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 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 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.
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.
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
9.
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.
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 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.
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
14.
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
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
17.
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 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 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 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 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 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 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 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.
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.
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
43.
Downhole electronics puck and retention, installation and removal methods
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 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
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
47.
Downhole eccentric reamer tool and related systems and methods
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.
A hydraulic fracturing system can include valve apparatuses that control the delivery of fluid to high-pressure pumps that supply the fluid to a wellhead. The valve apparatuses can receive electronic signals from a control system to regulate the flow rate of the fluid to the high-pressure pumps. In one or more examples, the flow rate of the fluid can be controlled such that proppant in the fluid remains in solution.
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.
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
E21B 19/06 - Elevators, i.e. rod- or tube-gripping devices
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 drilling rig having a lift arm, which may be an auxiliary lift arm provided in addition to a primary lifting cable system of the drilling rig. The lift arm may be configured to hoist and/or manipulate drill collar, drill pipe, or other drilling pipe or conduit. The lift arm may be coupled to a mast of the drilling rig and may have a cantilevered boom extending therefrom. The boom may be configured to pivot between alignment, or near alignment, with well center and a racking board. The lift arm may additionally have a pipe engaging element coupled to the boom. The pipe engaging element may be configured to couple to stands or lengths of drilling pipe. The pipe engaging element may be raised and lowered together with or relative to the boom via a lift line controllable via a hydraulic cylinder, winch, or other suitable mechanism for withdrawing and releasing the line.
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
B25J 13/08 - Controls for manipulators by means of sensing devices, e.g. viewing or touching devices
52.
WEAR RESISTANT TUBULAR MEMBERS AND SYSTEMS AND METHODS FOR PRODUCING THE SAME
A system for manufacturing a tubular member includes a mandrel configured to be inserted within a throughbore of the tubular member to engage with an inner diameter of the throughbore. In addition, the system includes a die assembly comprising a cavity. The die assembly is configured to be disposed about an outer surface of the tubular member such that a central portion of the tubular member is aligned with the cavity. Further, the system includes a ram configured to apply a load to the tubular member along a central axis of the tubular member to expand the central portion of the outer surface of the tubular member into the cavity to form an upset region along the tubular member.
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 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.
E21B 19/16 - Connecting or disconnecting pipe couplings or joints
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
55.
PROGRESSING CAVITY DEVICES AND ASSEMBLIES FOR COUPLING MULTIPLE STAGES OF PROGRESSING CAVITY DEVICES
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 15/00 - Component parts, details or accessories of machines, pumps or pumping installations, not provided for in groups
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
A dual activity top drive may include a mechanized system configured for suspension from a traveling block of a drill rig and for engaging and rotating a drill string from the top of the drill string. The dual activity top drive may also include a primary pipe handling system suspended from the mechanized system and configured for handling a pipe string and an auxiliary pipe handling system suspended from the mechanized system and configured for handling a segment of pipe to be added or removed from the pipe string.
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.
A method for increasing an amplitude of reciprocal axial extensions and contractions of a shock tool configured to induce axial oscillations in a drillstring during drilling operations includes (a) selecting the shock tool. The shock tool has a central axis and an axial length. The shock tool includes an outer housing, a mandrel telescopically disposed within the outer housing, and a first annular piston fixably coupled to the mandrel. The shock tool has a first amplitude of reciprocal axial extension and contraction at a pressure differential between a first fluid pressure in the outer housing and a second fluid pressure outside the outer housing. In addition, the method includes (b) fixably coupling a second annular piston to the mandrel of the shock tool and increasing the axial length of the shock tool after (a). The second annular piston is axially spaced from the first annular piston. The shock tool has a second amplitude of reciprocal axial extension and contraction at the pressure differential between the first fluid pressure in the outer housing and the second fluid pressure outside the outer housing after (b). The second amplitude of reciprocal axial extension and contraction is greater than the first amplitude of reciprocal axial extension and contraction.
An insert for a drill bit includes a base portion. In addition, the insert includes a formation engaging portion extending from the base portion. The formation engaging portion has a longitudinal axis and includes a first end, a second end opposite the first end, a first lateral side extending from the first end to the second end, and a second lateral side extending from the first end to the second end, and an elongate crown extending longitudinally from the first end to the second end and laterally from the first lateral side to the second lateral side. The first lateral side comprises a first curved surface having a first radius of curvature in top view of the insert and the second lateral side includes a second curved surface having a second radius of curvature in top view of the insert. The first radius of curvature of the first curved surface is different than the second radius of curvature of the second curved surface.
E21B 10/567 - Button-type inserts with preformed cutting elements mounted on a distinct support, e.g. polycrystalline inserts
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 10/52 - Drill bits characterised by wear resisting parts, e.g. diamond inserts the bit being of roller type with chisel- or button-type inserts
E21B 10/627 - Drill bits characterised by parts, e.g. cutting elements, which are detachable or adjustable with plural detachable cutting elements
60.
Drill bit cutter elements and drill bits including same
A cutter element for a drill bit includes a base portion having a central axis, a first end, a second end, and a radially outer 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 portion. The cutting layer includes a cutting face distal the base portion and a radially outer surface extending axially from the cutting face to the radially outer surface of the base portion. The cutting face includes a planar central region centered relative to the central axis and disposed in a plane oriented perpendicular to the central axis. Further, the cutting face includes a plurality of circumferentially-spaced cutting regions disposed about the planar central region. Still further, the cutting face includes a plurality of circumferentially-spaced relief regions disposed about the planar central region. The plurality of cutting regions and the plurality of relief regions are circumferentially arranged in an alternating manner such that one relief region is circumferentially disposed between two circumferentially adjacent cutting regions of the plurality of cutting regions. Each relief region is defined by a first edge at an intersection of the relief region and one circumferentially adjacent cutting region and a second edge at an intersection of the relief region and another circumferentially adjacent cutting region. The first edge and the second edge of each relief region are angularly spaced apart about the central axis by an angle α that ranges from 45° to 75°.
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.
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.
H01L 35/30 - SEMICONDUCTOR DEVICES; ELECTRIC SOLID STATE DEVICES NOT OTHERWISE PROVIDED FOR - Details thereof operating with Peltier or Seebeck effect only characterised by the heat-exchanging means at the junction
F03G 4/00 - Devices for producing mechanical power from geothermal energy
E21B 41/00 - Equipment or details not covered by groups
63.
CONNECTORS FOR PUMPING ASSEMBLIES AND METHODS RELATING THERETO
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.
A blowout preventer includes a housing including a longitudinal passage and a pair of ram passages extending from the longitudinal passage, a first ram assembly disposed in a first of the pair of ram passages and including first ram block assembly, and a second ram assembly disposed in a second of the pair of ram passages and including a second ram block assembly, wherein the first ram block assembly is configured to include a first configuration in which it sealingly engages an outer surface of a tubular member extending through the longitudinal passage of the housing when the blowout preventer is in a closed position, and a second configuration in which it sealingly engages the second ram block assembly when the blowout preventer is in the closed position.
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.
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.
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 including a first position that provides a first deflection angle between a longitudinal axis of the driveshaft housing and a longitudinal axis of the bearing mandrel, and a second position that provides a second deflection angle between the longitudinal axis of the driveshaft housing and the longitudinal axis of the bearing mandrel that is different from the first deflection angle, and one or more hydraulic pumps configured to actuate the bend adjustment assembly between the first position and the second position.
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 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.
B04B 1/20 - Centrifuges with rotary bowls provided with solid jackets for separating predominantly liquid mixtures with or without solid particles discharging solid particles from the bowl by a conveying screw coaxial with the bowl axis and rotating relatively to the bowl
70.
Wear resistant tubular members and systems and methods for producing the same
Some embodiments disclosed herein are directed to a tubular member including a central axis, a first end, a second end opposite the first end, an upset region between and axially spaced from the first end and the second end, and a first outer diameter axially spaced midway between the first end and the upset region. The upset region includes a second diameter which is larger than the first diameter, does not include a weld joint, and includes redistributed material from the tubular member.
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.
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
A mobile proppant delivery system may include a system for unloading proppant transport trailers, storing proppant in silos, and feeding proppant to frac operations. The system may include drive-over conveyors, swiveling distribution heads, internal silo bucket elevators, gravity feed, choke filling, and bases designed with internal conveying systems.
B65D 88/30 - Hoppers, i.e. containers having funnel-shaped discharge sections specially adapted to facilitate transportation from one utilisation site to another
B65D 88/32 - Hoppers, i.e. containers having funnel-shaped discharge sections in multiple arrangement
B65G 3/04 - Storing bulk material or loose, i.e. disorderly, articles in bunkers, hoppers or like large containers
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 blowout preventer including a housing including a central passage and a first aperture, and a first ram assembly slidably disposed in the first aperture, wherein the first ram assembly includes a ram block and an actuator configured to rotate the ram block when the ram block is disposed in the first aperture of the housing.
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.
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 19/14 - Racks, ramps, troughs or bins, for holding the lengths of rod singly or connected; Handling between storage place and borehole
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
A utility umbilical module may include an expandable frame, a plurality of extendable fluid lines arranged on the expandable frame and configured for fluid coupling between a utility plant and a drill rig, an expandable and retractable electrical system configured for electrically coupling a utility plant to a drill rig, and a ground engaging portion configured for over-the-road transport of the module.
A quick connect pipe connection for drill pipe may include a box end having an annular end surface that gives way internally to a receiving portion and externally to an engagement portion. The connection may also include a pin end configured for rotationally and longitudinally engaging the box end. The pin end may include a tapered portion configured for longitudinal insertion into the receiving portion and resisting relative rotation between the box end and the pin end. The pin end may also include a collar configured for sleeving over the engagement portion of the box end and resisting relative longitudinal motion between the box end and the pin end.
F16L 15/08 - Screw-threaded joints; Forms of screw-threads for such joints with supplementary elements
E21B 17/043 - Couplings; Joints between rod and bit, or between rod and rod threaded with locking means
F16L 37/252 - Couplings of the quick-acting type in which the connection is made by inserting one member axially into the other and rotating it to a limited extent, e.g. with bayonet-action the coupling being co-axial with the pipe the male part having lugs on its periphery penetrating into the corresponding slots provided in the female part
Several pre-assemblies holding panels of photovoltaic cells are constructed and pre-wired in a factory. The pre-assemblies are shipped to a solar farm, where they are lifted above posts secured to the ground. By being foldable, the solar panel assemblies can provide a compact shipping arrangement. Operators can connect the solar panel assemblies to a support and then unfolded the solar panel assemblies and lock them in the unfolded position.
An annular elastomeric packer for a blowout preventer includes a plurality of circumferentially spaced inserts, wherein at least one of the plurality of inserts includes a rib, and a foot pivotally coupled to the rib, and an elastomeric body coupled to the plurality of inserts and including an inner surface, wherein the foot is configured to resist deformation of the elastomeric body in response to the blowout preventer actuating from a first position to a second position.
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.
A cutter element for a drill bit includes a base portion having a central axis, a first end, and a second end. In addition, the cutter element includes a cutting layer fixably mounted to the first end of the base portion. The cutting layer includes a cutting face distal the base portion. The cutting face includes an elongate raised ridge having a first end at a radially outer surface of the cutting layer and a second end at the radially outer surface of the cutting layer. The raised ridge defines a maximum height of the cutter element measured axially from the second end of the base portion to the cutting face. The cutting face also includes a first planar lateral side surface and a second planar lateral side surface. Each planar lateral side surface extends from the raised ridge to the radially outer surface of the cutting layer.
E21B 10/567 - Button-type inserts with preformed cutting elements mounted on a distinct support, e.g. polycrystalline inserts
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 10/43 - 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
83.
Enhanced welded pipe, threaded connections, and methods for achieving the same
A tubular member includes a tube body, a tube end, an exterior surface, an interior surface, a nominal wall thickness, a longitudinal axis, a welded seam, and a patch of material. The welded seam forms an arcuate portion of the interior surface, and the patch covers a portion of the interior surface that includes a portion of the welded seam, extending from the tube end to an axially spaced first location. The resulting interior surface from the tube end to the axially spaced first location has a uniform inside diameter.
A cutter element includes a base portion having a central axis, a first end, and a second end. In addition, the cutter element includes a cutting layer fixably mounted to the first end of the base portion. The cutting layer includes a cutting face distal. The cutting face includes a planar central region centered relative to the central axis and disposed in a plane oriented perpendicular to the central axis. The cutting face also includes a plurality of circumferentially-spaced cutting regions disposed about the planar central region. Each cutting region extends from the planar central region to the radially outer surface of the cutting layer. Each cutting region slopes axially toward the base portion moving radially outward from the planar central region to the radially outer surface of the cutting layer. Further, the cutting face includes a plurality of circumferentially-spaced relief regions disposed about the planar central region. Each relief region extends from the planar central region to the radially outer surface. Each relief region slopes axially toward the base portion moving radially outward from the planar central region to the radially outer surface of the cutting layer. The plurality of cutting regions and the plurality of relief regions are circumferentially arranged in an alternating manner such that one relief region is circumferentially disposed two circumferentially adjacent cutting regions of the plurality of cutting regions.
A method includes receiving a drill bit design. The design specifies a design parameter for a plurality of cutter elements of a drill bit. The method also includes estimating a temperature value for the cutter elements based on the design parameter and a drilling parameter; estimating a wear value for the cutter elements based on the design parameter and the temperature value; updating a value of the design parameter for at least one of the cutter elements based on the wear value and a time period; and using the updated design parameter value, repeating the steps of estimating the temperature value, estimating the wear value, and updating the design parameter value until the design parameter value for the at least one of the cutter elements reaches a threshold value.
An insert for a drill bit includes a base portion having a central axis and a formation engaging portion. The formation engaging portion includes an elongate peaked ridge, a first flanking surface extending from the peaked ridge, and a second flanking surface extending from the peaked ridge. The first flanking surface is defined by a first curve rotated about a first axis and the second flanking surface is defined by a second curve rotated about a second axis. The first axis and the second axis are disposed in a reference plane that bisects the base portion and contains the central axis of the base portion. The first axis is disposed at a first radius measured in the reference plane and the second axis is disposed at a second radius measured in the reference plane. The first radius is different from the second radius.
E21B 10/567 - Button-type inserts with preformed cutting elements mounted on a distinct support, e.g. polycrystalline inserts
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 10/52 - Drill bits characterised by wear resisting parts, e.g. diamond inserts the bit being of roller type with chisel- or button-type inserts
E21B 10/627 - Drill bits characterised by parts, e.g. cutting elements, which are detachable or adjustable with plural detachable cutting elements
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.
G05D 16/20 - Control of fluid pressure characterised by the use of electric means
E21B 41/00 - Equipment or details not covered by groups
F16K 3/00 - Gate valves or sliding valves, i.e. cut-off apparatus with closing members having a sliding movement along the seat for opening and closing
F16K 17/18 - Safety valves; Equalising valves opening on surplus pressure on either side
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
Several pre-assemblies holding panels of photovoltaic cells are constructed and pre-wired in a factory. The pre-assemblies are shipped to a solar farm, where they are lifted above posts secured to the ground using, for example, using an excavator connected to an end effector. The pre-assemblies are then connected to the posts and electrically coupled to one another. Such installation of solar panels in a solar farm may be faster and less labor-intensive than other types of installation.
Detecting a breakover event during a friction test includes obtaining a hookload measurement for each of a series of time windows and generating a linear model and a nonlinear model from the plurality of hookload measurements. During run time, from the nonlinear model, an inflection point is identified from the nonlinear model, where the inflection point is determined to have occurred at a particular time window. A hookload value associated with the linear model, and a hookload value associated with the nonlinear model is determined for the particular time window. A breakover event is determined to have occurred at the particular time when the hookload value associated with the linear model at the particular time window exceeds the hookload value associated with the nonlinear model at the particular time window.
A valve for use in a hydraulic circuit to drive a piston is fluidly connected to a first actuating chamber of the hydraulic piston. The valve is piloted to close when the first chamber is pressurized. The valve vents the fluid in the first actuating chamber when the first chamber is not pressurized. The valve permits several fluid supplies connected to the chamber via check valves to be used to drive the piston. The hydraulic piston and hydraulic circuit may be implemented in a blowout preventer operating in a subsea environment to ensure safe drilling of deepwater wells.
F15B 13/02 - Fluid distribution or supply devices characterised by their adaptation to the control of servomotors
F15B 13/042 - Fluid distribution or supply devices characterised by their adaptation to the control of servomotors for use with a single servomotor operated by fluid pressure
E21B 33/035 - Well heads; Setting-up thereof specially adapted for underwater installations
F15B 11/10 - Servomotor systems without provision for follow-up action with only one servomotor in which the servomotor position is a function of the pressure
F16K 11/04 - 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 lift valves
F16K 11/044 - 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 lift valves with movable valve members positioned between valve seats
F16K 31/122 - Operating means; Releasing devices actuated by fluid the fluid acting on a piston
92.
Apparatus and method for separating solids from a solids laden drilling fluid
An apparatus for separating solids from solids laden drilling fluid is provided. The apparatus includes a shale shaker and a screen assembly. The shale shaker includes a base and a basket isolated from the base, a flow tray arranged in the basket for directing screened drilling fluid. The screen assembly includes at least one layer of screening material, a screen support having a perimeter with at least one support point within the perimeter, wherein the flow tray includes at least one raised portion to support the screen assembly. In some versions the shale shaker has a basket having side supports and at least one intermediate support arranged between the side supports. The screen assembly includes a screen support supporting at least one layer of screening material.
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
B07B 1/46 - Constructional details of screens in general; Cleaning or heating of screens
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.
F04B 23/10 - Combinations of two or more pumps the pumps being of different types at least one pump being of the reciprocating positive-displacement type
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 system for drilling a subterranean borehole. In an embodiment, the system includes a mast, and a pipe rotator coupled to the mast. The pipe rotator includes a stem that is configured to be coupled to an end of a drillstring and a motor that is configured to rotate the stem. In addition, the system includes a guide beam 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 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 method and system for drilling a wellbore. A method for drilling a wellbore includes: generating a library of defined patterns, each of the defined patterns corresponding to an operational behavior of drilling equipment used to drill the wellbore; collecting, during operation of the drilling equipment, measurements from sensors coupled to the drilling equipment; characterizing the measurements as correlating to one of the defined patterns; detecting the one of the defined patterns in the measurements; extracting a feature from the measurements; determining a condition of the drilling equipment by comparing a value of the feature to a threshold derived from the one of the defined patterns; and activating an actuator coupled to the drilling equipment to adjust operation of the drilling equipment based on the condition.
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
G05B 19/042 - Programme control other than numerical control, i.e. in sequence controllers or logic controllers using digital processors
A coupling assembly includes a coupling, a protective ring and two tubulars, the coupling of generally cylindrical shape with a channel therethrough, the coupling having at least one internal thread and two coupling ends and a pin end of at least one of the two tubulars having an external thread for threaded mating therewith so that the coupling assembly provides a connection between the two tubulars, the protective ring including a ring body for positioning adjacent an interior wall of the coupling between the two ends thereof, the ring body being generally cylindrical and having a ring channel therethrough, the protective ring includes one of a tongue and groove and at least one of the ends of at least one of the two tubulars having the other of a tongue and groove.
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.
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