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 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 portion 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.
F16L 33/34 - Arrangements for connecting hoses to rigid members; Rigid hose-connectors, i.e. single members engaging both hoses with bonding obtained by vulcanisation, gluing, melting, or the like
F16L 33/24 - Arrangements for connecting hoses to rigid members; Rigid hose-connectors, i.e. single members engaging both hoses with parts screwed directly on or into the hose
A rotary steerable drilling assembly 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 a 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 torque control actuator assembly includes a spool valve including a cylinder including a port and a hydraulically actuatable piston slidably disposed in the cylinder.
A progressive cavity device includes a stator, a rotor positioned within the stator, a driveshaft, and a joint coupling the driveshaft and the rotor. The joint includes a pivotable member fixably coupled to and engaged with an end of the driveshaft. The pivotable member has a central axis, a first end proximal the driveshaft, a second end distal the driveshaft, and a radially outer surface extending axially from the first end of the pivotable member to the second end of the pivotable member. The joint also includes a first wear pad mounted on the pivotable member. In addition, the joint includes a torque key disposed about the pivotable member and positioned radially adjacent the radially outer surface of the pivotable member. The torque key is rotationally locked to the rotor.
E21B 17/04 - Couplings; Joints between rod and bit, or between rod and rod
E21B 17/046 - Couplings; Joints between rod and bit, or between rod and rod with ribs, pins, or jaws, and complementary grooves or the like, e.g. bayonet catches
A pipe-dope application system can include an end effector including an applicator configured to retain pipe-dope for application to a drilling component surface, the end effector adapted for connection with a robotic arm configured to perform operations including: applying pipe-dope to the drilling component surface by moving the applicator along the drill pipe surface; and supplying pipe-dope to the applicator by positioning the applicator within a priming station configured to receive the applicator of the end effector.
A modular fixed cutter drill bit for drilling an earthen formation has a central axis and a cutting direction of rotation about the central axis. The drill bit includes a bit body configured to rotate about the central axis in the cutting direction of rotation. The bit body includes a bit face. In addition, the drill bit includes a blade extending radially along the bit face. The blade has a leading side relative to the cutting direction of rotation, a trailing side relative to the cutting direction of rotation, and a cutter-supporting surface extending from the leading side to the traling side. The blade includes a socket extending from the cutter-supporting surface of the blade. Further, the drill bit includes a cutter element assembly mounted to the blade and extending from a cutter-supporting surface of the blade. The cutter element assembly includes a pod seated in the socket and fixably attached to the blade and a cutter element fixably attached to the pod.
E21B 10/573 - Button-type inserts with preformed cutting elements mounted on a distinct support, e.g. polycrystalline inserts - characterised by support details, e.g. the substrate construction or the interface between the substrate and the cutting element
E21B 10/633 - Drill bits characterised by parts, e.g. cutting elements, which are detachable or adjustable with plural detachable cutting elements independently detachable
E21B 10/567 - Button-type inserts with preformed cutting elements mounted on a distinct support, e.g. polycrystalline inserts
E21B 10/627 - Drill bits characterised by parts, e.g. cutting elements, which are detachable or adjustable with plural detachable cutting elements
7.
COILED TUBING INJECTOR WITH REACTIVE CHAIN TENSION
A coiled tubing injector including two or more drive chains each carrying a plurality of grippers for engaging coiled tubing within a grip zone defined between the two or more drive chains, a drive system including at least one hydraulic motor connected to a drive line and a return line forming a drive circuit for fluidly powering the at least one hydraulic motor, and a tension system including at least one hydraulic cylinder for tensioning the two or more drive chains. The tension system can include a reactive chain tension circuit for automatically tensioning the two or more drive chains by maintaining a pressure differential between a fluid pressure within the drive line and a fluid pressure within the at least one hydraulic cylinder.
09 - Scientific and electric apparatus and instruments
42 - Scientific, technological and industrial services, research and design
Goods & Services
Monitoring and control systems for oil and gas wellstream processing systems that include natural gas dehydration units with catalyst media, namely, for CO2 and H2 gas streams, for monitoring water content in the gas streams, monitoring water content in the catalyst media, monitoring the health status of valves, electrical heaters, and air coolers, and controlling when the catalyst media is saturated in water to extend the life of the catalyst media, and components therefor, namely, control program software, moisture sensors, electronic valve actuators, conductivity sensors for electrical heaters, and vibration sensors for air coolers Monitoring and control services for oil and gas wellstream processing systems that include natural gas dehydration units with catalyst media, namely, for CO2 and H2 gas streams, for monitoring water content in the gas streams, monitoring water content in the catalyst media, monitoring the health status of valves and valve actuators, electrical heaters, and air coolers of the wellstream processing systems, controlling when the catalyst media is saturated in water to extend the life of the catalyst media, and providing key performance indicators, alerts, and notifications for the wellstream processing systems
A modular well cellar system can include a planar base member defining an aperture sized to receive a conductor pipe; a first end member secured to the base member and configured to support a first lateral wall of the well cellar excavation; a first side member secured to the base member, the first end member, and the second end member, and configured to support a first longitudinal wall of the well cellar excavation; a second side member secured to the planar base member and the first end member and configured to support a second longitudinal wall of the well cellar excavation; and a seal formed between a top surface of the planar base member and each of the first end member, the first side member, and the second side member.
A modular well cellar system can include a planar base member defining an aperture sized to receive a conductor pipe; a first end member secured to the base member and configured to support a first lateral wall of the well cellar excavation; a first side member secured to the base member, the first end member, and the second end member, and configured to support a first longitudinal wall of the well cellar excavation; a second side member secured to the planar base member and the first end member and configured to support a second longitudinal wall of the well cellar excavation; and a seal formed between a top surface of the planar base member and each of the first end member, the first side member, and the second side member.
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 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 Reid vapor pressure control system includes a separator vessel that receives a multiphase flow stream having a gas phase, an oil phase, and a water phase. The Reid vapor pressure control system further includes a gas phase output meter and one or more liquid phase output meters operably connected to a process controller. The process controller is configured to determine an energy input rate used to reduce the Reid vapor pressure of the oil phase based on the operating parameters of the Reid vapor pressure control system during a disturbance test. During operation, the process controller supplies input energy at the energy input rate to the Reid vapor pressure control system.
B01D 33/03 - Filters with filtering elements which move during the filtering operation with translationally moving filtering elements, e.g. pistons with vibrating filter elements
E21B 21/06 - Arrangements for treating drilling fluids outside the borehole
B07C 5/00 - Sorting according to a characteristic or feature of the articles or material being sorted, e.g. by control effected by devices which detect or measure such characteristic or feature; Sorting by manually actuated devices, e.g. switches
Various embodiments disclosed relate to a reciprocating triplex pump. The present disclosure includes a reciprocating triplex pump with a longer stroke time. Such a pump can include a prime mover with a shaft extending longitudinally; a gear box arranged longitudinally along the shaft, the gear box for actuating the prime mover; and a slider-crank mechanism laterally offset from the gear box. The slider-crank mechanism can include a rotating member assembly, a sliding member assembly, and a connecting rod assembly.
F04B 27/10 - Multi-cylinder pumps specially adapted for elastic fluids and characterised by number or arrangement of cylinders having cylinders coaxial with, or parallel or inclined to, main shaft axis having stationary cylinders
F04B 35/00 - Piston pumps specially adapted for elastic fluids and characterised by the driving means to their working members, or by combination with, or adaptation to, specific driving engines or motors, not otherwise provided for
This disclosure relates to shaker adjustments based on sensor measurements for sensors positioned at different locations about the shaker. This disclosure explains techniques to adjust a shale shaker as would be used to separate particulates (cuttings and other solids) from drilling fluid (commonly referred to as “mud”) during a drilling operation. Empirical models have been formulated to provide for programming a controller to calculate run-time adjustments to the shaker to increase efficiency. The controller may control one or more shakers concurrently. Different techniques and measurement types may be used concurrently to achieve desired shaker inclination and maintain a proper beach location during operation. Sensors include accelerometers, proximity sensors, and other types of data acquisition devices that may be used to detect motion parameters of an operational (e.g., in-use and running) shaker.
Various embodiments disclosed relate to a reciprocating triplex pump. The present disclosure includes a reciprocating triplex pump with a longer stroke time. Such a pump can include a prime mover with a shaft extending longitudinally; a gear box arranged longitudinally along the shaft, the gear box for actuating the prime mover; and a slider-crank mechanism laterally offset from the gear box. The slider-crank mechanism can include a rotating member assembly, a sliding member assembly, and a connecting rod assembly.
F04B 1/0404 - Multi-cylinder machines or pumps characterised by number or arrangement of cylinders having cylinders in star- or fan-arrangement - Details or component parts
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 17/03 - Pumps characterised by combination with, or adaptation to, specific driving engines or motors driven by electric motors
F04B 17/05 - Pumps characterised by combination with, or adaptation to, specific driving engines or motors driven by internal-combustion engines
F04B 1/12 - 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
A pump system may include a drive shaft extending along a longitudinal axis and supplying rotation about the longitudinal axis, a gear system operably coupled to the shaft for changing the orientation of the rotation, and a slider-crank mechanism. The slider crank mechanism may include a rotating member assembly mechanically coupled to and driven by the gear system. The rotating member assembly may include a plurality of rotating members having respective rotational axes offset laterally from one another and generally orthogonal to the longitudinal axis. The slider crank mechanism may also include a sliding member assembly mechanically coupled to the rotating member assembly. The rotating member assembly may be configured to drive reciprocating motion of the sliding member to alternately draw fluid in and discharge fluid. The slider crank mechanism may also include a connecting rod assembly mechanically coupling the rotating member assembly to the sliding member assembly.
F04B 9/02 - Piston machines or pumps characterised by the driving or driven means to or from their working members the means being mechanical
F16H 21/16 - Gearings comprising primarily only links or levers, with or without slides all movement being in, or parallel to, a single plane for interconverting rotary motion and reciprocating motion
F16H 57/038 - Gearboxes for accommodating bevel gears
20.
Downhole friction reduction systems having a flexible agitator
An agitator deployable in a wellbore includes a housing including a central axis and a central passage, a valve including a first valve body having a first contact face and a second valve body permitted to rotate relative to the first valve body and having a second contact face configured to contact the first contact face, a first valve adapter including a first receptacle which receives at least a portion of the first valve body to couple the first valve adapter to the first valve body, and a flexible valve configured to permit the first valve body to flex relative to the first valve adapter whereby an angular misalignment may form between a central axis of the first valve body and a central axis of the first valve adapter.
An agitator deployable in a wellbore includes a housing including a central axis and a central passage, a valve including a first valve body having a first contact face and a second valve body permitted to rotate relative to the first valve body and having a second contact face configured to contact the first contact face, a first valve adapter including a first receptacle which receives at least a portion of the first valve body to couple the first valve adapter to the first valve body, and a flexible valve configured to permit the first valve body to flex relative to the first valve adapter whereby an angular misalignment may form between a central axis of the first valve body and a central axis of the first valve adapter.
09 - Scientific and electric apparatus and instruments
42 - Scientific, technological and industrial services, research and design
Goods & Services
Downloadable software in the nature of a mobile application that uses artificial intelligence for analyzing and training machines to learn and to improve manufacturing efficiency Providing online non-downloadable software that uses artificial intelligence for analyzing and training machines to learn and to improve manufacturing efficiency
23.
WEAR RESISTANT TUBULAR MEMBERS AND SYSTEMS AND METHODS FOR PRODUCING THE SAME
A tubular member includes a central axis, a first end, a second end opposite the first end, and a throughbore extending axially from the first end to the second end. In addition, the tubular member includes a first connector at the first end and a second connector at the second end. Further, the tubular member includes a tubular region axially positioned between and axially spaced from the first connector and the second connector. The tubular member also includes a first upset axially positioned between the tubular region and the first connector. The first upset has an internal transition within the throughbore that increases an inner diameter of the throughbore when moving axially from the first upset to the tubular region. Moreover, the tubular member includes a first wear pad integrally formed on the tubular region. An outer diameter of the tubular member is greater along the first wear pad than along the tubular region.
A tubular member includes a central axis, a first end, a second end opposite the first end, and a throughbore extending axially from the first end to the second end. In addition, the tubular member includes a first connector at the first end and a second connector at the second end. Further, the tubular member includes a tubular region axially positioned between and axially spaced from the first connector and the second connector. The tubular member also includes a first upset axially positioned between the tubular region and the first connector. The first upset has an internal transition within the throughbore that increases an inner diameter of the throughbore when moving axially from the first upset to the tubular region. Moreover, the tubular member includes a first wear pad integrally formed on the tubular region. An outer diameter of the tubular member is greater along the first wear pad than along the tubular region.
A valve for a displacement pump includes a valve body having an annular strikeface and defining an annular receptacle, and an annular seal received in the receptacle of the valve body, the seal including an annular contact surface, wherein the seal defines a cumulative displacement ratio of (i) at least one of at most 0.20 at a location that is spaced 40% from an inner diameter (ID) of the contact surface of the seal moving towards an outer diameter (OD) of the contact surface, (ii) at most 0.35 at a location that is spaced 55% from the ID of the contact surface moving towards the OD of the contact surface, and (iii) at most 0.45 at a location that is spaced 65% from the ID of the contact surface moving towards the OD of the contact surface.
A cutter element for a fixed cutter drill bit (100) configured to drill a borehole (20) in a subterranean formation (90) includes a base (210) having a central axis, a first end (210a), a second end (210b), and a radially outer cylindrical surface extending axially from the first end to the second end. In addition, the cutter element includes a cutting layer (220) fixably mounted to the first end (210) of the base. The cutting layer includes a stepped cutting face (221) distal the base and a radially outer cylindrical surface extending axially from the cutting face to the radially outer cylindrical surface of the base. The radially outer cylindrical surface of the cutting layer is contiguous with the radially outer cylindrical surface of the base. The stepped cutting face includes a first step (230), a second step (240) axially spaced from the first step, and a riser axially positioned between the first step and the second step. The first step is axially positioned between the riser and the base.
A cutter element for a fixed cutter drill bit configured to drill a borehole in a subterranean formation includes a base having a central axis, a first end, a second end, and a radially outer cylindrical surface extending axially from the first end to the second end. In addition, the cutter element includes a cutting layer fixably mounted to the first end of the base. The cutting layer includes a stepped cutting face distal the base and a radially outer cylindrical surface extending axially from the cutting face to the radially outer cylindrical surface of the base. The radially outer cylindrical surface of the cutting layer is contiguous with the radially outer cylindrical surface of the base. The stepped cutting face includes a first step, a second step axially spaced from the first step, and a riser axially positioned between the first step and the second step. The first step is axially positioned between the riser and the base.
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
A shale shaker for separating formation cuttings from a drilling fluid includes a basket and a screen deck positioned within the basket. The screen deck includes a plurality of screens positioned on a plurality of screen supports, such that each screen is positioned on a corresponding one of the plurality of screen supports. Each screen includes a top side, a bottom side opposite the top side, and a mounting bracket positioned along the bottom side. The mounting bracket includes a pair of parallel first support members and a clamping bar coupled to and extending between the pair of first support members. Each screen support includes a pair of parallel second support members and a latch assembly including a hook assembly positioned between the pair of second support members. The hook assembly is configured to engage with the clamping bar to secure the screen to the screen support.
A shale shaker for separating formation cuttings from a drilling fluid includes a basket and a screen deck positioned within the basket. The screen deck includes a plurality of screens positioned on a plurality of screen supports, such that each screen is positioned on a corresponding one of the plurality of screen supports. Each screen includes a top side, a bottom side opposite the top side, and a mounting bracket positioned along the bottom side. The mounting bracket includes a pair of parallel first support members and a clamping bar coupled to and extending between the pair of first support members. Each screen support includes a pair of parallel second support members and a latch assembly including a hook assembly positioned between the pair of second support members. The hook assembly is configured to engage with the clamping bar to secure the screen to the screen support.
E21B 21/06 - Arrangements for treating drilling fluids outside the borehole
B01D 33/03 - Filters with filtering elements which move during the filtering operation with translationally moving filtering elements, e.g. pistons with vibrating filter elements
09 - Scientific and electric apparatus and instruments
42 - Scientific, technological and industrial services, research and design
Goods & Services
Downloadable computer software for use in supply chain logistics for use in the agriculture industry; Downloadable mobile applications for use in supply chain logistics for use in the agriculture industry Providing on-line non-downloadable software using artificial intelligence for analyzing the supply chain for use in the agriculture industry
33.
AUTOMATED SYSTEMS AND METHODS FOR CONTROLLING THE OPERATION OF DOWNHOLE-ADJUSTABLE MOTORS
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
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
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.
G01R 19/00 - Arrangements for measuring currents or voltages or for indicating presence or sign thereof
G01L 3/10 - Rotary-transmission dynamometers wherein the torque-transmitting element comprises a torsionally-flexible shaft involving electric or magnetic means for indicating
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
40.
DRILL BIT CUTTER ELEMENTS WITH MULTIPLE SURFACE FINISHES
A cutter element for a fixed cutter drill bit has a central axis and includes a cylindrical substrate and a cutting layer mounted to the substrate. The cutting layer includes a first end engaged with the substrate, a second end opposite the first end, and a radially outer surface extending axially between the first and second ends. In addition, the cutting layer includes a cutting surface positioned at the second end and a cutting tip positioned between the cutting surface and the radially outer surface. Further, the cutting layer includes a first region on the cutting surface having a first surface roughness, and a second region on the cutting surface having a second surface roughness that is higher than the first surface roughness. The second region covers the central axis along the cutting surface, and the first region extends from the second region to the cutting tip.
E21B 10/567 - Button-type inserts with preformed cutting elements mounted on a distinct support, e.g. polycrystalline inserts
E21B 10/573 - Button-type inserts with preformed cutting elements mounted on a distinct support, e.g. polycrystalline inserts - characterised by support details, e.g. the substrate construction or the interface between the substrate and the cutting element
41.
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.
A tower crane for performing a lifting a load includes an extendable tower assembly having a central axis and including a plurality of separate tower sections, a climbing assembly including a climbing frame positioned on the tower assembly and a latching assembly to transport the climbing assembly vertically along the tower assembly, and a boom assembly atop the tower assembly and including a crane floor, a boom supported on the crane floor, a lifting member coupled to the boom, and a slew bearing coupled to the crane floor and configured to permit the crane floor to rotate about a rotational axis, wherein the slew bearing includes a first bearing position and a second bearing position spaced from the first bearing position relative to the central axis of the tower assembly.
A downhole motor for directional drilling includes a driveshaft assembly including a driveshaft housing and a driveshaft rotatably disposed within the driveshaft housing, a bearing assembly including a bearing housing and a bearing mandrel rotatably disposed within the bearing housing, wherein the bearing mandrel is configured to couple with a drill bit, a bend adjustment assembly configured to adjust a bend setting of the downhole motor, a lock piston including an unlocked position, and a locked position configured to lock the bend setting of the bend adjustment assembly, one or more hydraulic pumps configured to actuate the lock piston into the unlocked position to unlock the bend adjustment assembly, and an electronics package configured to indicate the bend setting of the bend adjustment assembly.
E21B 47/09 - Locating or determining the position of objects in boreholes or wells; Identifying the free or blocked portions of pipes
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 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.
A washpipe assembly for a rotational device includes a gland assembly, a washpipe positioned within the gland assembly, and a seal assembly positioned about the washpipe within the gland assembly. The seal assembly includes a plurality of ring seals, a plurality of annular chambers positioned between the ring seals along the washpipe, and a pressure manifold fluidly coupled to the plurality of annular chambers. The pressure manifold is configured to receive a first fluid pressure and is configured to apply a plurality of pressures to the annular chambers, and the plurality of pressures are each less than the first fluid pressure.
A centrifuge system includes an inlet fluid conduit to receive a flow of raw fluid, an outlet fluid conduit to receive a flow of effluent fluid, an effluent sensor to determine a density of the effluent fluid, a centrifuge including an inlet to receive the raw fluid, an effluent outlet to discharge the effluent fluid, and a solids outlet configured to discharge solids separated from the raw fluid by the centrifuge, a feed pump to pump the raw fluid to the inlet of the centrifuge at a selected flowrate, and a controller to automatically adjust at least one of a speed of the feed pump, a rotational speed of a bowl of the centrifuge about a rotational axis, and a rotational speed of a conveyor of the centrifuge about the rotational axis in response to a change in the density of the effluent fluid as determined by the effluent sensor.
A washpipe assembly for a rotational device includes a gland assembly, a washpipe positioned within the gland assembly, and a seal assembly positioned about the washpipe within the gland assembly. The seal assembly includes a plurality of ring seals, a plurality of annular chambers positioned between the ring seals along the washpipe, and a pressure manifold fluidly coupled to the plurality of annular chambers. The pressure manifold is configured to receive a first fluid pressure and is configured to apply a plurality of pressures to the annular chambers, and the plurality of pressures are each less than the first fluid pressure.
A mounting bracket for a solar array includes a top hat assembly including an outer top hat having a longitudinally extending first rail configured to contact a solar module of the solar array, and an inner top having a longitudinally extending second rail also configured to contact the solar module, an actuator arm assembly comprising a pair of actuator arms which extend from the top hat assembly and which form an opening configured to receive a tubular member of the solar array, and a fastener assembly configured to connect the pair of actuator arms and secure the mounting bracket to both the solar module and the tubular member.
A mounting bracket for a solar array includes a top hat assembly including an outer top hat having a longitudinally extending first rail configured to contact a solar module of the solar array, and an inner top having a longitudinally extending second rail also configured to contact the solar module, an actuator arm assembly comprising a pair of actuator arms which extend from the top hat assembly and which form an opening configured to receive a tubular member of the solar array, and a fastener assembly configured to connect the pair of actuator arms and secure the mounting bracket to both the solar module and the tubular member.
A coiled tubing injector including two or more drive chains each carrying a plurality of grippers for engaging coiled tubing within a grip zone defined between the two or more drive chains, a drive system including at least one hydraulic motor connected to a drive line and a return line forming a drive circuit for fluidly powering the at least one hydraulic motor, and a tension system including at least one hydraulic cylinder for tensioning the two or more drive chains. The tension system can include a reactive chain tension circuit for automatically tensioning the two or more drive chains by maintaining a pressure differential between a fluid pressure within the drive line and a fluid pressure within the at least one hydraulic cylinder.
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.
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.
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 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 polycrystalline composite tool component and associated methods are disclosed. In one example plurality of diamond particles are coated with a conforming catalyst metal coating and a plurality of graphene particles. Various asymmetric distributions of graphene particles are shown that provide a variety of material properties.
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 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 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 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 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 valve lock for a linear valve system includes a housing including a passage configured to receive a rod of a linearly extendable valve member of the linear valve system, and a collet assembly received in the housing, wherein the collet assembly has a central axis extending parallel the rod of the valve member, a radially inner configuration with respect to the central axis of the collet assembly, and a radially outer configuration relative to the central axis of the collet assembly, wherein the lock includes an unlocked configuration associated with the radially outer configuration of the collet assembly, and a locked configuration associated with the radially inner configuration of the collet assembly and which locks against the rod of the valve member and thereby prevent the rod from travelling in at least one axial direction.
A magnetic transmission system includes an outer gear ring including an outer plurality of permanent magnets and configured to rotate about a rotational drive axis, an inner gear ring positioned within the outer gear ring and including an inner plurality of permanent magnets magnetically coupled to the outer plurality of permanent magnets, and an eccentric bearing assembly configured to convert orbital motion of the inner gear ring about the rotational drive axis into rotational motion of the eccentric bearing assembly about a bearing rotational axis that is radially offset from the rotational drive axis, and a first drive shaft coupled to the outer gear ring and a second drive shaft coupled to the inner gear ring, wherein the outer gear ring and the inner gear ring are configured to provide a gear ratio between the first drive shaft and the second drive shaft.
H02K 49/10 - Dynamo-electric clutches; Dynamo-electric brakes of the permanent-magnet type
H02K 51/00 - Dynamo-electric gears, i.e. dynamo-electric means for transmitting mechanical power from a driving shaft to a driven shaft and comprising structurally interrelated motor and generator parts
A system includes a wellbore that extends from a surface into a subterranean formation. In addition, the system includes a power generation assembly including a fluid circuit that is in fluid communication with the wellbore wherein the power generation assembly is configured to generate electricity in response to a flow of a working fluid through the fluid circuit. Further, the system includes a bubble pump positioned within the wellbore that is configured to circulate the working fluid between the fluid circuit of the power generation assembly and the wellbore via a thermosiphon effect.
E21B 41/00 - Equipment or details not covered by groups
E21B 43/00 - Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
F24T 10/13 - Geothermal collectors with circulation of working fluids through underground channels, the working fluids not coming into direct contact with the ground using tube assemblies suitable for insertion into boreholes in the ground, e.g. geothermal probes
69.
FIXED CUTTER DRILL BITS AND CUTTER ELEMENT ARRANGEMENTS FOR SAME
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 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.
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.
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
74.
HELICAL MAGNET ARRANGEMENT FOR A MAGNETIC LINEAR ACTUATOR
A magnetic linear actuator includes a stator and a rotor. The stator includes a first helical array of magnets. The rotor is disposed within the stator and includes a second helical array of magnets. The second helical array of magnets includes a first helical band of magnets and a second helical band of magnets. A first of the magnets of the first helical band coupled to at least one other of the magnets of the first helical band. A first of the magnets of the second helical band coupled to at least one other of the magnets of the second helical band.
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 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.
A magnetic linear actuator includes a stator, a translator, and a ball bearing. The stator includes a first helical array of magnets. The translator is disposed within the stator, and includes a second helical array of magnets. The ball bearing is disposed between the stator and the translator, and includes a plurality of balls in contact with the stator.
H02K 5/173 - Means for supporting bearings, e.g. insulating supports or means for fitting bearings in the bearing-shields using bearings with rolling contact, e.g. ball bearings
A non-drive dynamic stabilizer includes a damper and an actuator. The dynamic stabilizer provides multiple states of support to a solar tracker structure. These states may include 1) flexible movement and/or damping during normal operation (i.e. tracking) and/or 2) rigid or locked, whereby the dynamic stabilizer acts as a restraint. The dynamic stabilizer is actuated by a control system according to the real-time demands on the structure. Sensors to provide input to the control system may include wind speed sensors, wind direction sensors, snow sensors, vibration sensors and/or displacement sensors.
H02S 20/32 - Supporting structures being movable or adjustable, e.g. for angle adjustment specially adapted for solar tracking
F16F 9/56 - Means for adjusting the length of, or for locking, the spring or damper, e.g. at the end of the stroke
F24S 40/80 - Accommodating differential expansion of solar heat collector elements
F24S 25/67 - Fixation means, e.g. fasteners, specially adapted for supporting solar heat collector modules for coupling adjacent modules or their peripheral frames
F24S 30/458 - Arrangements for moving or orienting solar heat collector modules for rotary movement with two rotation axes with inclined primary axis
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 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 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.
09 - Scientific and electric apparatus and instruments
Goods & Services
downloadable software for recording data relating to tubulars that are transported through the drill floor and in and out of the oil well, namely, tubular identifying information and tubular attributes, namely, size, length, tensile strength, location, depth, torque applied, date of use, and utilization data
83.
SYSTEMS AND METHODS FOR WIRE ARC ADDITIVE MANUFACTURING
A system, a non-transitory computer readable medium for executing instructions, and a method for fabricating a subsea connector, including selecting a substrate on which to form the subsea connector, positioning the substrate on a welding positioner base, and applying a first weld bead using a first multiple axis robot, applying a second weld bead using a second multiple axis robot, forming a plurality of weld bead layers comprising the first weld bead and the second weld bead, and forming a subsea connector formed from the plurality of weld bead layers.
B23K 35/38 - Selection of media, e.g. special atmospheres for surrounding the working area
B23K 9/16 - Arc welding or cutting making use of shielding gas
B23K 37/04 - Auxiliary devices or processes, not specially adapted to a procedure covered by only one of the other main groups of this subclass for holding or positioning work
B33Y 30/00 - ADDITIVE MANUFACTURING, i.e. MANUFACTURING OF THREE-DIMENSIONAL [3D] OBJECTS BY ADDITIVE DEPOSITION, ADDITIVE AGGLOMERATION OR ADDITIVE LAYERING, e.g. BY 3D PRINTING, STEREOLITHOGRAPHY OR SELECTIVE LASER SINTERING - Details thereof or accessories therefor
B33Y 80/00 - Products made by additive manufacturing
Tower erection systems and methods utilizing a load-sharing support member (LS support member) are disclosed. The LS support member can have a first end coupled to a crane tower and a second end configured to repeatably couple to the upper-most tower section of a partially assembled tower stack during assembly. During lifting, a portion of the vertical load is transferred to the partially assembled tower stack.
F03D 13/20 - Arrangements for mounting or supporting wind motors; Masts or towers for wind motors
B66C 23/18 - Cranes comprising essentially a beam, boom or triangular structure acting as a cantilever and mounted for translatory or swinging movements in vertical or horizontal planes or a combination of such movements, e.g. jib cranes, derricks or tower cranes specially adapted for use in particular locations or for particular purposes
E04H 12/34 - Arrangements for erecting or lowering towers, masts, poles, chimney stacks, or the like
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 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.
40 - Treatment of materials; recycling, air and water treatment,
Goods & Services
Electrostatic coalescing machines used for scientific and electrical applications in the oil and gas industry Treatment of materials in the nature of emulsions by means of electrostatic coalescing technology device
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 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 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.
An actuator includes housing having a reciprocation axis, drive gear configured to couple to the motor, and electromagnetic clutch configured to couple to the motor and coupled to the drive gear. The clutch engages first and second clutch plates responsive to being powered and disengages the clutch plates responsive to not being powered. Actuator includes a ball screw including a nut and a threaded shaft. The nut is coupled to the drive gear and rotation of the drive gear induces rotation of the nut about the reciprocation axis. Rotation of the nut induces motion of the threaded shaft along the reciprocation axis. Actuator includes a fluid damper having a piston coupled to the threaded shaft and disposed within a chamber containing a fluid. Piston includes a port that couples a first chamber portion to a second chamber portion. A brake assembly limits rotation of the nut responsive to the assembly being engaged.
A valve for a well system including a valve housing including a first housing port, a second housing port, and a bore, a piston received in the bore and including a first end, a second end, and an annular flange including a first annular surface and a second annular surface both of which are in fluid communication with the second housing port, a piston seal disposed in the outer surface of the piston and in sealing engagement with an inner surface of the bore, and a cage assembly that includes a cage including a bore, a first cage port, a second cage port, and a third cage port, and a spool disposed in the cage and coupled to the piston, the spool including a throughbore.
F16K 11/07 - Multiple-way valves, e.g. mixing valves; Pipe fittings incorporating such valves; Arrangement of valves and flow lines specially adapted for mixing fluid with all movable sealing faces moving as one unit comprising only sliding valves with linearly sliding closure members with cylindrical slides
E21B 33/035 - Well heads; Setting-up thereof specially adapted for underwater installations
E21B 34/16 - Control means therefor being outside the borehole
F16K 31/122 - Operating means; Releasing devices actuated by fluid the fluid acting on a piston
F16K 3/26 - 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 sealing faces shaped as surfaces of solids of revolution with cylindrical valve members with fluid passages in the valve member
93.
ROBOT END-EFFECTOR ORIENTATION CONSTRAINT FOR PIPE TAILING PATH
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.
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.
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
A wellsite monitoring system includes a base station, a plurality of access points, and a wellsite communication interface. The base station is configured to provide communication between the wellsite and a remote system. Each of the access points is configured to communicate with base station. The wellsite communication interface is interfaced to well service equipment, and is configured to communicate with the access points via a wellsite protocol used by the base station, and to present an authentication credential to the base station. The base station is also configured to verify an identity of the wellsite communication interface via the authentication credential, and to enable communication with the wellsite communication interface based on verification of the identity of the wellsite communication interface.
A magnetic linear actuator includes a rotor, a first end cap, a second end cap, a translator, and a guide rod. The rotor includes a first helical array of magnets. The first end cap disposed at a first end of the rotor. The second end cap is disposed at a second end of the rotor. The second end is opposite the first end. The translator is disposed within the rotor, and includes a second helical array of magnets. The guide rod passes through the translator and includes a first end that engages the first end cap, and a second end the engages the second end cap.
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.
B60P 3/035 - Vehicles adapted to transport, to carry or to comprise special loads or objects for transporting reel units
B62D 21/14 - Understructures, i.e. chassis frame on which a vehicle body may be mounted of adjustable length or width
B62D 21/09 - Means for mounting load bearing surfaces
B62D 21/20 - Understructures, i.e. chassis frame on which a vehicle body may be mounted characterised by the vehicle type and not provided for in groups trailer type, i.e. a frame specifically constructed for use in a non-powered vehicle
B62D 61/10 - Motor vehicles or trailers, characterised by the arrangement or number of wheels, not otherwise provided for, e.g. four wheels in diamond pattern with more than four wheels
E21B 19/22 - Handling reeled pipe or rod units, e.g. flexible drilling pipes
99.
METHOD TO CONTROL THE FLOW OF FLUID TO HIGH PRESSURE PUMPS
A hydraulic fracturing system (100) comprises: a wellhead (146); a pump system (206) that includes one or more high-pressure pumps (238) to deliver fluid to the wellhead (146), and a fluid communication system (208) including a number of valve apparatuses (126) that control the delivery of fluid to the high-pressure pumps (238). The valve apparatuses (126) can receive signals from a control system (150) to regulate the flow rate of the fluid to the high-pressure pumps (238), wherein the control system (150) is configured to: determine a target flow rate for the fluid supplied to the one or more high- pressure pumps (238); determine a valve apparatus actuation scheme based on the target flow rate, the valve apparatus actuation scheme indicating that a valve apparatus (126) of the number of valve apparatuses is to be in an open state; and send an actuation signal to the valve apparatus (126) to actuate a flow control member of the valve apparatus. The corresponding method to control inlet flow to the one or more high-pressure pumps (238) is also disclosed.
F04B 49/22 - Control of, or safety measures for, machines, pumps, or pumping installations, not otherwise provided for in, or of interest apart from, groups by means of valves
A tower crane for assembling a wind turbine includes a boom assembly including a boom and a hoisting block coupled to the boom, an extendable tower assembly including a plurality of tower sections, and a transport assembly including a central support frame coupled to the tower assembly, a self-propelled transporter configured to transport the tower crane, and a diagonal brace extending between the central support frame and the transporter, wherein the diagonal brace includes a linear actuator configured to selectably extend and retract the diagonal brace.
B66C 23/18 - Cranes comprising essentially a beam, boom or triangular structure acting as a cantilever and mounted for translatory or swinging movements in vertical or horizontal planes or a combination of such movements, e.g. jib cranes, derricks or tower cranes specially adapted for use in particular locations or for particular purposes
B66C 23/36 - Cranes comprising essentially a beam, boom or triangular structure acting as a cantilever and mounted for translatory or swinging movements in vertical or horizontal planes or a combination of such movements, e.g. jib cranes, derricks or tower cranes specially adapted for use in particular locations or for particular purposes mounted on road or rail vehicles; Manually-movable jib cranes for use in workshops; Floating cranes
