A method for manufacturing a fixed cutter drill bit for drilling an earthen formation, the drill bit including a bit body, the method including (a) preparing a powdered metal matrix mixture including 5.0 wt % to 20.0 wt % of a plurality of large size particles having mesh sizes ranging from 80 mesh to 200 mesh. The plurality of large size particles consist essentially of a plurality of crushed cast tungsten carbide (WC) particles, a plurality of macrocrystalline WC particles, a plurality of spherical cast WC particles, a plurality of tungsten (W) particles, or a combination thereof. The powdered metal matrix mixture also includes at least 50.0 wt % of a plurality of medium size particles having mesh sizes ranging from 200 mesh to 325 mesh. The plurality of medium size particles consist essentially of a plurality of spherical cast WC particles. The powdered metal matrix mixture further includes a plurality of small size particles having mesh sizes ranging from 325 mesh to 600 mesh. The plurality of small size particles consist essentially of (i) a plurality of small size metal or metal alloy particles, and (ii) a plurality of small size macrocrystalline WC particles, a plurality of small size carburized WC particles, a plurality of small size spherical cast WC particles, a plurality of small size W particles, or a combination thereof. The powdered metal matrix mixture still further includes 5.0 wt % to 20.0 wt % of the plurality of small size macrocrystalline WC particles, the plurality of small size carburized WC particles, the plurality of small size spherical cast WC particles, or the combination thereof. The powdered metal matrix mixture also includes 0.0 wt % to 10.0 wt % of the plurality of small size W particles and 0.0 wt % to 7.0 wt % of the plurality of small size metal or metal alloy particles. In addition, the method includes (b) placing the powdered metal matrix mixture in a mold after (a). Further, the method includes (c) positioning an infiltration alloy on top of the powdered metal matrix mixture in the mold after (b). Still further, the method includes (d) heating the mold, the powdered metal matrix mixture in the mold, and the infiltration alloy after (c) to melt the metal or metal alloy particles and melt the infiltration alloy. Moreover, the method includes (e) infiltrating the powdered metal matrix mixture with the melted metal or metal alloy and the melted infiltration alloy during (d). The method also includes (f) cooling the mold, the melted metal or metal alloy, and the melted infiltration alloy to solidify the melted metal or metal alloy and solidify the melted infiltration alloy after (e) to form the bit body.
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.
A cutter element assembly for a fixed cutter drill bit includes a cutter element carrier configured to be fixably attached to a cutter-supporting surface of a blade of the fixed cutter drill bit. The cutter element carrier has a central axis, a first end, a second end opposite the first end, and a receptacle extending axially from the first end. The cutter element assembly also includes a cutter element having a central axis coaxially aligned with the central axis of the cutter element carrier, a first end, and a second end opposite the first end of the cutter element. The cutter element includes a substrate and a cutting layer fixably attached to the substrate. The substrate includes a shaft extending from the second end of the cutter element and a head. The cutting layer is fixably attached to the head and is disposed at the first end of the cutter element. The shaft of the substrate is slidingly disposed in the receptacle with the head seated against the first end of the cutter element carrier. The cutter element is axially locked relative to the cutter element carrier such that the cutter element is prevented from moving axially relative to the cutter element carrier. The cutter element is rotationally locked relative to the cutter element carrier such that the cutter element is prevented from rotating about the central axis of the cutter element relative to the cutter element carrier.
E21B 10/62 - Drill bits characterised by parts, e.g. cutting elements, which are detachable or adjustable
E21B 10/633 - Drill bits characterised by parts, e.g. cutting elements, which are detachable or adjustable with plural detachable cutting elements independently detachable
4.
DRILL BITS FOR DRILLING SUBTERRANEAN BOREHOLES AND MECHANICALLY LOCKED CUTTER ELEMENTS FOR SAME
A cutter element assembly for a fixed cutter drill bit includes a cutter element carrier configured to be fixably attached to a cutter-supporting surface of a blade of the fixed cutter drill bit. The cutter element carrier has a central axis, a first end, a second end opposite the first end, and a receptacle extending axially from the first end. The cutter element assembly also includes a cutter element having a central axis coaxially aligned with the central axis of the cutter element carrier, a first end, and a second end opposite the first end of the cutter element. The cutter element includes a substrate and a cutting layer fixably attached to the substrate. The substrate includes a shaft extending from the second end of the cutter element and a head. The cutting layer is fixably attached to the head and is disposed at the first end of the cutter element. The shaft of the substrate is slidingly disposed in the receptacle with the head seated against the first end of the cutter element carrier. The cutter element is axially locked relative to the cutter element carrier such that the cutter element is prevented from moving axially relative to the cutter element carrier. The cutter element is rotationally locked relative to the cutter element carrier such that the cutter element is prevented from rotating about the central axis of the cutter element relative to the cutter element carrier.
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 5 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 10 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 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
F04B 27/08 - 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
F04B 47/00 - Pumps or pumping installations specially adapted for raising fluids from great depths, e.g. well pumps
F04B 53/14 - Pistons, piston-rods or piston-rod connections
(1) Power operated oil and gas well fracturing completion and service tools, namely, an open hole ball drop system for well completions comprised of frac sleeves, frac balls, frac pipes, frac packers, and frac valves
A shale shaker system includes a shaker screen and a fluid sampling loop coupled to a collection device or shaker sump of the shale shaker system. The fluid sampling loop may include one or more of a pump, a pressure sensor, a blowdown valve, a flowmeter, or a strainer. The fluid sampling loop is used to monitor the condition or health of the shaker screen. The shale shaker system may include a flushing loop for cleaning the strainer. Related methods include using pressure differentials, flow rates, or other metrics in a fluid sampling loop to monitor the condition or health of shaker screens. The methods may include flushing the fluid sampling loop to clean it.
E21B 49/08 - Obtaining fluid samples or testing fluids, in boreholes or wells
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 1/28 - Moving screens not otherwise provided for, e.g. swinging, reciprocating, rocking, tilting, or wobbling screens
E21B 21/06 - Arrangements for treating drilling fluids outside the borehole
E21B 21/08 - Controlling or monitoring pressure or flow of drilling fluid, e.g. automatic filling of boreholes, automatic control of bottom pressure
E21B 21/10 - Valves arrangements in drilling-fluid circulation systems
E21B 27/00 - Containers for collecting or depositing substances in boreholes or wells, e.g. bailers for collecting mud or sandDrill bits with means for collecting substances, e.g. valve drill bits
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.
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
B04B 13/00 - Control arrangements specially designed for centrifugesProgramme control of centrifuges
E21B 21/06 - Arrangements for treating drilling fluids outside the borehole
9.
WELD JOINTS INVOLVING DISSIMILAR METALS AND METHODS FOR FORMING SAME
A welded joint includes a high-strength low alloy steel first member, a stainless steel second member, and a weld formed between the first and second members, the weld further including a border layer of weld material welded to the first member, the border layer comprising gamma and sigma microstructures and a body of weld material disposed between the border layer and the second member. The first and second members may be tubular. The body of weld material may be annular. A heat-affected zone of the first member may lack untempered martensite microstructures. The stainless steel may be a precipitation-hardened (PH) stainless steel, and the weld material of the border layer and the weld material of the body may both include a super duplex stainless steel.
A valve sub for a friction reduction system includes a housing including a central axis and a central passage, an uphole valve assembly, and a downhole valve assembly, wherein the uphole valve assembly and the downhole valve assembly form both a first rotary valve and a separate second rotary valve in the housing each having an open configuration and a closed configuration, wherein the valve sub has a depressurization state in which the first rotary valve is in the closed configuration and the second rotary valve is in the open configuration, and wherein the valve sub has a pressurization state in which the first rotary valve is in the open configuration and the second rotary valve is in the closed configuration whereby the valve sub is configured to hydraulically stroke a downhole end of the friction reduction system.
A robot configured for pipe handling. The robot may include an articulated arm controllable by a controller and an end effector arranged at an end of the articulated arm. The articulated arm may include two pipe engaging jaws, each jaw having an inner contour configured for engaging a pipe section. At least one of the jaws may be a fixed jaw. The end effector may be configured to restrict radial movement of the pipe section while permitting axial movement. The inner contours of the two jaws may be arranged on different planes in some embodiments. The inner contours May additionally be concave in opposing directions. The articulated arm may be configured to pivot the end effector about a central axis extending between, and parallel to, the planes of the inner contours. In some embodiments, one or both jaws may be actuatable.
E21B 15/00 - Supports for the drilling machine, e.g. derricks or masts
E21B 19/06 - Elevators, i.e. rod- or tube-gripping devices
E21B 19/084 - Apparatus for feeding the rods or cablesApparatus for increasing or decreasing the pressure on the drilling toolApparatus for counterbalancing the weight of the rods with flexible drawing means, e.g. cables
National Oilwell Varco, L.P., National Oilwell Varco, L.P. is a Limited partnership organized under the laws of Delaware. It is composed of NOW Oilfield Services, LLC, Limited liability company, Delaware ()
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 method for downhole event detection includes measuring a parameter of a wellbore using a first sensor of a drill string, and measuring the parameter of the wellbore using a second sensor of the drill string. The method also includes detecting, by surface equipment, an event in the wellbore based on a first set of measurements provided by the first sensor, and detecting, by the surface equipment, the event in the wellbore based on a second set of measurements provided by the second sensor. The method further includes assigning, by the surface equipment, a probability value to the event based on the event as detected in the first set of measurement values and the event as detected in the second set of measurement values.
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 systemsSystems specially adapted for monitoring a plurality of drilling variables or conditions
A method for downhole event detection includes measuring a parameter of a wellbore using a first sensor of a drill string, and measuring the parameter of the wellbore using a second sensor of the drill string. The method also includes detecting, by surface equipment, an event in the wellbore based on a first set of measurements provided by the first sensor, and detecting, by the surface equipment, the event in the wellbore based on a second set of measurements provided by the second sensor. The method further includes assigning, by the surface equipment, a probability value to the event based on the event as detected in the first set of measurement values and the event as detected in the second set of measurement values.
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 systemsSystems specially adapted for monitoring a plurality of drilling variables or conditions
E21B 21/08 - Controlling or monitoring pressure or flow of drilling fluid, e.g. automatic filling of boreholes, automatic control of bottom pressure
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
National Oilwell Varco, L.P., National Oilwell Varco, L.P. is a Limited partnership organized under the laws of Delaware. It is composed of NOW Oilfield Services, LLC, Limited liability company, Delaware ()
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, a solids separator in fluid communication with and upstream from the cooler, and a fluid powered jet pump for pumping the drilling fluid from the solids separator to the cooler of the drilling fluid pre-chilling system, 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.
Heavy duty construction and material handling equipment, namely cranes, winches, hoists, windlasses, pipe laying equipment, namely, j-lay systems and s-lay systems, and ancillary line handling equipment, pipe clamps, pipe rollers, umbilical winches, and abandonment and recovery systems for the preceding goods
21.
DEPTH ACTIVATED DOWNHOLE ADJUSTABLE BEND ASSEMBLIES
A downhole mud motor includes a driveshaft rotatably disposed in a driveshaft housing, a bearing mandrel coupled to the driveshaft, wherein the bend adjustment assembly includes a first configuration that provides a first deflection angle between the driveshaft housing and the bearing mandrel, wherein the bend adjustment assembly includes a second configuration that provides a second deflection angle between the driveshaft housing and the bearing mandrel, and a locking assembly including a locked configuration configured to lock the bend adjustment assembly into one of the first configuration and the second configuration until the downhole mud motor has at least one of reached a predefined depth in the wellbore, and a mud weight has reached a predefined mud weight threshold at a given depth, in response to which the locking assembly is configured to actuate from the locked configuration to an unlocked configuration.
A system for storing materials in an earthen subterranean formation includes a wellbore extending from a terranean surface into the subterranean formation, the wellbore extending from an uphole end at the terranean surface to a longitudinally opposing downhole end, a casing string extending through the wellbore, wherein the casing string is cemented in place in the wellbore, a subterranean storage chamber formed in a salt deposit of the subterranean formation and fluidically connected to the wellbore, the storage chamber at least partially filled with brine and having a lateral width that exceeds a vertical height of the storage chamber, wellbore-transportable foreign material that is stored in the storage chamber.
A method for manufacturing a fixed cutter drill bit for drilling an earthen formation includes (a) providing a mold including a rigid body and a cavity extending from an upper end of the rigid body. The cavity includes a bit body recess, a plurality of circumferentially-spaced blade recesses extending from the bit body recess, and a tool cutting structure recess extending from each blade recess. In addition, the method includes (b) placing a first binder in each tool cutting structure recess. Further, the method includes (c) filling each blade recess and the bit body recess with a powdered matrix material comprising tungsten carbide after (b). Still further, the method includes (d) placing a second binder on top of the powdered matrix material after (c). The method also includes (e) heating the mold, the first binder and the second binder after (d) to melt the first binder and the second binder. Moreover, the method includes (f) infiltrating the powdered matrix material with the melted second binder during (e). Additionally, the method also includes (g) cooling the mold, the melted first binder, and the melted second binder to solidify the melted first binder and the melted second binder after (f) to form a bit body, a plurality of blades, and a tool cutting structure.
B22F 5/00 - Manufacture of workpieces or articles from metallic powder characterised by the special shape of the product
B22F 7/06 - Manufacture of composite layers, workpieces, or articles, comprising metallic powder, by sintering the powder, with or without compacting of composite workpieces or articles from parts, e.g. to form tipped tools
E21B 10/42 - Rotary drag type drill bits with teeth, blades or like cutting elements, e.g. fork-type bits, fish tail bits
24.
FIXED CUTTER DRILL BITS AND METHODS OF MAKING SAME
A method for manufacturing a fixed cutter drill bit for drilling an earthen formation includes (a) providing a mold including a rigid body and a cavity extending from an upper end of the rigid body. The cavity includes a bit body recess, a plurality of circumferentially-spaced blade recesses extending from the bit body recess, and a tool cutting structure recess extending from each blade recess. In addition, the method includes (b) placing a first binder in each tool cutting structure recess. Further, the method includes (c) filling each blade recess and the bit body recess with a powdered matrix material comprising tungsten carbide after (b). Still further, the method includes (d) placing a second binder on top of the powdered matrix material after (c). The method also includes (e) heating the mold, the first binder and the second binder after (d) to melt the first binder and the second binder. Moreover, the method includes (f) infiltrating the powdered matrix material with the melted second binder during (e). Additionally, the method also includes (g) cooling the mold, the melted first binder, and the melted second binder to solidify the melted first binder and the melted second binder after (f) to form a bit body, a plurality of blades, and a tool cutting structure.
B22F 7/06 - Manufacture of composite layers, workpieces, or articles, comprising metallic powder, by sintering the powder, with or without compacting of composite workpieces or articles from parts, e.g. to form tipped tools
B22F 7/08 - Manufacture of composite layers, workpieces, or articles, comprising metallic powder, by sintering the powder, with or without compacting of composite workpieces or articles from parts, e.g. to form tipped tools with one or more parts not made from powder
C22C 29/08 - Alloys based on carbides, oxides, borides, nitrides or silicides, e.g. cermets, or other metal compounds, e. g. oxynitrides, sulfides based on carbides or carbonitrides based on carbides, but not containing other metal compounds based on tungsten carbide
E21B 10/42 - Rotary drag type drill bits with teeth, blades or like cutting elements, e.g. fork-type bits, fish tail bits
E21B 10/55 - 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 10/60 - Drill bits characterised by conduits or nozzles for drilling fluids
E21B 10/64 - Drill bits characterised by the whole or part thereof being insertable into or removable from the borehole without withdrawing the drilling pipe
E21B 10/54 - Drill bits characterised by wear resisting parts, e.g. diamond inserts the bit being of the rotary drag type, e.g. fork-type bits
A wrist pin assembly can include a connecting rod can be pivotably attached to a crank member. A housing can extend between a crank member end and a piston rod end. The connecting rod can extend from the crank member and into the housing through the crank member end. A crosshead can be installed within the housing. The crosshead can be operable to translate within the housing between the crank member end and the piston rod end. A wrist pin can be installed within the crosshead. The connecting rod can be pivotably attached to the wrist pin to translate the wrist pin and the crosshead within the housing in a first direction and a second direction as the crank member rotates. A plunger assembly can be directly coupled to the wrist pin and can extend from the wrist pin through the piston rod end.
A robotic pipe handling system can include at least two robotic manipulators, one positioned on either side of an individual piece of drill pipe, to pick the individual piece up and move it horizontally from one point to another. The system can include at least one elongate drill pipe storage area including a plurality of drill pipe receptacles. The system can also include a controller for coordinating movements of the first and second robotic manipulators with each other to horizontally lift the first piece of drill pipe and move the first piece of drill pipe toward a pipe-receiving area.
E21B 19/15 - Racking of rods in horizontal positionHandling between horizontal and vertical position
E21B 19/20 - Combined feeding from rack and connecting, e.g. automatically
B25J 9/02 - Programme-controlled manipulators characterised by movement of the arms, e.g. cartesian co-ordinate type
E21B 19/087 - Apparatus for feeding the rods or cablesApparatus for increasing or decreasing the pressure on the drilling toolApparatus for counterbalancing the weight of the rods by means of a swinging arm
G05B 19/18 - Numerical control [NC], i.e. automatically operating machines, in particular machine tools, e.g. in a manufacturing environment, so as to execute positioning, movement or co-ordinated operations by means of programme data in numerical form
Power operated oil and gas well fracturing completion and service tools, namely, an open hole ball drop system for well completions comprised of frac sleeves, frac balls, frac pipes, frac packers, and frac valves
A threaded connection between an end of a first tubular member having a central axis and an end of a second tubular member having a central axis coaxially aligned with the central axis of the first tubular member includes a threaded box connector disposed at the end of the first tubular member. The threaded box connector includes a box external shoulder, a box internal shoulder axially spaced from the box external shoulder, a plurality of internal threads axially positioned between the box external shoulder and the box internal shoulder, and a box seal surface axially positioned between the internal threads and the box internal shoulder. In addition, the threaded connection includes a threaded pin connector disposed at the end of the second tubular member and threadably coupled to the threaded box connector. The threaded pin connector includes a pin external shoulder that engages the box external shoulder, a pin internal shoulder axially spaced from the pin external shoulder, a plurality of external threads axially positioned between the pin external shoulder and the pin internal shoulder, and a pin nose extending axially from the plurality of external threads to the pin internal shoulder. The pin internal shoulder engages the box internal shoulder. The external threads of the threaded pin connector mate with and threadably engage the internal threads of the threaded box connector. The pin nose includes a pin seal surface that sealingly engages the box seal surface and a major pin nose section extending axially from the external threads to the pin seal surface. The pin nose has a length Lp-nose measured axially from the plurality of external threads to the pin internal shoulder, wherein the length Lp-nose is greater than or equal to 1.625 in.
A threaded connection between an end of a first tubular member having a central axis and an end of a second tubular member having a central axis coaxially aligned with the central axis of the first tubular member includes a threaded box connector disposed at the end of the first tubular member. The threaded box connector includes a box external shoulder, a box internal shoulder axially spaced from the box external shoulder, a plurality of internal threads axially positioned between the box external shoulder and the box internal shoulder, and a box seal surface axially positioned between the internal threads and the box internal shoulder. In addition, the threaded connection includes a threaded pin connector disposed at the end of the second tubular member and threadably coupled to the threaded box connector. The threaded pin connector includes a pin external shoulder that engages the box external shoulder, a pin internal shoulder axially spaced from the pin external shoulder, a plurality of external threads axially positioned between the pin external shoulder and the pin internal shoulder, and a pin nose extending axially from the plurality of external threads to the pin internal shoulder. The pin internal shoulder engages the box internal shoulder. The external threads of the threaded pin connector mate with and threadably engage the internal threads of the threaded box connector. The pin nose includes a pin seal surface that sealingly engages the box seal surface and a major pin nose section extending axially from the external threads to the pin seal surface. The pin nose has a length Lp-nose measured axially from the plurality of external threads to the pin internal shoulder, wherein the length Lp-nose is greater than or equal to 1.625 in.
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
B60P 1/16 - Vehicles predominantly for transporting loads and modified to facilitate loading, consolidating the load, or unloading with a tipping movement of load supporting or containing element actuated by fluid-operated mechanisms
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
B65G 65/40 - Devices for emptying otherwise than from the top
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.
A drilling system includes a drill string and surface equipment. The drill string includes a mud pulse transmitter. The mud pulse transmitter is configured to provide a first mud pulse transmission at a first rate responsive to drilling, and provide a second mud pulse transmission at a second rate responsive to not drilling. The surface equipment is coupled to the drill string. The surface equipment includes a mud pulse receiver. The mud pulse receiver is configured to receive the first mud pulse transmission at the first rate responsive to drilling, and receive the second mud pulse transmission at the first rate responsive to drilling. The second rate is higher than the first rate.
E21B 47/20 - 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 by modulation of mud waves, e.g. by continuous modulation
A drilling system includes a drill string and surface equipment. The drill string includes a mud pulse transmitter. The mud pulse transmitter is configured to provide a first mud pulse transmission at a first rate responsive to drilling, and provide a second mud pulse transmission at a second rate responsive to not drilling. The surface equipment is coupled to the drill string. The surface equipment includes a mud pulse receiver. The mud pulse receiver is configured to receive the first mud pulse transmission at the first rate responsive to drilling, and receive the second mud pulse transmission at the first rate responsive to drilling. The second rate is higher than the first rate.
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 47/18 - 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
E21B 47/16 - 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 drill string or casing
E21B 7/00 - Special methods or apparatus for drilling
35.
REMOVAL OF COMPONENTS FROM A GAS STREAM IN A SYSTEM COMPRISING ABSORPTION VESSELS INCLUDING NOZZLES
The systems and processes described herein can use horizontally arranged equipment to remove impurities from a gas stream using an absorber liquid that can include one or more solvents. The system can include an absorption section that contacts a gas stream with a solvent that removes one or more components from the gas stream and binds the one or more components with the solvent. The solvent with the bound gas components can then be separated from the gas stream to produce a modified gas stream having a lesser amount of the one or more components than the initial gas stream. In at least some cases, the system can include a number of absorption sections arranged sequentially and arranged horizontally and with each absorption section in the series, the amount of the one or more components included in the gas stream decreases.
B01D 53/14 - Separation of gases or vapoursRecovering vapours of volatile solvents from gasesChemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases or aerosols by absorption
An annular grappling element of a grappling tool for retrieving a downhole tool includes a body extending between a first end and a second end longitudinally opposite the first end, the body defining an inner surface extending between the first end and the second end and an outer surface also extending between the first end and the second end, herein one or more engagement members for grappling the downhole tool are formed on one of the inner surface and the outer surface of the body, and wherein the body is formed from a base material having a nickel content that is equal to or greater than 0.60 percent by weight (Wt%) and a carbon content that is equal to or less than 0.20 Wt%.
C21D 9/08 - Heat treatment, e.g. annealing, hardening, quenching or tempering, adapted for particular articlesFurnaces therefor for tubular bodies or pipes
C22C 38/08 - Ferrous alloys, e.g. steel alloys containing nickel
C22C 38/40 - Ferrous alloys, e.g. steel alloys containing chromium with nickel
An annular grappling element of a grappling tool for retrieving a downhole tool includes a body extending between a first end and a second end longitudinally opposite the first end, the body defining an inner surface extending between the first end and the second end and an outer surface also extending between the first end and the second end, herein one or more engagement members for grappling the downhole tool are formed on one of the inner surface and the outer surface of the body, and wherein the body is formed from a base material having a nickel content that is equal to or greater than 0.60 percent by weight (Wt %) and a carbon content that is equal to or less than 0.20 Wt %.
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 vibration mitigation tool may include a mandrel portion, a sleeve portion arranged about the mandrel portion and configured to move longitudinally and rotationally relative to the mandrel portion. The tool may also include a spring stack configured to control compression on the vibration mitigation tool through compression of the spring stack and to control tension on the vibration mitigation tool through compression of the spring stack. A helical engagement between the mandrel portion and the sleeve portion may also be provided.
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 non-planar surface. The non-planar surface includes a surface finish including a plurality of elongate raised ridges and a plurality of recesses positioned between the raised ridges.
A vibration mitigation tool may include a mandrel portion, a sleeve portion arranged about the mandrel portion and configured to move longitudinally and rotationally relative to the mandrel portion. The tool may also include a spring stack configured to control compression on the vibration mitigation tool through compression of the spring stack and to control tension on the vibration mitigation tool through compression of the spring stack. A helical engagement between the mandrel portion and the sleeve portion may also be provided.
An insulated drill pipe joint for a drill string of a well system includes an outer sub defining a central passage extending between a first end of the outer sub and a longitudinally opposed second end of the outer sub, wherein the outer sub includes a first connector located at the first end and a second connector located at the second end, an inner mandrel slidably received in the central passage of the outer sub and defining a central passage extending between a first end of the inner mandrel and a longitudinally opposed second end of the inner mandrel, wherein an annular insulation compartment is formed that at least partially surrounds the inner mandrel and which is sealed from the central passage of the inner mandrel, and an insulation medium located in the insulation compartment and has a greater thermal resistance than the outer sub.
09 - Scientific and electric apparatus and instruments
42 - Scientific, technological and industrial services, research and design
Goods & Services
(1) 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 (1) 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
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.
An insulated drill pipe joint for a drill string of a well system includes an outer sub defining a central passage extending between a first end of the outer sub and a longitudinally opposed second end of the outer sub, wherein the outer sub includes a first connector located at the first end and a second connector located at the second end, an inner mandrel slidably received in the central passage of the outer sub and defining a central passage extending between a first end of the inner mandrel and a longitudinally opposed second end of the inner mandrel, wherein an annular insulation compartment is formed that at least partially surrounds the inner mandrel and which is sealed from the central passage of the inner mandrel, and an insulation medium located in the insulation compartment and has a greater thermal resistance than the outer sub.
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 well system includes a rig floor, a first 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, a mast extending from the rig floor, the mast including a plurality of legs, a pipe transport assembly slidably coupled to one of the legs of the mast, wherein the pipe transport assembly includes an elevator configured to transport the pipe stand, and a winch coupled to the mast and configured to raise and lower the pipe transport assembly along the mast.
An agitator deployable in a wellbore includes a housing, a valve disposed in the housing and including a first valve body and a second valve body permitted to rotate relative to the first valve body, a first valve adapter coupled to the housing and which includes a first receptacle which receives at least a portion of the first valve body, wherein the first receptacle includes a cylindrical inner surface and an annular shoulder projecting radially inwards from the cylindrical inner surface, and a flexible valve seat positioned in the first receptacle of the first valve adapter between the first valve body and the first valve adapter, wherein the flexible valve seat has a cylindrical portion and an annular shoulder extending radially inwards from the cylindrical portion.
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
Performing a corrective action includes obtaining assembly parameters indicating assembly information of a drilling component and drilling parameters indicating drilling information associated with the drilling component, monitoring the assembly parameters and the drilling parameters for a period of time, the period of time being dynamically configured or a preconfigured period of time, comparing the assembly parameters to threshold assembly parameters and the drilling parameters to threshold drilling parameters; determining whether the assembly parameters meet the threshold assembly parameters or the drilling parameters meet the threshold drilling parameters, and triggering a corrective action that modifies an application configuration associated with the drilling component.
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 systemsSystems specially adapted for monitoring a plurality of drilling variables or conditions
E21B 4/00 - Drives for drilling, used in the borehole
E21B 7/00 - Special methods or apparatus for drilling
E21B 6/00 - Drives for drilling with combined rotary and percussive action
A downhole mud motor includes a driveshaft housing, a driveshaft rotatably disposed in the driveshaft housing, a bearing mandrel coupled to the driveshaft, and a bend adjustment assembly including a first position, wherein the bend adjustment assembly includes a second position, wherein the bend adjustment assembly includes an adjustment mandrel having a first axial position corresponding to the first position of the bend adjustment assembly and a second axial position which corresponds to the second position of the bend adjustment assembly, and wherein the bend adjustment assembly is prevented from actuating from the first position to the second position when the adjustment mandrel is in the first axial position, and wherein the bend adjustment assembly is permitted to actuate between the first position and the second position when the adjustment mandrel is in a second axial position that is axially spaced from the first axial position.
Oil and gas well sealing systems, namely, power-operated wireline severance and sealing tools for mounting to oil and gas wellheads or production pipes for cutting wireline cables and sealing openings in the oil and gas wellheads or production pipes
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 membersRigid 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 membersRigid 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 - CouplingsJoints between rod and bit, or between rod and rod
E21B 17/046 - CouplingsJoints 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.
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
E21B 10/627 - Drill bits characterised by parts, e.g. cutting elements, which are detachable or adjustable with plural detachable cutting elements
E21B 10/633 - Drill bits characterised by parts, e.g. cutting elements, which are detachable or adjustable with plural detachable cutting elements independently detachable
66.
MODULAR DRILL BITS WITH MECHANICALLY ATTACHED CUTTER ELEMENT ASSEMBLIES
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
67.
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.
A stator assembly for an ESP. The assembly can include stators with tabs and corresponding slots that prevent rotation of the stators during use in downhole activities.
09 - Scientific and electric apparatus and instruments
42 - Scientific, technological and industrial services, research and design
Goods & Services
Monitoring and control systems comprising downloadable industrial process control software, moisture sensors, electronic valve actuators, conductivity sensors for electrical heaters, and vibration sensors for air coolers, for monitoring and controlling oil and gas wellstream processing systems comprising natural gas dehydration units with catalyst media 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 Quality control services for others, namely, monitoring and controlling 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
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 featureSorting by manually actuated devices, e.g. switches
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
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
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 19/02 - Machines or pumps having pertinent characteristics not provided for in, or of interest apart from, groups having movable cylinders
F04B 23/06 - Combinations of two or more pumps the pumps being all of reciprocating positive-displacement type
F04B 47/00 - Pumps or pumping installations specially adapted for raising fluids from great depths, e.g. well pumps
F04B 53/14 - Pistons, piston-rods or piston-rod connections
F04B 53/16 - CasingsCylindersCylinder liners or headsFluid connections
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
84.
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
88.
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 managing supply chain logistics for use in the agriculture industry; downloadable mobile applications for use in managing 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
100.
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 21/08 - Controlling or monitoring pressure or flow of drilling fluid, e.g. automatic filling of boreholes, automatic control of bottom pressure
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 systemsSystems specially adapted for monitoring a plurality of drilling variables or conditions
E21B 45/00 - Measuring the drilling time or rate of penetration
