) of the housing (202), and a first annular seal (248) disposed between the housing (202) and the piston (240) and configured to restrict fluid communication between the housing (202) and the piston (240), wherein the piston (240) includes a passage (242) extending through the piston (240) and having a pin (254) coupled to a first end (240a) of the piston, the piston (240) being actuatable to move between a first position (260) where the pin (254) is clear of the orifice (134) of the hydrocyclone, and a second position where the pin (254) is disposed in the orifice (134), wherein, the piston (240) is configured such that as the piston is actuated from the first position to the second position, fluid is permitted to flow into the passage (242) of the piston (240) from the bore (204) of the housing (202).
The present disclosure, in one or more embodiments, relates to a drilling rig with a self-elevating drill floor. The drilling rig may have one or more jacking systems that may operate to raise the drill floor. The one or more jacking systems may raise the drill floor to a height sufficient to accommodate a substructure such as a substructure box. A substructure box may be placed, and the one or more jacking systems may lower the drill floor onto the substructure box. Substructure boxes may be placed beneath the drill floor, using the one or more jacking systems, until a desired drill floor height is reached. In some embodiments, the one or more jacking systems may additionally operate to move the drilling rig, for example between adjacent wells on a pad drilling site. The jacking systems may operate to move the drilling rig using walking feet or another mechanism.
E21B 15/00 - Supports for the drilling machine, e.g. derricks or masts
B62D 57/02 - Vehicles characterised by having other propulsion or other ground-engaging means than wheels or endless track, alone or in addition to wheels or endless track with ground-engaging propulsion means, e.g. walking members
B65G 7/02 - Devices adapted to be interposed between loads and the ground or floor, e.g. crowbars with means for assisting conveyance of loads
B66F 11/00 - Lifting devices specially adapted for particular uses not otherwise provided for
The present disclosure, in one or more embodiments, relates to a drilling rig with a self-elevating drill floor. The drilling rig may have one or more jacking systems that may operate to raise the drill floor. The one or more jacking systems may raise the drill floor to a height sufficient to accommodate a substructure such as a substructure box. A substructure box may be placed, and the one or more jacking systems may lower the drill floor onto the substructure box. Substructure boxes may be placed beneath the drill floor, using the one or more jacking systems, until a desired drill floor height is reached. In some embodiments, the one or more jacking systems may additionally operate to move the drilling rig, for example between adjacent wells on a pad drilling site. The jacking systems may operate to move the drilling rig using walking feet or another mechanism.
The invention relates to a pumping system with connectable and disconnectable pumping assemblies coupled between the suction manifold and discharge manifold. The system comprises one or more pump assemblies including one or more pressures sensors and the pump assemblies are configured to draw the working fluid from the suction manifold, pressurize the working fluid and to discharge the working fluid to the discharge manifold. The system also comprises a controller coupled to the pumping system and including one or more circuits configured to adjust a rotational speed of the driver in response to a pressure pulsation detected by at least one of the pressure sensors and to adjust a volume of the variable volume chamber of the pulsation dampening assembly based at least in part of the measurement from the at least one of the pressure sensors.
F04B 9/02 - Piston machines or pumps characterised by the driving or driven means to or from their working members the means being mechanical
F04B 11/00 - Equalisation of pulses, e.g. by use of air vessels; Counteracting cavitation
F04B 15/02 - Pumps adapted to handle specific fluids, e.g. by selection of specific materials for pumps or pump parts the fluids being viscous or non-homogeneous
F04B 23/06 - Combinations of two or more pumps the pumps being all of reciprocating positive-displacement type
F16H 23/08 - Wobble-plate gearings; Oblique-crank gearings with non-rotary wobble-members connected to reciprocating members by connecting-rods
78.
BLOWOUT PREVENTER WITH INTERLOCKING RAM ASSEMBLY AND METHOD OF USING SAME
A ram assembly is disclosed. The ram assembly includes a ram wedge, a blade, and a ram seat. The ram wedge has a tubular cavity therethrough for receiving the tubular. The ram wedge is slidably positionable in the ram channel between a retracted and an extended position, and has rails extending therefrom. The blade is positionable about the tubular cavity, the blade carried by the ram wedge to cuttingly engage the tubular. The ram seat is positionable in the housing about the passage, and has a hole for receiving the tubular therethrough. The ram seat also has an outer surface interlockingly engageable with the rails as the ram wedge moves relative thereto whereby a gap is reduced therebetween.
A lubrication system includes a pair of mating surfaces subject to relative motion and a source of lubrication in communication with the mating surfaces. A microfluidic channel system including at least one diffuser element is disposed in an interface between the mating surfaces to create a coherent fluid film at the interface in response to the relative motion.
B05D 3/10 - Pretreatment of surfaces to which liquids or other fluent materials are to be applied; After-treatment of applied coatings, e.g. intermediate treating of an applied coating preparatory to subsequent applications of liquids or other fluent materials by other chemical means
B05D 3/12 - Pretreatment of surfaces to which liquids or other fluent materials are to be applied; After-treatment of applied coatings, e.g. intermediate treating of an applied coating preparatory to subsequent applications of liquids or other fluent materials by mechanical means
A system (10) for drilling a subterranean borehole (20). In an embodiment, the system includes a mast (12), and a pipe rotator (50) coupled to the mast. The pipe rotator includes a stem (52) that is configured to be coupled to an end of a drillstring (30) and a motor (51) that is configured to rotate the stem. In addition, the system includes a guide beam (150) coupled to the mast. The guide beam includes a longitudinal axis and is configured to guide vertical motion of the pipe rotator. The guide beam includes a plurality of elongate sections (151, 152, 153) configured to be generally aligned along the longitudinal axis. In addition, the guide beam includes a plurality of coupling assemblies configured to interconnect the plurality of elongate sections and align the plurality elongate sections along the longitudinal axis.
A gooseneck (100) and a power swivel (10) including a gooseneck (100) are disclosed. In an embodiment, the gooseneck includes an inlet section (120) including an inlet (124) and a first fluid flow path (170) extending from the inlet. In addition, the gooseneck includes an outlet section (150) coupled to the inlet section. The outlet section includes an outlet (156). In addition, the outlet section (150) includes a second fluid flow path (160) extending axially from the outlet. The second fluid flow path is in fluid communication with the first fluid flow path. Further, the outlet section includes a radially outer surface (150c) that includes a first polygonal section having a plurality of planar surfaces (166) joined at a plurality of comers (168).
A power swivel (10) 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 (12), a gear box (16) coupled to the motor, and a lubrication system (100) coupled to the gear box. The lubrication system includes a pump (120) disposed within the gear box, the pump including an outlet (126). In addition, the lubrication system includes a recirculation line (130) fluidly coupled to the outlet of the pump. Further, the lubrication system includes a first injector (148) fluidly coupled to the recirculation line. The injector is configured to deliver lubricant to one of a bearing (145) and a gear (147) disposed within the gear box.
A magnetic cycloid gear assembly includes an outer magnet drum comprising a plurality of outer drum magnets having a first number of magnetic pole pairs. The assembly also includes a first inner magnet drum comprising a first plurality of inner drum magnets having a second number of magnetic pole pairs. The assembly also includes a second inner magnet drum comprising a second plurality of inner drum magnets having a third number of magnetic pole pairs. Each of the first and second inner drums has an inner magnet drum axis that is offset from an outer magnet drum axis. The assembly further includes a plurality of drive mechanisms, each mechanism being operatively coupled to each of the first and second inner drums. The plurality of drive mechanisms is configured to drive each of the first and second inner magnet drums to revolve in an eccentric manner about the outer drum axis.
A pipe handler for handling tubular members of a well system includes a mounting member for mounting the pipe handler to a structure of the well system, a first arm having a first end coupled to a structure of the well system, and a second end, wherein the first arm is configured to pivot relative to the mounting member about a first axis, a second arm having a first end and a second end, a connector coupled to the second end of the first arm and the first end of the second arm, and wherein the connector is configured to rotate the second arm about a second axis and a guide member coupled to the second end of the second arm for guiding a tubular member, wherein the second arm is configured to pivot relative to the connector about a third axis.
E21B 19/08 - Apparatus for feeding the rods or cables; Apparatus for increasing or decreasing the pressure on the drilling tool; Apparatus for counterbalancing the weight of the rods
E21B 19/14 - Racks, ramps, troughs or bins, for holding the lengths of rod singly or connected; Handling between storage place and borehole
E21B 19/16 - Connecting or disconnecting pipe couplings or joints
85.
APPARATUS, SYSTEMS AND METHODS FOR MULTI-STAGE STIMULATION
Embodiments of a sleeve assembly, used for stimulating multiple stages in a completion string has a lower shifting sleeve and an upper shifting sleeve and stimulation ports formed therebetween. The sleeves are caused to shift by progressively larger objects pumped through a bore of the completion string and engaging seats formed thereon. The seat on the lower sleeve is a releasable seat. When shifted the lower sleeve opens the stimulation ports. The seat on the upper sleeve is sized to accept the same size object as is required to engage and shift the lower sleeve on the stage uphole therefrom to close the ports. Thereby, stimulation ports are opened and closed without increasing a number of objects required to stimulate the wellbore. Further, as the ports at each stage below the stage being stimulated are closed, the objects are not required to isolate the bore therebelow.
E21B 34/14 - Valve arrangements for boreholes or wells in wells operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools
A flow responsiveness enhancer apparatus may include a stack of manifolds with at least one manifold dedicated to each of the rams of the blowout preventer. The flow responsiveness enhancer includes a shared pressure line coupled to each of the manifolds, and a shared tank line coupled to each of the manifolds. Each manifold can include a 4-way directional valve that is piloted by the pressure levels in a pair of input ports. Each 4-way directional valve can couple the shared pressure line and the shared tank line to a pair of output ports.
E21B 34/16 - Control means therefor being outside the borehole
F15B 3/00 - Intensifiers or fluid-pressure converters, e.g. pressure exchangers; Conveying pressure from one fluid system to another, without contact between the fluids
A handler holds a blowout preventer (BOP) assembly (partially or fully assembled) for transport and then erects it from a transport position to a vertical position for deployment. In the transport position the BOP assembly generally rests in a horizontal position. During deployment of the BOP assembly by the handler, the handler is capable of moving the BOP assembly to a vertical position, elevating it, and moving it outward, away from the base of the handler and toward a wellhead, so that the BOP assembly may be connected to a coiled tubing injector, work may be performed underneath the BOP assembly before connection to a well head, and the BOP assembly may be placed on top of a well head for connection to the well head.
A tubular member (50) having a longitudinal axis (55), a first end (60), and a second end (80) is disclosed. The tubular member includes a pin connector including an external shoulder (62), an internal shoulder (64) axially spaced from the external shoulder, and a plurality of threads (68) in a region between the external shoulder and the internal shoulder that taper relative to the longitudinal axis at 1.0 to 1.5 inches per foot. The threads include an axial density measured in a number of threads per inch (TPI), and when the pin connector is threadably engaged with a box connector, each of the threads contacts a corresponding box thread on the box connector along a projected radial distance Hc. In addition, the threads are configured such that the product of 2(v3)(H c )(TPI) is greater than or equal to 0.95 and less than or equal to 1.05.
Embodiments of systems and methods to control directional drilling in borehole drilling for hydrocarbon wells are disclosed. An actual toolface orientation measurement value and an actual downhole torque on bit (DTOB) or actual downhole weight on bit (DWOB) measurement value for a drill string positioned in a borehole are determined. Responsive to a comparison of target measurement values and actual measurement values, error values are determined. A control command for one or more of a top drive, a drawworks, and a mud pump responsive to the DTOB or DWOB error value and the toolface orientation error value is determined. Additionally, one or more of the top drive, the drawworks, and the mud pump are operated responsive to the control command thereby to correct a toolface orientation of the drill string.
A coiled tubing handler lifts a support platform upon which a coiled tubing injector is mounted, and extends the platform outwardly over a wellhead at a well site. The handler is collapsible into a compact arrangement that allows it and the coiled tubing injector to be transported to a well site on a vehicle or trailer. The handler can be used at the well site to raise, position, and support the coiled tubing injector, along with a BOP and riser assembly suspended from the coiled tubing injector, for connecting the BOP and riser assembly to the wellhead. The support platform may be tilted backward and forward, shifted from side-to- side, and raised and lowered.
A safety joint designed to prevent hydrostatic locking is made up by assembling a pin end having a first seal, a threaded connection, and a movable second seal to a box end. The movable seal is disposed in a recess formed in the pin end and includes an O-ring and a spring. When the safety joint is assembled downhole, a volume of fluid may become trapped between the first seal and the second seal. The trapped fluid in turn pushes the O-ring towards the spring, thereby limiting pressure build-up by substantially maintaining the volume trapped between the first and second seals.
A rotator mechanism for rotating an elongate member in a pumping system includes a body member (180) having a longitudinal body axis (161) and a through-hole aligned with the body axis and configured to receive the elongate member. The rotator mechanism also includes a worm gear (190) concentric with the body axis and a worm (195) meshing with the worm gear. The rotator mechanism includes a lever (164) configured to rotate the worm, and a clutch (254) coupled between the lever and the worm and configured to cause the worm to rotate in a first direction when the lever moves in the first direction. Rotation of the worm (195) causes the worm gear and the elongate member to rotate about the body axis.
F16H 37/12 - Gearings comprising primarily toothed or friction gearing, links or levers, and cams, or members of at least two of these three types
E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
F04B 47/00 - Pumps or pumping installations specially adapted for raising fluids from great depths, e.g. well pumps
F16H 19/08 - Gearings comprising essentially only toothed gears or friction members and not capable of conveying indefinitely-continuing rotary motion for interconverting rotary motion and oscillating motion
F16H 31/00 - Other gearings with freewheeling members or other intermittently-driving members
93.
WIPER SEAL ASSEMBLIES FOR A RECIPROCATING PUMP AND METHODS RELATING THERETO
A wiper seal assembly for a reciprocating pump, the pump including a power section configured to be powered by a motor, a fluid section having an inlet and an outlet, and a plunger having a longitudinal plunger axis, a first end coupled to the power section, and a second end opposite the first end and disposed within the fluid section. The wiper seal assembly includes a cover mounted to the power section. In addition, the wiper seal assembly includes a first wiper seal radially disposed between the cover and the plunger. Further, the wiper seal assembly includes a splash guard disposed about the plunger and axially spaced from the cover. Still further, the wiper seal assembly includes a biasing member axially biasing the splash guard away from the first wiper seal.
F04B 53/02 - Packing the free space between cylinders and pistons
F04B 39/00 - Component parts, details, or accessories, of pumps or pumping systems specially adapted for elastic fluids, not otherwise provided for in, or of interest apart from, groups
F16J 15/56 - Other sealings for reciprocating rods
A driveshaft assembly (100) includes a driveshaft (120) with a shaft axis (125), a first end (120a), and a radially outer surface. The first end includes a plurality of recesses (124) extending radially inward from the radially outer surface and each including an engagement surface (126). The driveshaft assembly also includes an end housing (130) with a receptacle (146) including a plurality of planar receptacle surfaces. Further, the driveshaft assembly includes a torque transfer assembly (185) including a plurality of torque transfer keys (190) each with a planar key surface (194) and a convex key surface (196), and an adapter (200) including a plurality of concave adapter surfaces (212) and a plurality of planar adapter surfaces. The engagement surface of the each recess engages the planar key surface of one of the keys. The convex key surface of each key engages one of the concave adapter surfaces. Each of the planar adapter surfaces of the adapter engage with one of the receptacle surfaces.
F16D 3/20 - Universal joints in which flexibility is produced by means of pivots or sliding or rolling connecting parts one coupling part entering a sleeve of the other coupling part and connected thereto by sliding or rolling members
95.
CLOSED LOOP DRILLING MUD COOLING SYSTEM FOR LAND-BASED DRILLING OPERATIONS
A drilling mud cooler (230) includes a first mud heat exchanger (232a) that is adapted to receive a flow of drilling mud (210y), a first closed-loop cooling system (250) that is adapted to cool a first cooling fluid (260) that is circulated through the first mud heat exchanger (232a) so as to reduce a temperature of the flow of drilling mud (210y) from a first temperature to a second temperature, a second mud heat exchanger (232b) that is adapted to receive the flow of reduced temperature drilling mud (210y) from the first mud heat exchanger (232a), and a second closed-loop cooling system (270) that is adapted to cool a second cooling fluid (280) that is circulated through the second mud heat exchanger (232b) so as to further reduce the temperature of the flow of drilling mud from the second temperature to a third temperature.
A sheave may include a body portion with a circular circumference and defining a center plane, a bore extending through the body portion and configured for receiving a shaft and allowing the body portion to rotate in the center plane, and a rope groove arranged on the circular circumference, wherein, the body portion comprises a structured profile.
A powered reamer comprising a stationary assembly having a flow bore therethrough. A rotating assembly is disposed about the stationary assembly and one or more cutting structures are coupled to an outer surface of the rotating assembly. A flow restriction is disposed within the flow bore so as to divert a portion of fluid flowing through the flow bore through an outlet from the flow bore into an annulus between the stationary assembly and the rotating assembly. A power section is formed in the annulus between the stationary assembly and the rotating assembly. The power section operates to eccentrically rotate the rotating assembly about the stationary assembly in response to fluid flowing through the annulus between the stationary assembly and the rotating assembly.
A powered reamer comprising a stationary assembly having a flow bore therethrough. A rotating assembly is disposed about the stationary assembly and one or more cutting structures are coupled to an outer surface of the rotating assembly. A flow restriction is disposed within the flow bore so as to divert a portion of fluid flowing through the flow bore through an outlet from the flow bore into an annulus between the stationary assembly and the rotating assembly. A power section is formed in the annulus between the stationary assembly and the rotating assembly. The power section operates to eccentrically rotate the rotating assembly about the stationary assembly in response to fluid flowing through the annulus between the stationary assembly and the rotating assembly.
A stabilizer for a line may include a guide configured for arrangement on the line to resist and/or dampen lateral motions of the line where the guide may include a guide jacket having a static sleeve configured to allow the line to pass through the guide and a fortifying bracket configured to reinforce the guide jacket and configured to interface with a hanging system to support the guide jacket and maintain the guide jacket in position on the line.
A stabilizer for a line may include a guide configured for arrangement on the line to resist and/or dampen lateral motions of the line where the guide may include a guide jacket having a static sleeve configured to allow the line to pass through the guide and a fortifying bracket configured to reinforce the guide jacket and configured to interface with a hanging system to support the guide jacket and maintain the guide jacket in position on the line.
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