A system (400) for performing downhole logging operations includes a conductor coil (406) configured to alternate between producing a magnetic field and measuring a magnetic field induced in a formation, a power supply (402) couplable to the conductor coil (406) for providing an electrical control current to conductor coil (406), and a signal acquisition system (418) couplable to the conductor coil (406). The system (400) further includes a permanent magnet (408) coupled to the conductor coil (406), and a multi-state switch (416) operable in a first state and a second state. In the first state, the conductor coil (416) is coupled to an output of the power supply (402) and decoupled from an input of the signal acquisition system (418). In the second state, the conductor coil (406) is coupled to the input of acquisition electronics (418) and decoupled from the output of the power supply (402).
G01V 3/08 - Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination or deviation operating with magnetic or electric fields produced or modified by objects or geological structures or by detecting devices
G01V 3/10 - Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination or deviation operating with magnetic or electric fields produced or modified by objects or geological structures or by detecting devices using induction coils
G01V 3/18 - Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for well-logging
G01V 3/30 - Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for well-logging operating with electromagnetic waves
2.
APPARATUS AND METHODS FOR DETERMINING IN REAL-TIME EFFICIENCY OF EXTRACTING GAS FROM DRILLING FLUID AT SURFACE
A system and method for determining an efficiency of gas extraction. A chamber allows inflow and outflow of the drilling fluid. An amount of gas extracted from a drilling fluid flowing through the chamber at a constant rate during a dynamic process is measured. A dissolution curve is obtained indicative of a gas remaining in the chamber after the dynamic process. An amount drawn from the chamber during a static process subsequent to the dynamic process is measured. An amount of gas from the drilling fluid during the static process is determined from a difference between the amount of gas drawn from the chamber during the static process and an amount of gas indicated by the dissolution curve. The gas extraction efficiency is determined from a ratio of the amount of gas extracted during the static process and the amount of gas extracted during the dynamic process.
A drilling assembly and method of drilling a wellbore is disclosed. The drilling assembly includes a steering device having a tilt device and an actuation device. A first section and a second section of the drilling assembly are coupled through the tilt device, wherein the first section is attached to a drill bit. The actuation device includes an electromechanical actuator and causes a tilt of the tilt device to cause the first section attached to the drill bit and the drill bit to tilt relative to the second section. The wellbore is drilled using the drill bit. The electromechanical actuator is actuated to tilt the tilt device to cause the first section attached to the drill bit and the drill bit to tilt relative to the second section and to maintain the tilt geostationary while the drilling assembly is rotating to form a deviated section of the wellbore.
A control valve assembly includes a body having a fluid inlet and a fluid outlet. A portion of the body is formed from a first magnetic material. A sleeve is slidingly mounted to the body. At least a portion of the sleeve is formed from a second magnetic material. A magnetic circuit having a gap is defined within the control valve assembly. A solenoid is mounted to the body about at least a portion of the first magnetic material of the body. The solenoid is selectively activated to create a magnetic field across the gap in the magnetic circuit. The magnetic circuit causes the sleeve to slide, narrowing the gap and sliding from the first position to the second position to produce a pressure pulse in the wellbore, wherein the biasing member biases the sleeve back to the first position.
E21B 34/06 - Valve arrangements for boreholes or wells in wells
E21B 34/14 - Valve arrangements for boreholes or wells in wells operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools
A frac plug system, downhole tool and method of securing a frac plug system in a wellbore in a formation. A mandrel includes a first end and a second end. A setting assembly is coupled to the mandrel at the first end, and an anchor is arranged at the second end of the mandrel and receptive to the setting assembly. The anchor is settable to engage the wellbore. A bottom sub is arranged at the second end of the mandrel and includes a first member movable relative to the mandrel. A gas generates a pressure to shift the first member along the mandrel to move the anchor against the setting assembly, securing the setting assembly in the wellbore via radial deployment of the anchor. The mandrel is separated from the bottom sub to leave the setting assembly and the anchor in the wellbore.
E21B 33/128 - Packers; Plugs with a member expanded radially by axial pressure
E21B 23/04 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells operated by fluid means, e.g. actuated by explosion
E21B 33/129 - Packers; Plugs with mechanical slips for hooking into the casing
A frac plug system downhole tool and method of securing a frac plug system in a wellbore. A mandrel extending from a first end to a second end. A setting assembly is on the first end of the mandrel and is movable along the mandrel. An anchor is at the second end of the mandrel and is expandable to engage the wellbore. A gas generates a pressure to move the setting assembly along the mandrel to expand the anchor at the second end of the mandrel.
E21B 33/128 - Packers; Plugs with a member expanded radially by axial pressure
E21B 33/129 - Packers; Plugs with mechanical slips for hooking into the casing
E21B 23/04 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells operated by fluid means, e.g. actuated by explosion
E21B 33/1295 - Packers; Plugs with mechanical slips for hooking into the casing actuated by fluid pressure
E21B 29/02 - Cutting or destroying pipes, packers, plugs, or wire lines, located in boreholes or wells, e.g. cutting of damaged pipes, of windows; Deforming of pipes in boreholes or wells; Reconditioning of well casings while in the ground by explosives or by thermal or chemical means
E21B 36/04 - Heating, cooling, or insulating arrangements for boreholes or wells, e.g. for use in permafrost zones using electrical heaters
E21B 33/128 - Packers; Plugs with a member expanded radially by axial pressure
E21B 33/129 - Packers; Plugs with mechanical slips for hooking into the casing
A backup ring assembly has a plurality of radially offset ring members including an outermost ring member formed from plurality of axially extending segments. Each of the plurality of axially extending segments includes an outer surface. A first interlock member support is coupled to the outer surface of one of the plurality of axially extending segments of the outer most ring member. A second interlock member support is coupled to the outer surface of an another one of the plurality of axially extending segments of the outermost ring member. An interlock member includes a first end supported at the first interlock member support and a second end supported at the second interlock member support. The interlock member restrains radially outward expansion of the ring and circumferential expansion of a gap extending between the one of the axially extending segments and the another one of the axially extending segments.
E21B 23/01 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for anchoring the tools or the like
E21B 23/06 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for setting packers
E21B 33/128 - Packers; Plugs with a member expanded radially by axial pressure
Metals, such as mercury, may be removed from aqueous, hydrocarbon, or mixed oilfield or refinery fluids by: applying a sulfur compound having the general formula HS-X, wherein X is a heteroatom substituted alkyl, cycloalkyl, aryl, and/or alkylaryl group either alone or in combination with or as a blend with at least one demulsifier, a buffering agent, a pour point depressant, and/or a water clarifier to chelate the at least one metal and form a chelate complex of the sulfur compound with the at least one metal and then separating the chelate complex from the fluid.
Methods and systems for damping torsional oscillations of downhole systems are described. The systems include a downhole string, a bit support assembly configured to support and receive a disintegration device, wherein the disintegration device is disposed on an end of the downhole string and mounted to the bit support assembly, and a damping system configured at least one of on and in the bit support assembly, the damping system comprising at least one damper element arranged in contact with a portion of the bit support assembly.
Systems and methods for damping torsional oscillations of downhole systems are described. The systems include a downhole string comprising a disintegration device and a damping system at least one of in and on the downhole string, the damping system configured to damp torsional oscillations of the downhole string. The methods include installing a damping system at least one of on and in the downhole system with the downhole system including a downhole string having a disintegration device and the damping system is configured to damp torsional oscillation of the downhole string.
An anchor and seal system including a slip, a cone in radially expanding communication with the slip, an element in loadable communication with the cone, and a pusher configured to radially displace the element to reside on an element retention surface of the pusher. A method for treating a borehole including running an anchor and seal system above to depth, activating a setting arrangement to anchor and seal the anchor and seal system.
E21B 33/128 - Packers; Plugs with a member expanded radially by axial pressure
E21B 33/129 - Packers; Plugs with mechanical slips for hooking into the casing
E21B 23/01 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for anchoring the tools or the like
E21B 34/14 - Valve arrangements for boreholes or wells in wells operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools
E21B 43/267 - Methods for stimulating production by forming crevices or fractures reinforcing fractures by propping
13.
DEMULSIFYING ADDITIVE FOR SEPARATION OF OIL AND WATER
A demulsifying additive comprising a branched aliphatic compound may be introduced to a stream containing mixtures of or emulsions of oil and water in an effective amount to separate water from the oil in the stream, such as separating oil from emulsified oil-in-water and/or separating water from emulsified water-in-oil in a production fluid. The branched aliphatic compound may be grafted with a polyether via a crosslinking reaction. Alternatively, branched aliphatic compounds may be crosslinked together.
The disclosure relates to an aqueous acidizing fluid. In addition to an acid, the fluid contains an organophosphorus surfactant and/or an acid retarder. The organophosphorus surfactant may be an amino phosphonate or a phosphino carboxylate. The acid retarder comprises the combination of urea or a urea derivative and a bifunctional organic compound. Suitable bifunctional organic compounds contain at least one quaternary ammonium or phosphonium and at least one alcohol as well as salts of nitrogen containing heterocyclic rings.
A single-phase microemulsion additive may be introduced to a stream containing mixtures of or emulsions of oil and water in an effective amount to separate oil from the water in the stream and/or separating water from the oil in the stream. The single-phase microemulsion additive is formed by combining at least one demulsifier, at least one water clarifier, at least one surfactant, and optionally at least one solvent.
Methods and apparatus for estimating a presence of oil-based mud (OBM) in a downhole fluid. Methods include generating measurement values by measuring one or more gross physical properties of the downhole fluid with at least one sensor, the measurement values comprising at least one measurement value representative of each gross physical property; and estimating with at least one processor a relative concentration of OBM with respect to the downhole fluid by using a model correlating the measurement values with the relative concentration. Methods may include taking measurements from the downhole fluid in situ and/or estimating the relative concentration in real-time with respect to generating the measurement values. The model may comprise a correlation prediction function mapping the measurement values to the relative concentration, which may use the measurement values as input to predict the relative concentration.
E21B 49/08 - Obtaining fluid samples or testing fluids, in boreholes or wells
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
This disclosure is directed to the use of a portable Surface Enhance Raman Spectroscopy method to detect, quantify, and/or monitor corrosion inhibitors that are present in fluids in a wide range of concentrations in order to manage corrosion treatment in oil and gas production and refining systems or other industrial systems and to reduce the amount of time spent in obtaining data that is reliable and useful for corrosion control.
C07C 323/12 - Thiols, sulfides, hydropolysulfides or polysulfides substituted by halogen, oxygen or nitrogen atoms, or by sulfur atoms not being part of thio groups containing thio groups and singly-bound oxygen atoms bound to the same carbon skeleton having the sulfur atoms of the thio groups bound to acyclic carbon atoms of the carbon skeleton the carbon skeleton being acyclic and saturated
C07C 321/04 - Thiols having mercapto groups bound to acyclic carbon atoms of an acyclic saturated carbon skeleton
C09K 15/18 - Anti-oxidant compositions; Compositions inhibiting chemical change containing organic compounds containing nitrogen containing an amine or imine moiety
18.
ONE-WAY ENERGY RETENTION DEVICE, METHOD AND SYSTEM
A one-way energy retaining device including a body, at least a portion of which comprises a degradable material; a protrusion extending radially from the body that allows movement of the device along a separate structure in a first direction and prevents movement along the separate structure in the opposite direction.
A backup ring assembly has a plurality of radially offset ring members including an outermost ring member formed from plurality of axially extending segments. Each of the plurality of axially extending segments includes an outer surface. A first interlock member support is coupled to the outer surface of one of the plurality of axially extending segments of the outer most ring member. A second interlock member support is coupled to the outer surface of an another one of the plurality of axially extending segments of the outermost ring member. An interlock member includes a first end supported at the first interlock member support and a second end supported at the second interlock member support. The interlock member restrains radially outward expansion of the ring and circumferential expansion of a gap extending between the one of the axially extending segments and the another one of the axially extending segments.
A control valve assembly for use in a wellbore includes a body having a fluid inlet and a fluid outlet. A portion of the body is formed from magnetic material. A plunger is mounted within the body. A portion of the plunger is formed from a magnetic material. A magnetic circuit having a gap is defined within the control valve assembly. The portion of the body formed from magnetic material defines a first portion of the magnetic circuit and the portion of the plunger formed from magnetic material forms another portion of the magnetic circuit. A solenoid is mounted at the body. The solenoid is selectively activated to create a magnetic field across the gap in the magnetic circuit. The magnetic field causes the plunger to shift, narrowing the gap disengaging from the one of the fluid inlet and the fluid outlet to produce a pressure pulse in the wellbore.
An apparatus for use in a drill string configured for use in a subterranean formation includes a drive shaft coupled to a drill bit, the drill bit configured to continuously rotate and penetrate within the subterranean formation, a drill string housing that houses the drive shaft, the drive shaft continuously rotating within the drill string housing relative to the drill string housing, and a bearing assembly configured bear the drive shaft within the drill string housing, the bearing assembly comprising a first bearing surface having a first curvature.
A horizontal pumping system has a motor, a pump driven by the motor and a priming module. The pump has a discharge on a first end of the pump, a suction end on a second end of the pump, and a plurality of stages between the suction end and the discharge. Each of the plurality of stages includes an impeller and a diffuser that encases the impeller. Each diffuser is an independent pressure vessel. The priming module may be a wet priming module or a dry priming module. The priming module permits the use of the horizontal pumping system in many applications in which the liquid is not naturally present at the pump intake.
F04C 15/00 - Component parts, details or accessories of machines, pumps or pumping installations, not provided for in groups
F04C 29/00 - Component parts, details, or accessories, of pumps or pumping installations specially adapted for elastic fluids, not provided for in groups
F04C 14/00 - Control of, monitoring of, or safety arrangements for, machines, pumps or pumping installations
F04C 14/10 - Control of, monitoring of, or safety arrangements for, machines, pumps or pumping installations characterised by changing the positions of the inlet or outlet openings with respect to the working chamber
23.
DIAMOND HIGH TEMPERATURE SHEAR VALVE DESIGNED TO BE USED IN EXTREME THERMAL ENVIRONMENTS
A control valve assembly for a downhole wellbore including a body formed partially from a magnetic material. A plunger is moveably mounted in the body. A portion of the plunger is formed from a magnetic material. A magnetic circuit having a gap is arranged within the control valve assembly. The portion of the body formed from a magnetic material defines a first portion of the magnetic circuit and the portion of the plunger formed from magnetic material forms another portion of the magnetic circuit. A solenoid is mounted at the body and is selectively activated to create a magnetic field across the gap in the magnetic circuit causing the plunger to move thereby narrowing the gap to produce a pressure pulse in the wellbore.
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 34/06 - Valve arrangements for boreholes or wells in wells
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
F16K 25/00 - VALVES; TAPS; COCKS; ACTUATING-FLOATS; DEVICES FOR VENTING OR AERATING - Details relating to contact between valve members and seats
F16K 27/04 - Construction of housings; Use of materials therefor of sliding valves
F16K 31/06 - Operating means; Releasing devices magnetic using a magnet
24.
SELF-ALIGNING BEARING ASSEMBLY FOR DOWNHOLE MOTORS
An apparatus for use in a wellbore includes a drill string section, a drive shaft disposed in the drill string section, a bearing assembly connected to the drive shaft, and an alignment assembly connecting the bearing assembly to the drill string section. The alignment assembly has a first alignment member and a second alignment member slidingly engaging one another to allow at least a portion of the bearing assembly to tilt relative to the drill string section. A related method includes the steps of positioning a drive shaft in a drill string section; connecting a bearing assembly to the drive shaft using the alignment assembly, the alignment assembly having a first alignment member and a second alignment member; and allowing at least a portion of the bearing assembly to tilt relative to the drill string section using the alignment assembly by having the first alignment member and the second alignment member slidingly engage one another.
Systems, methods, and a computer readable medium are provided for automatically controlling a pump in an oil production environment. Sensor data can be collected from pump machinery and can be used to generate an advisory statement identifying a change in pump operation in regard to one or more operating conditions. The advisory plan can be used to determine an optimization action plan to maintain the operation of the pump machinery with respect to the operating conditions. The optimization action plan can include an action, a parameter, and a parameter variable and can be transmitted to a computing device configured within a supervisory control and data acquisition system and coupled to the pump machinery. The computing device can execute the optimization action plan to control the pump machinery with respect to the operating conditions.
The strength of a proppant or sand control particulate may be improved by coating the proppant to form a composite. The composite has enhanced compressive strength between about 34 to about 130 MPa and minimizes the spalling of fines at closure stresses in excess of 5,000 psi. Conductivity of fractures is further enhanced by forming a pack of the composites in the fracture.
A method for generating a well completion plan includes: evaluating a plurality of different well completion plans using a reservoir simulator to calculate dynamic flows of fluid through a subsurface formation, each well completion plan having a flow control device with location and associated flow setting or rating, and optionally a packer and location to provide output data for each well completion plan evaluation; developing a surrogate reservoir model using the output data and input data for each well completion plan evaluation; using intelligent sequential sampling of the output and input data for each well completion plan evaluation to provide intelligent sequential sampling data in response to the surrogate reservoir model not meeting a validation criterion; updating the surrogate reservoir model using the intelligent sequential sampling data; and iterating the using and the updating using a latest surrogate reservoir model until the latest surrogate reservoir model meets the validation criterion.
The strength of a proppant or sand control particulate may be improved by coating the proppant to form a composite. The composite has enhanced compressive strength between about 34 to about 130 MPa and minimizes the spalling of fines at closure stresses in excess of 5,000 psi. Conductivity of the proppant pack in the fractures is further enhanced due to the increase in strength of the particles.
A valve including a housing having a coil therein; a seat in the housing; a ball disposed against the seat, the ball rotationally responsive to a magnetic field generated in the coil.
A method and apparatus for determining a pressure in an annulus between an inner casing and an outer casing. An acoustic transducer is disposed within the casing at a selected depth within the inner casing and is configured to generate an acoustic pulse and receive a reflection of the acoustic pulse from the inner casing. A time of flight is measured of the acoustic pulse to the inner surface of the inner casing. An inner diameter of the inner casing is determined from the time of flight. The pressure in the annulus is determined from the inner diameter. A processor can be used to measure time and determine inner diameter and annulus pressure.
E21B 47/08 - Measuring diameters or related dimensions at the borehole
G01L 9/00 - Measuring steady or quasi-steady pressure of a fluid or a fluent solid material by electric or magnetic pressure-sensitive elements; Transmitting or indicating the displacement of mechanical pressure-sensitive elements, used to measure the steady or quasi-steady pressure of a fluid or fluent solid material, by electric or magnetic means
31.
PREVENTION OF BACKFLOW DURING DRILLING AND COMPLETION OPERATIONS
A system includes a drill bit, and a tubular connected thereto. The tubular is configured to be rotated to rotate the drill bit and drill a length of a borehole and cemented in place. The tubular and the drill bit form a conduit to permit cement to be pumped through the tubular and the drill bit and into an annulus. The system also includes a collar disposed between the tubular and the drill bit. The collar includes a receptacle made from a drillable material, which has a profile that corresponds to a shape of a component deployed through the length of the tubular, and is configured to form a substantially fluid tight seal between the component and the drillable material when the component is seated in the receptacle. The collar and the component prevent backflow of the cement.
A valve including a closure member having a first portion and a second portion the first and second portions in fluid tight contact with one another when closed and spaced when open, a flow tube in operative contact with the closure member.
F16K 13/02 - Other constructional types of cut-off apparatus; Arrangements for cutting-off with both sealing faces shaped as small segments of a cylinder and the moving member pivotally mounted
F16K 15/18 - Check valves with actuating mechanism; Combined check valves and actuated valves
F16K 31/528 - Mechanical actuating means with crank, eccentric, or cam with pin and slot
33.
METHOD AND APPARATUS FOR PREVENTING PREMATURE SET OF LINER TOP PACKER
A tool for use in a wellbore includes a first tubular having an outer surface and an inner surface defining a first conduit. The inner surface includes a dog engagement zone. A second tubular includes an outer surface portion and an inner surface portion defining a second conduit. The second tubular extends into the first conduit and including a dog opening having a dog support. A dog is arranged in the dog opening. The dog includes an outer surface contour that engages with the dog engagement zone and an inner surface including a recess that engages with the one or more dog supports. The dog is moveably retained between the first tubular and the second tubular.
E21B 23/02 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for locking the tools or the like in landing nipples or in recesses between adjacent sections of tubing
123456 161411 alkyl, and where x ranges from 1 to 6, may be contacted with a hydrocarbon stream to remove or extract non-acidic contaminants, such as thiophenes, benzothiophenes, alkyl sulfides, alkyl disulfides, mercaptans, aromatics, oxygenates, metals, olefins, and combinations thereof, from the hydrocarbon stream. The extraction solvent may include co-solvents and the hydrocarbon stream may be in gas and/or liquid form.
C10G 21/02 - Refining of hydrocarbon oils, in the absence of hydrogen, by extraction with selective solvents with two or more solvents, which are introduced or withdrawn separately
Systems, methods, and computer readable mediums are provided for predicting a cache policy based on usage patterns. Usage pattern data can be received and used with a predictive model to determine a cache policy associated with a datastore. The cache policy can identify the configuration of predicted output data to be provisioned in the datastore and subsequently provided to a client in a just-in-time manner. The predictive model can be trained to output the cache policy based on usage pattern data received from a usage point, a provider point, or a datastore configuration.
G06F 12/0866 - Addressing of a memory level in which the access to the desired data or data block requires associative addressing means, e.g. caches for peripheral storage systems, e.g. disk cache
A gas-lift well including a casing extending down a wellbore, production tubing extending within the casing, a gas system for inserting compressed gas into an annular space between the casing and the production tubing, at least one gas-lift input extending from the annular space, through the production tubing, and to an interior of the production tubing, and at least one fluid flow regime modifier within the production tubing and at least partially within a fluid column of the production tubing, the at least one fluid flow regime modifier configured to reduce fluid fallback and impart a turbulent flow regime to at least a portion of the fluid column.
An apparatus for generating power includes a fluid chamber configured to receive borehole fluid, one or more conductive coils surrounding the fluid chamber, a reciprocating magnetic shuttle disposed in the fluid chamber and dividing the fluid chamber into a first volume and a second volume, a first conduit connected to the first volume, and a second conduit connected to the second volume, the first conduit and the second conduit extending from a tubular conduit to an annulus. The apparatus includes a switching assembly configured to alternate between a first operating state where the first volume is in fluid communication with the annulus and a second operating state where the first volume is in fluid communication with the tubular conduit, to alternate a direction of differential pressure between the first volume and the second volume and cause the magnetic shuttle to move in a reciprocating motion and generate an electric current.
H02K 35/02 - Generators with reciprocating, oscillating or vibrating coil system, magnet, armature or other part of the magnetic circuit with moving magnets and stationary coil systems
H02P 9/02 - Arrangements for controlling electric generators for the purpose of obtaining a desired output - Details
A guiding sleeve for aligning downhole tubulars includes a body having a first end portion, a second end portion and an intermediate portion extending therebetween. The first end portion is receptive of a terminal end of a first tubular and the second end portion includes a guiding feature that promotes axial alignment of the first tubular with a second tubular.
A guiding sleeve for aligning downhole tubulars includes a body having a first end portion, a second end portion and an intermediate portion extending therebetween. The first end portion is receptive of a terminal end of a first tubular and the second end portion includes a guiding feature that promotes axial alignment of the first tubular with a second tubular.
A downhole tool including a body having a hydraulic fluid chamber, and a flexible multi-layer barrier impermeable to gas and water mounted at the body separating the hydraulic fluid chamber from fluids external to the body. The flexible multi-layer barrier including a first elastomeric layer, a second elastomeric layer, and a gas impermeable layer arranged between the first elastomeric layer and the second elastomeric layer, the gas impermeable layer being formed from a metal layer.
A shank assembly includes a neck portion, a shank portion defining a cylindrical aperture extending therethrough, and an anchor tube secured to the neck portion and extending through the shank portion, the anchor tube and the shank portion defining an annular cavity therebetween, and an electronics module disposed within the annular cavity. The annular cavity is formed to maximize space for electronics while maintaining structural integrity of a crown and shank of an earth-boring tool. A method includes disposing the anchor tube of a shank assembly through the cylindrical aperture and securing the anchor tube to a neck portion of the shank assembly, disposing the electronics module within the annular cavity, and disposing the shank portion and anchor tube of the shank assembly at least partially within a crown of the earth-boring tool such that annular cavity extends into the crown in an axial direction a distance that is between about 10% and about 80% of an overall axial length of the crown.
A downhole assembly includes a first tubular including a first shoulder and a second tubular including a second shoulder. The assembly further includes a transmission element having a first portion disposed in the first shoulder, the first portion includes an electrically conductive member having a first arc length and a second portion disposed in the second shoulder. The second portion includes a contacting element having a second arc length that is substantially less than the first arc length and further includes an outer insulating carrier that defines a groove. The contacting element is disposed in the groove. When the first tubular is joined to the second tubular, the contacting element contacts the electrically conductive member and the second portion defines at least one region between the electrically conductive member and the second portion in areas of the groove where the contacting element does not contact the electrically conductive member.
E21B 17/046 - Couplings; Joints between rod and bit, or between rod and rod with ribs, pins, or jaws, and complementary grooves or the like, e.g. bayonet catches
E21B 17/042 - Couplings; Joints between rod and bit, or between rod and rod threaded
A seal assembly for downhole use that includes a sealing ring, and a backup ring set generally coaxial with and adjacent to the sealing ring. A height of the backup ring exceeds a diameter of the sealing ring; and is disposed on a low pressure side of the seal assembly to prevent the sealing ring from extruding into the low pressure side. The backup ring is made of a core and a coating on the core. Material properties of the coating are generally unaffected when exposed to downhole conditions, and the coating prevents diffusion of fluid or gas molecules into the low pressure side.
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
44.
SYSTEMS AND METHODS TO CONTROL DRILLING OPERATIONS BASED ON FORMATION ORIENTATIONS
Systems and methods for controlling subsurface drilling operations are described. The methods include performing the subsurface drilling operation using a bottomhole assembly having a disintegrating device, detecting, with a sensor, a formation layer orientation, approaching, with the disintegrating device, a rock layer, and generating a steering command to change an angle of attack of the disintegrating device relative to the rock layer based on the detected formation layer orientation.
E21B 44/00 - Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systems; Systems specially adapted for monitoring a plurality of drilling variables or conditions
E21B 49/00 - Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
E21B 41/00 - Equipment or details not covered by groups
45.
MOTORS FOR DOWNHOLE TOOLS DEVICES AND RELATED METHODS
A motor includes one or more actuator, one or more one passive members, and one or more pushing members. The actuator(s) vibrate along a first axis. The vibrations vary a dimension of the actuator(s) as measured along the first axis. The passive member(s) rotate around a second axis that is substantially parallel to the first axis. The pushing member(s) are positioned between the actuator(s) and the passive member(s). The pushing member(s) are fixed to the actuator(s) and have a contact surface frictionally engaging and applying a mechanical force to the passive member (s). The pushing member(s) have an asymmetric rigidity along the first axis. The motor and a power consumer may be conveyed into a wellbore. The motor may be energized to supply mechanical power to the power consumer.
A system for subterranean deployment in a wellbore includes an expandable tubular having an outer surface supporting at least one anchor slip and an inner surface including a running tool engagement element, and a running tool for deploying the expandable tubular into the wellbore. The running tool includes an inner surface portion defining a passage and an outer surface portion supporting a forcing cone for expanding at least a portion of the expandable tubular, and a tubular support system selectively engaging with the running tool engagement element.
E21B 23/01 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for anchoring the tools or the like
E21B 23/02 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for locking the tools or the like in landing nipples or in recesses between adjacent sections of tubing
E21B 43/10 - Setting of casings, screens or liners in wells
E21B 33/13 - Methods or devices for cementing, for plugging holes, crevices, or the like
47.
EVALUATION OF FORMATION FRACTURE PROPERTIES USING NUCLEAR MAGNETIC RESONANCE
222 distribution based on a cut-off time into a first volumetric indicative of matrix and pore responses and a second volumetric indicative of fracture responses, estimate a pore size distribution based on the second volumetric, and calculate a fracture aperture size distribution based on the pore diameter.
G01V 3/32 - Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for well-logging operating with electron or nuclear magnetic resonance
E21B 49/00 - Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
E21B 41/00 - Equipment or details not covered by groups
48.
POWER-EFFICIENT TRANSIENT ELECTROMAGNETIC EVALUATION SYSTEM AND METHOD
A system (400) for performing downhole logging operations includes a power supply (402) for providing a current and a conductor coil (406) electrically coupled to receive the current from the power supply (402). The system (400) further includes a switch (410) electrically coupled to the power supply (402) for controlling current provided to the conductor coil (406) and enabling a pulse of current to be supplied to the conductor coil (406) for an "on" duration and turning off current provided to the conductor coil (406) for an "off' duration after the "on" duration, in which the "off' duration lasts longer than the "on" duration. The system (400) also includes a permanent magnet (408) coupled to the conductor coil (406). The conductor coil (406) receives the pulse of current from the power supply (402) during the "on" duration and not receiving current during the "off' duration. The pulse of current causes the permanent magnet (408) to reverse polarity and generate a transient magnetic field.
G01F 1/58 - Measuring the volume flow or mass flow of fluid or fluent solid material wherein the fluid passes through a meter in a continuous flow by using electric or magnetic effects by electromagnetic flowmeters
G01N 27/10 - Investigation or analysis specially adapted for controlling or monitoring operations or for signalling
G01N 27/90 - Investigating or analysing materials by the use of electric, electrochemical, or magnetic means by investigating magnetic variables for investigating the presence of flaws using eddy currents
H01F 7/06 - Electromagnets; Actuators including electromagnets
G01V 1/40 - Seismology; Seismic or acoustic prospecting or detecting specially adapted for well-logging
G01V 3/08 - Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination or deviation operating with magnetic or electric fields produced or modified by objects or geological structures or by detecting devices
G01V 3/18 - Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for well-logging
G01V 3/28 - Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for well-logging operating with magnetic or electric fields produced or modified either by the surrounding earth formation or by the detecting device using induction coils
G01V 3/30 - Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for well-logging operating with electromagnetic waves
G01V 3/32 - Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for well-logging operating with electron or nuclear magnetic resonance
A method of in situ ultrasonic flow meter validation includes receiving data characterizing first signal diagnostics and data characterizing a first speed of a first acoustic signal through a gas mixture along a first path in a pipe. The first speed of the first acoustic signal is detected by a first channel of an ultrasonic flow meter including a first pair of transducers that are separated by a first path length of the first path. The gas mixture is configured to flow along a flow path in the pipe. The method also includes determining a status associated with the ultrasonic flow meter based on the data characterizing the first signal diagnostics and/or a difference between the first speed of the first acoustic signal and an independently calculated speed of sound. The speed of sound is calculated based on one or more properties of the gas mixture.
G01F 1/66 - Measuring the volume flow or mass flow of fluid or fluent solid material wherein the fluid passes through a meter in a continuous flow by measuring frequency, phase shift or propagation time of electromagnetic or other waves, e.g. using ultrasonic flowmeters
A system including an energy industry operation component and a processing system associated with the energy industry operation component is provided. The processing system includes an accelerator and is configured to perform at least one of image segmentation and vision analysis for authenticated lockout, image segmentation and vision analysis for performance audit, or augmented reality rendering and streaming.
A pump that is configured to lift fluids through a tubing string includes a gas mitigation system and a screen flush module. The gas mitigation system has a canister with an interior and an intake screen. The gas mitigation system further includes an intake tube that extends into the canister. The screen flush module is configured to flush solids particles trapped in the intake screen.
An anchor including a tubular body having a longitudinal axis, a number of wedges defined in the tubular body, the wedges having edges defined by surfaces at least one of the edges at a point along that edge having a first angle and at the same or another point along that edge having a second angle.
E21B 23/01 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for anchoring the tools or the like
E21B 23/06 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for setting packers
A downhole tool includes a setting tool having an outer surface, an inner surface defining a passage and a terminal end. An actuator mechanism is arranged in the passage. A setting member is arranged at the terminal end in the passage. The setting member includes a side portion that is angled radially inwardly from a first end portion to a second end portion. A collet member extends over the setting member, and a seal member is operatively connected to the collet member at the second end portion of the setting member.
An apparatus for monitoring deployment of filtration media at least partially surrounding a tubular disposed in a borehole penetrating the earth includes a carrier configured to be conveyed through the tubular, a low-frequency acoustic wave source disposed on the carrier and configured to transmit acoustic waves in a frequency that is less than 3000 Hz into the tubular, and an acoustic wave receiver disposed on the carrier a distance from the low-frequency acoustic wave source and configured to receive acoustic waves transmitted by the low-frequency acoustic wave source. The apparatus also includes a controller configured to compare data characterizing the received acoustic waves to reference data characterizing acoustic waves with the filtration media not deployed.
G01S 3/80 - Direction-finders for determining the direction from which infrasonic, sonic, ultrasonic, or electromagnetic waves, or particle emission, not having a directional significance, are being received using ultrasonic, sonic, or infrasonic waves
55.
FRACTURE PRESSURE TRANSMISSION TEST APPARATUS WITH FLOWBACK MODULE
In a fracture pressure transmission test apparatus utilizing fracture simulating slotted discs, the apparatus can assess the effectiveness of a lost circulation material (LCM) in a test fluid, allow for the assessment of the ability of the LCM to reduce pressure transmission to a tip of a fracture to prevent fracture propagation, and allow for the simulation of flow back to assess the ease of clean-up for reservoir applications.
E21B 49/00 - Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
56.
FLUID SUBSTITUTION METHOD FOR T2 DISTRIBUTIONS OF RESERVOIR ROCKS
A method for transforming an earth formation and/or production equipment based on correcting nuclear magnetic resonance (NMR) data to account for partially water-saturated rock includes: receiving NMR logging data having echo-trains for an earth formation; inverting the echo-trains to provide transverse relaxation time constant (T2) distributions for various components of fluid in the earth formation; substituting a T2 distribution for mobile water of fully water-saturated rock for a T2 distribution for mobile water of partially water-saturated rock based on values of the mobile water T2 distribution of partially water-saturated rock and a total porosity constraint; summing the T2 distribution for mobile water of fully water-saturated rock and a T2 distribution for an immobile water component of the fluid to provide a T2 distribution for fully water-saturated rock; and transforming the earth formation and/or the production equipment based on a parameter derived from the T2 distribution for fully water-saturated rock.
E21B 49/00 - Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
E21B 43/16 - Enhanced recovery methods for obtaining hydrocarbons
E21B 41/00 - Equipment or details not covered by groups
G01V 3/32 - Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for well-logging operating with electron or nuclear magnetic resonance
57.
GAS-LOCK RE-PRIME SHAFT PASSAGE IN SUBMERSIBLE WELL PUMP AND METHOD OF RE-PRIMING THE PUMP
A well fluid centrifugal pump (19) has a shaft passage (59) in the shaft (37). The shaft passage has an open upper end above the impellers (45) and a closed lower end below the impellers. An outlet port (61) extends laterally from the shaft passage. A gas-lock re-priming device (63) in the shaft passage diverts a portion of well fluid in the discharge adapter bore (41) through the shaft passage and out the outlet port. The re-priming device may be a pressure actuated valve (63) that is biased to a closed position and opens when the pressure in the discharge adapter bore drops below a minimum. Alternately, the re-priming device may be an orifice member (123) with an orifice passage (125) that continuously diverts a portion of the well fluid in the discharge adapter bore (119) out the outlet port.
A downhole tool has a setting cone including a body having an outer surface having a first end, a second end. At least a portion of the body includes a taper at the second end. A passage extends through the body. The passage includes a first portion having a first diameter and a second portion having a second diameter that is less than the first diameter. An anchor is arranged at the second end of the setting cone. The anchor includes a central passage that aligns with the passage through the setting cone. A mandrel extends through the passage of the setting cone and the central passage of the anchor. The mandrel includes a first end portion, a second end portion and an intermediate section. A conduit extends from the first end portion toward the second end portion. A portion of the conduit defines an actuation chamber.
A surface pumping system has a motor and a pump driven by the motor. The pump has a discharge on a first end of the pump, a suction end on a second end of the pump, and a plurality of stages between the suction end and the discharge. Each of the plurality of stages includes an impeller and a diffuser that encases the impeller. Each diffuser is an independent pressure vessel. In some embodiments, the diffuser and impeller in each stage are large and configured for use in low net positive suction head (NPSH) applications.
A downhole tool includes a setting cone having a body including an outer surface. The body has a first end, a second end and an intermediate portion. At least a portion of the body includes a taper at the second end. A passage extends through the body from the first end to the second end. An anchor is arranged at the second end. The anchor includes a first end section receptive of the setting cone and a second end section. A mandrel extends through the passage of the setting cone and the anchor. The mandrel includes a first end portion, a second end portion and an intermediate section. A bottom sub is arranged at the second end section of the anchor. The bottom sub includes a first member fixedly mounted to the mandrel and a second member that is shiftable relative to the mandrel.
Carbon quantum dots may be introduced into oil-based downhole fluids, such as drilling fluids, completion fluids, stimulation fluids, remediation fluids, and combinations thereof, or into distillate fuels, to increase their electrical conductivity and improve or maintain their performance in oil production and refining operations, in both low and high shear conditions.
A chemically modified polysaccharide additive may be introduced to a wastewater stream in an effective amount to remove oil-coated particulates and/or heavy metal contaminants from the wastewater stream. The chemically modified polysaccharide includes at least one sulfur-containing moiety and/or nitrogen-containing moiety and the contaminants may be removed by using this chemically modified polysaccharide to capture the contaminants and separating out the captured contaminants.
An embodiment of a fluid bypass apparatus includes an axially elongated body configured to be deployed in a borehole in an earth formation, the body including a pilot conduit that allows fluid to flow through the body and a bypass conduit extending from the pilot conduit to an exterior of the body and defining a fluid flow path from the primary conduit to the exterior of the body, The apparatus also includes a modular valve insert housed within the bypass conduit, the valve insert being removable and replaceable, the modular valve insert configured to obstruct the fluid flow path and configured to automatically open in response to a pressure or flow rate through the primary conduit meeting or exceeding a selected threshold pressure or flow rate.
Methods, systems, devices, and products for hydrocarbon tubular evaluation. Methods comprise conveying the logging tool in the tubular with a carrier; inducing with a transmitter a horizontal shear (SH) wave; identifying higher order SH mode signals received at a plurality of offset receivers responsive to a higher order SH mode engendered by the horizontal shear (SH) wave; estimating a dominant frequency for higher order SH mode from the higher order SH mode signals; estimating a group velocity for the higher order SH mode from the higher order SH mode signals; and estimating a tubular parameter using the dominant frequency and the group velocity. The tubular parameter may be at least tubular thickness. The method includes estimating the tubular parameter independent of the fundamental horizontal shear wave mode (SHO).
G01B 15/02 - Measuring arrangements characterised by the use of electromagnetic waves or particle radiation, e.g. by the use of microwaves, X-rays, gamma rays or electrons for measuring thickness
G01N 29/14 - Investigating or analysing materials by the use of ultrasonic, sonic or infrasonic waves; Visualisation of the interior of objects by transmitting ultrasonic or sonic waves through the object using acoustic emission techniques
G01N 29/46 - Processing the detected response signal by spectral analysis, e.g. Fourier analysis
An acoustic device deployment system including an acoustic device, a pad disposed upon the acoustic device, a device displacer operatively connected to the acoustic device that during use causes the device to move radially outwardly into contact with another structure.
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
A submersible well pump assembly (11) has a communication path (49, 51) for communicating motor lubricant (37) to an interior of a pressure equalizer (41). A check valve passage (55) with a check valve (57) leads from the communication path to a pressure equalizing chamber (43). A dip tube (59) has a dip tube inlet (61) at the check valve passage below the check valve and a dip tube outlet (63) in the pressure equalizing chamber. The dip tube is filled with motor lubricant to retard migration of well fluid from the pressure equalizing chamber into contact with the check valve.
A method includes obtaining a dielectric measurement of a downhole formation (902). The method also includes processing the dielectric measurement via a trained machine learning system (904). The method further includes determining water saturation and at least one classification or textural parameter of the downhole formation, via the machine learning system, based at least in part on the dielectric measurement (906). The method includes assigning water saturation and at least one of the classification or the textural parameter to the downhole formation (908).
A method of analyzing a well sample for a well treatment additive includes contacting the sample with functionalized metallic nanoparticles that contain metallic nanoparticles functionalized with a functional group including a cyano group, a thiol group, a carboxyl group, an amino group, a boronic acid group, an aza group, an ether group, a hydroxyl group, or a combination including at least one of the foregoing; irradiating the sample contacted with the functionalized metallic nanoparticles with electromagnetic radiation at a selected energy level; measuring a Raman spectrum emitted from the sample; and determining presence, type or concentration of the well treatment additive in the sample from the Raman spectrum.
A cyanide-functionalized gold nanoparticle. A method of making cyanidefunctionalized gold nanoparticles includes forming an aqueous reaction mixture comprising a gold precursor and glycine, keeping the reaction mixture at about 18C to about 50C for at least 6 days to provide formation of the cyanide-functionalized gold nanoparticles, and isolating the cyanide-functionalized gold nanoparticles from the reaction mixture. A method of analyzing a sample, comprising contacting cyanide-functionalized gold nanoparticles with the sample and performing an analytical method on the sample. A sensor comprises cyanidefunctionalized gold nanoparticles.
B22F 1/00 - Metallic powder; Treatment of metallic powder, e.g. to facilitate working or to improve properties
B22F 9/24 - Making metallic powder or suspensions thereof; Apparatus or devices specially adapted therefor using chemical processes with reduction of metal compounds starting from liquid metal compounds, e.g. solutions
A submersible well pump (13) has diffusers (49) fixed within the housing (25) and an impeller (63) mounted between each of the diffusers. Spacer sleeves (71) located between and in abutment with hubs (65) of adjacent ones of the impellers define a stack (73) wherein the impellers rotate in unison with the shaft (29) and are axially movable in unison with each other relative to the shaft. A stop shoulder (75) on the shaft abuts the lower end of the stack. A spring (77) mounted in compression around the shaft in abutment with the upper end of the stack urges the lower end of the stack against the stop shoulder. Upward movement of the stack requires further compression of the spring. Up thrust and down thrust gaps (81, 87) between each impeller and adjacent diffusers prevent up thrust and down thrust from being transferred to any of the diffusers.
A pumping system includes a motor and a drive shaft configured for rotation by the motor. The pumping system includes an upper pump positioned above the motor, an upper pump shaft and an upper directional coupling connected between the drive shaft and the upper pump shaft. The upper directional coupling is configured to lock the upper pump shaft to the drive shaft when the drive shaft is rotated in a first direction. The pumping system further includes a lower pump positioned below the motor, a lower pump shaft, and a lower directional coupling connected between the drive shaft and the lower pump shaft. The lower directional coupling is configured to lock the lower pump shaft to the drive shaft when the drive shaft is rotated in a second direction.
An apparatus for removing at least a section of a tubular includes an axially elongated body configured to be advanced through an inner tubular in a borehole to a selected location, the inner tubular disposed within an outer tubular in the borehole and having a diameter that is less than a diameter of the outer tubular. The apparatus also includes a cutter configured to be actuated between a closed position in which the cutter is disposed within the body and an open position in which the cutter extends radially, the cutter having a length sufficient to engage and cut the outer tubular, the cutter configured to be advanced in an axial cutting direction as the outer tubular is cut. The apparatus further includes an automatic stabilization member disposed on the cutter, the stabilization member configured to restrict lateral movement of the cutter by contacting the outer tubular during cutting.
E21B 29/00 - Cutting or destroying pipes, packers, plugs, or wire lines, located in boreholes or wells, e.g. cutting of damaged pipes, of windows; Deforming of pipes in boreholes or wells; Reconditioning of well casings while in the ground
E21B 29/06 - Cutting windows, e.g. directional window cutters for whipstock operations
73.
SCREEN ASSEMBLY AND METHOD OF FORMING A SCREEN ASSEMBLY
A screen assembly for subsurface systems including a tubular having an outer surface. A first screen portion and a second screen portion extend about the outer surface. The second screen portion is displaced from the first screen portion by a void region. A plurality of weld plugs is mounted about the outer surface of the tubular in the void region. A centralizing ring extends about the tubular at the void region. The centralizing ring extending over each of the first screen portion and the second screen portion and is mechanically joined to the tubular through the plurality of weld plugs.
A method of treating a wellbore comprises supporting a first tubular member in a housing; coupling a second tubular member to the first tubular member via a connector; the first tubular member, the second tubular member, or both comprising a chemical deployment modular device charged with a plurality of particulates preloaded with a well treatment additive; and deploying the first and second tubular members into the wellbore.
Configurable ovoid units, earth-boring tools including configurable ovoid units, and related methods are disclosed. An earth-boring tool may include a body including at least one blade. The earth-boring tool may further include a cutting element secured to the at least one blade and including at least one sensor configured to sense at least one condition of the cutting element. Moreover, the earth-boring tool may include at least one configurable ovoid unit disposed at least partially within the at least one blade and comprising an adjustable ovoid head. Additionally, the earth-boring tool may include a control module disposed within the earth-boring drilling tool. The control module may be configured to receive sensor data from the at least one sensor, and to convey at least one signal to the at least one ovoid unit for configuring the at least one ovoid unit in response to the sensor data.
E21B 44/00 - Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systems; Systems specially adapted for monitoring a plurality of drilling variables or conditions
E21B 10/62 - Drill bits characterised by parts, e.g. cutting elements, which are detachable or adjustable
E21B 10/43 - Rotary drag type drill bits with teeth, blades or like cutting elements, e.g. fork-type bits, fish tail bits characterised by the arrangement of teeth or other cutting elements
E21B 10/55 - Drill bits characterised by wear resisting parts, e.g. diamond inserts the bit being of the rotary drag type, e.g. fork-type bits with preformed cutting elements
A method for fabricating a perforating gun includes forming an expendable hollow carrier (EHC) (300) via a drawing process. The method also includes determining a wall thickness (310) of the EHC (300) is above a threshold. The method includes machining a coupling component (414) to at least one end of the EHC. The method further includes installing perforating components within an interior of the EHC (300).
A pumping system has a motor, a shaft assembly connected to the motor, a production pump connected to the shaft assembly and driven by the motor, an electrical generator connected to the shaft assembly and driven by the motor, an oil circulation pump connected to shaft assembly and driven by the motor, and a heat exchanger. The heat exchanger includes an outer housing, a heat exchange core inside the outer housing, a plurality of heat exchange fluid passages extending through the heat exchange core, and one or more thermoelectric cooling modules in contact with the outer housing and the heat exchange core. The one or more thermoelectric cooling modules are powered by the output from the electrical generator. The oil circulation pump circulates motor lubricant oil between the motor and the heat exchanger.
Systems and methods for sealing a pothead connection to prevent external fluids from leaking into an ESP motor. In one embodiment, a pothead housing has a set of sealing assemblies, where each of the sealing assemblies has a sealing body that is positioned in a port of the motor's housing to form a direct seal against both a corresponding motor lead extension cable and the motor housing. The sealing assembly has a pothead terminal that is electrically connected to the conductor of the corresponding cable. When the pothead is secured to the motor housing, the pothead terminal engages a corresponding motor housing terminal positioned in the port. The motor housing terminal is connected to the motor windings, so this electrically connects the motor lead to the windings. An insulator is positioned to electrically isolate the motor housing terminal from the housing itself.
A cleaning agent comprising a polyacrylate terpolymer and a maleic olefin compound may be added to an aqueous system having a metal surface, such as a metal surface of a heat exchanger, in a concentration sufficient to remove fouling deposits from the metal surface in neutral or alkaline conditions. The removal of fouling deposits with the application of the cleaning agent may occur while the system is shut down or in service.
A test skid for a pumping system is configured to evaluate the performance of a pump. The test skid includes a motor and a torque-thrust chamber connected between the motor and the pump. The torque-thrust chamber has a torque meter and a thrust bearing. The thrust bearing is positioned between the torque meter and the motor such that the torque meter is connected directly to the pump through a pump input shaft. In this configuration, the torque meter measures the torque applied directly to the pump without the need to account for losses through an intermediate thrust bearing.
An organic blend chemical additive comprising more than 50 wt.% organic solvent (e.g. methanol and/or ethylene glycol), less than 10 wt.% water, a nitrate salt, a maleic acid copolymer, and optionally an imidazoline may be delivered to a production well through a conduit having a stainless steel and corrosion resistant metal alloy surface, such as a capillary string or an umbilical tubing, the organic blend chemical additive being shown to be useful in inhibiting localized corrosion of and improving the repassivation of the equipment or conduit.
C09K 8/54 - Compositions for in situ inhibition of corrosion in boreholes or wells
E21B 37/06 - Methods or apparatus for cleaning boreholes or wells using chemical means for preventing or limiting the deposition of paraffins or like substances
E21B 41/02 - Equipment or details not covered by groups in situ inhibition of corrosion in boreholes or wells
Systems and methods for enabling communication in a downhole power and communications system installed in a well, where one or more components of a wired backbone of the system have failed. Equipment positioned at the surface of a well is connected to a wired power and communication backbone that has one or more conductors and one or more nodes with standardized interfaces that enable downhole devices to be interchangeably connected to the wired backbone. When the wired backbone has failed at one or more points, preventing wired communications between the surface equipment and one or more downhole devices installed at the nodes, one or more wireless-enabled modules are installed at corresponding nodes of the wired backbone to establish wireless channels that bridge the failed portion of the wired backbone and thereby enable communication between the surface equipment and the downhole devices.
E21B 47/14 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling using acoustic waves
H04B 3/54 - Systems for transmission via power distribution lines
Certain sugars, when exposed to high temperatures, undergo oxidation to produce acidic species. Certain sugar alcohols are also acid precursors. The acidification process is a function of temperature, salinity, pH, and/or the pres¬ ence of an agent, such as an accelerator or a retarder. The rate of acidification may be controlled within a filter cake breaker fluid in order to achieve a prede- termined fluid pH after a selectable period of time. The time controllable nature of the acidification allows the development of filter cake breaker fluids with an engineered activity delay.
Systems and methods for vibration attenuation, and for investigating a subsurface volume of interest from a borehole. System embodiments may include a vibration attenuation system, comprising: at least one vibration attenuator configured to dynamically isolate a vibration source, the at least one vibration attenuator comprising metamaterial defining a plurality of cells; wherein at least one cell of the plurality of cells comprises a plurality of sub-cells azimuthally arrayed about an axis of alignment, and at least one sub-cell of the plurality is defined by a solid, the at least one sub-cell including a plurality of cell segments substantially oriented in alignment with a mapping geometry comprising an inversion of a canonical tangent circles mapping. The vibration source may comprise an acoustic source. The system may have an enclosure having the acoustic source and the at least one receiver disposed therein, with the at least one acoustic attenuator is positioned between.
E21B 49/00 - Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
G01V 1/40 - Seismology; Seismic or acoustic prospecting or detecting specially adapted for well-logging
G01V 1/44 - Seismology; Seismic or acoustic prospecting or detecting specially adapted for well-logging using generators and receivers in the same well
G01K 11/16 - Measuring temperature based on physical or chemical changes not covered by group , , , or using changes in colour, translucency or reflectance of organic materials
85.
STEALTH APPLICATIONS OF ACOUSTIC HYPERABSORPTION BY ACOUSTICALLY DARK METAMATERIAL CELLS
Aspects of the present disclosure include apparatus, systems, and methods for enhancing passive stealth capabilities. Apparatus may include at least one acoustic attenuator comprising a metamaterial matrix having a plurality of cells and configured, upon at least a partial immersion in a fluid, to form an acoustic attenuation system including at least a portion of the matrix and the fluid, the acoustic attenuation system configured to acoustically attenuate acoustic signals incident on the attenuator from the fluid. At least one cell of the plurality of cells may comprise a plurality of sub-cells azimuthally arrayed about an axis of alignment, with at least one sub-cell of the plurality comprising a plurality of solid cell segments substantially oriented in alignment with a mapping geometry comprising an inversion of a canonical tangent circles mapping.
A method for deploying a fiber optic line from a surface to a desired location in a wellbore includes the steps of identifying a heater cable deployed in the wellbore, where the heater cable includes one or more conductors and a first capillary tube. The method continues with the step of loading a terminal end of the fiber optic line into the first capillary tube from the surface. Next, the method includes the step of pumping a working fluid into the first capillary tube from the surface to inject the fiber optic line through a portion of the first capillary tube. The method concludes with the step of stopping the injection of the fiber optic line when the terminal end of the fiber optic line reaches the desired location in the wellbore.
E21B 47/09 - Locating or determining the position of objects in boreholes or wells; Identifying the free or blocked portions of pipes
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
A shaft coupling for connecting an upper shaft with a lower shaft within a pumping system is designed to handle a large tensile load between the upper and lower shafts. In some embodiments, the upper shaft includes a shaft ring groove and the coupling has a body and a first receiving chamber within the body that receives an end of the upper shaft. The coupling also includes an upper internal groove extending into the body from the first receiving chamber and an upper split ring that is configured to be compressed into a position occupying both the upper internal groove and the shaft ring groove of the upper shaft. Set screws compress the upper split ring into the shaft ring groove of the upper shaft. In another embodiment, the coupling includes a plurality of locking screws that extend through the body into corresponding lock screw grooves in the upper and lower shafts.
F04B 47/06 - Pumps or pumping installations specially adapted for raising fluids from great depths, e.g. well pumps having motor-pump units situated at great depth
F04D 29/044 - Arrangements for joining or assembling shafts
F04D 29/054 - Arrangements for joining or assembling shafts
A multistage centrifugal pump has a rotatable shaft, a plurality of pump stages and a thrust module. Each of the plurality of pump stages has an impeller connected to the rotatable shaft and a stationary diffuser. The thrust module has a thrust runner and a unitary thrust pad. The unitary thrust pad has an axial wear face adjacent the thrust runner and a radial wear surface adjacent the rotatable shaft. The axial wear face and radial wear surface are integrated as a unitary component. The unitary thrust pad is secured to a thrust pad support with threaded fasteners that are torqued to a predetermined extent.
Methods, systems, devices, and products for constructing a downhole tool electronics module. Methods may include creating a circuit board by metallizing at least part of a first surface on a first side of a substrate to define at least one metallized area on the first surface, wherein the substrate comprises a ceramic material and includes: the first side, including at least (i) the first surface, and (ii) an elevated surface elevated from the first surface, and a second side opposite the first side; flattening at least partially the elevated surface to a predefined first flatness to create a mounting portion by removing material from the elevated surface; attaching an electronics component to the first surface; and mounting the circuit board on an electronics carrier by adhering at least part of the mounting portion to a mounting surface on the electronics carrier. Flattening at least partially the elevated surface to the predefined first flatness may be carried out by removing the material by areal grinding.
H05K 1/18 - Printed circuits structurally associated with non-printed electric components
H05K 3/32 - Assembling printed circuits with electric components, e.g. with resistor electrically connecting electric components or wires to printed circuits
A transformer configured for use in connection with a variable speed motor drive includes primary windings and secondary windings. The secondary windings are configured as wye-windings and a ground lead and a plurality of phase leads. The transformer includes a ferrite blocking circuit connected to the ground lead.
Downhole fiber optic interrogation systems are described. The systems include a fiber optic control system, a first sensing system, a second sensing system, an optical fiber disposed within a well, and an optical switch arranged between the optical fiber and the first and second sensing systems, wherein the fiber optic control system performs time division multiplex control of the optical switch wherein the first sensing system is operably connected to the optical fiber and the second sensing system is not connected to the optical fiber, and further controls the optical switch such that the second sensing system is operably connected to the optical fiber and the first sensing system is not connected to the optical fiber.
G01V 8/24 - Detecting, e.g. by using light barriers using multiple transmitters or receivers using optical fibres
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
G02B 6/04 - Light guides; Structural details of arrangements comprising light guides and other optical elements, e.g. couplings formed by bundles of fibres
Ionic liquid containing compositions may be used in the production, recovery and refining of oil and gas. In addition, they may be used to treat wastewater and/or to inhibit and/or prevent fouling of contaminants onto surfaces.
An inflow promotion arrangement including a housing; and a promotion configuration within the housing, the promotion configuration actuatable by fluid from a relatively higher productivity index zone of a wellbore.
A borehole system including a completion in a borehole; an interval of the borehole having a plurality of productivity zones therein, at least one of the zones being a lower productivity zone and at least one of the zones being a higher productivity zone; a pump connected to the at least one lower productivity zone of the interval and configured to bring production from the lower productivity zone to a production capacity of the higher productivity zone of the interval.
A production system and a frac sleeve assembly of a frac assembly of the production system. The frac sleeve assembly includes a funnel section that reduces in diameter in a direction of an outlet of the frac assembly, a throat section having a selected diameter, and a ball seat at an intersection of the funnel section and the throat section for receiving a ball. When seated in the ball seat, an entire portion of a ball extending into the funnel section is exposed to disintegrating fluid in the funnel section.
A seal system for downhole use in a surrounding tubular includes a seal support including a frusto-conical surface, and a seal member positioned about the seal support. The seal member includes a seal support member including first side having a recess, a second, opposing side, and a seal element coupled to the second, opposing side. The seal element is engageable with the surrounding tubular. An expansion limiter is arranged between the seal support and the seal member. The expansion limiter is positioned in the recess of the seal support member to limit axial movement of the seal member relative to the frusto-conical surface.
Downhole formation pressure testing systems are provide. The systems include a drawdown pump, a probe configured to engage with a borehole wall and extract fluid from a formation, and a control element operably connected to the probe and the drawdown pump to perform a formation pressure testing operation. The formation pressure testing operation includes extracting a fluid from the formation for at least three drawdown intervals, monitoring a fluid pressure for a response interval at an end of each drawdown interval, measuring a fluid pressure at an end of each response interval to obtain a data point for each response interval, wherein each response interval is of the same duration, and wherein at least three data points are obtained, and performing a best fit analysis on the at least three data points, wherein the best fit analysis calculates a formation pressure.
E21B 49/00 - Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
E21B 49/08 - Obtaining fluid samples or testing fluids, in boreholes or wells
E21B 47/08 - Measuring diameters or related dimensions at the borehole
A packer including a body having a first axial end and a second axial end; an element disposed about the body; a flow passage within the body extending from the first axial end to the second axial end; a first pathway including a first port dimensioned and configured to receive a first penetrator and a second opening having a dimension smaller than the first port, the first port being located at the first axial end of the body and the second opening being located at the second axial end of the body; and a second pathway including a second port dimensioned and configured to receive a second penetrator and a first opening having a dimension smaller than the second port, the second port being located at the second axial end of the body and the first opening being located at the first axial end of the body.
A spring biased device having a plurality of operational spring rates including a housing; a first spring disposed between a selective support and a functional component; a second spring disposed between the selective support and another support; and a releasable connection between the selective support and the housing. A valve including a housing; a seat disposed within the housing; poppet movable to a position on the seat and a position off the seat, the poppet having a valve stem; a selective support; another support attached to the housing, the selective support and the another support allowing through passage of the valve stem; a first spring disposed between the selective support and the poppet; a second spring disposed between the another support and the selective support; and a connection between the selective support and the housing, the connection being selectively defeatible.
A method for deploying a sand screen in a borehole penetrating the earth includes: disposing the sand screen in an unexpanded form in the borehole, the sand screen at least partially surrounding a base-pipe; and activating the sand screen in the unexpanded form by applying at least one of an activation fluid and heat to the sand screen causing the sand screen to expand into an expanded form. The method further includes: conveying a downhole tool through the base-pipe, the downhole tool being configured to sense a property derived from at least one of expansion and non-expansion of the sand screen as a function of distance into the borehole to provide sensed data as a function of distance into the borehole; and identifying one of an expanded state and an unexpanded state of the sand screen using the sensed data as a function of distance into the borehole.
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