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.
An ultrasonic transducer is provided. The ultrasonic transducer can be configured for flow metering applications and can include a head mass, a tail mass, and a spanning element joining the head mass with the tail mass. At least one cavity can be created in the head mass, tail mass, or spanning element using additive manufacturing. A method of manufacturing is also provided. The method of manufacturing can include forming a head mass utilizing a first process of additive manufacturing. The method of manufacturing can also include forming a tail mass utilizing a second process or additive manufacturing. The method of manufacturing can further include joining the head mass and the tail mass by a spanning element.
B06B 1/06 - Processes or apparatus for generating mechanical vibrations of infrasonic, sonic or ultrasonic frequency making use of electrical energy operating with piezoelectric effect or with electrostriction
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
An apparatus for manipulating an object in a borehole in an earthen formation includes a body configured to be conveyed along the borehole and a plurality of linear actuators disposed in the body and operatively connected to the object. The plurality of linear actuators applies a translational and rotational movement to the object. A related method includes applying a translational and rotational movement to the object using the plurality of linear actuators.
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
E21B 47/007 - Measuring stresses in a pipe string or casing
E21B 47/135 - 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 using light waves, e.g. infrared or ultraviolet waves
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 49/06 - 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 by mechanically taking samples of the soil using side-wall drilling tools or scrapers
E21B 49/10 - Obtaining fluid samples or testing fluids, in boreholes or wells using side-wall fluid samplers or testers
4.
DAMPERS FOR MITIGATION OF DOWNHOLE TOOL VIBRATIONS AND VIBRATION ISOLATION DEVICE FOR DOWNHOLE BOTTOM HOLE ASSEMBLY
A system for drilling a borehole into the earth's subsurface includes a drill bit configured to rotate and penetrate through the earth's subsurface, and a vibration isolation device configured to isolate vibration that is caused at the drill bit, the vibration having an amplitude. The amplitude of the vibration downhole of the vibration isolation device is at least 20% higher than the amplitude of the vibration uphole of the vibration isolation device.
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
The present discussion relates to the addressing sensor drift issues in virtual flow meter applications. By way of example, in certain implementations: 1) pressure, temperature, or other sensors are prioritized based on one or more evaluation criteria, 2) a determination is made as to whether there are sensor drifts for those sensors with high priority, and 3) sensor readings experiencing drift, such as above a specified or measureable threshold, are compensated. In this manner, virtual flow meter accuracy is maintained over time.
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 method and apparatus for predicting a formation parameter at a drill bit drilling a formation is disclosed. A vibration measurement is obtained at each of a plurality of depths in the borehole. A formation parameter is obtained proximate each of the plurality of depths in the borehole. A relationship is determined between the obtained vibration measurements and the measured formation parameters at the plurality of depths. A vibration measurement at a new drill bit location is obtained and the formation parameter at the new drill bit location is predicted from the vibration measurement and the determined relation. Formation type can be determined at the new drill bit location from the new vibration measurement and the determined relationship.
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
9.
A ROTARY STEERABLE DRILLING ASSEMBLY WITH A ROTATING STEERING DEVICE FOR DRILLING DEVIATED WELLBORES
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.
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.
A method of fracturing multiple productive zones of a subterranean formation penetrated by a wellbore is disclosed. The method comprises injecting a fracturing fluid into each of the multiple production zones at a pressure sufficient to enlarge or create fractures in the multiple productive zones, wherein the fracturing fluid comprises an upconverting nanoparticle that has a host material, a dopant, and a surface modification such that the upconverting nanoparticle is soluble or dispersible in water, a hydrocarbon oil, or a combination thereof; recovering a fluid from one or more of the multiple production zones; detecting the upconverting nanoparticle in the recovered fluid by exposing the recovered fluid to an excitation radiation having a monochromatic wavelength; and identifying the zone that produces the recovered fluid or monitoring an amount of water or oil in the produced fluid by measuring an optical property of the upconverting nanoparticle in the recovered fluid.
A method of processing a workpiece includes supporting the workpiece on a tailstock extending along an axis, thermally processing the workpiece with a processing device, and displacing a portion of the tailstock assembly in response to thermal expansion of the workpiece as a result of processing with the thermal processing device.
C23C 4/00 - Coating by spraying the coating material in the molten state, e.g. by flame, plasma or electric discharge
B23B 1/00 - Methods for turning or working essentially requiring the use of turning-machines; Use of auxiliary equipment in connection with such methods
B05B 12/12 - Arrangements for controlling delivery; Arrangements for controlling the spray area responsive to condition of liquid or other fluent material discharged, of ambient medium or of target responsive to conditions of ambient medium or target, e.g. humidity, temperature
B05B 13/02 - Means for supporting work; Arrangement or mounting of spray heads; Adaptation or arrangement of means for feeding work
B05B 7/16 - Spraying apparatus for discharge of liquids or other fluent materials from two or more sources, e.g. of liquid and air, of powder and gas incorporating means for heating the material to be sprayed
B05B 3/00 - Spraying or sprinkling apparatus with moving outlet elements or moving deflecting elements
B22F 3/115 - Manufacture of workpieces or articles from metallic powder characterised by the manner of compacting or sintering; Apparatus specially adapted therefor by spraying molten metal, i.e. spray sintering, spray casting
G01N 29/265 - Arrangements for orientation or scanning by moving the sensor relative to a stationary material
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 non-destructive testing (NDT) system can provide a tree model of an inspection on a display of an NDT device and on a web page configured in a web browser on a computing device coupled to the NDT device. Inspection data acquired using the NDT device can be provided in real-time as the inspection data is associated with a node configured in the tree model. The NDT system can generate an inspection tree model based on an inspection template including a template tree model. Defect properties, inspection instructions, and/or image transforms can be applied to nodes of the template tree model such that the generated inspection tree model includes the applied defect properties, inspection instructions, and/or image transforms, which can then be applied to the inspection data acquired at the inspection point location corresponding to each node.
Methods, systems, and apparatuses for remote well operation control. Methods include conducting, with a plurality of remote well operation control hosts operating on corresponding remote well logging data acquisition management systems, a well operation using a well operation system at a well, wherein the well operation system includes a carrier having disposed thereon at least one logging instrument. Methods may include establishing a first operational control relationship between the carrier and a first of the plurality of remote well operation control hosts sufficient for the first remote well operation control host to control the carrier; and establishing a second operational control relationship between a selected one of the at least one logging instrument and a second remote well operation control host different than the first, the operational control relationship sufficient for the second remote well operation control host to control the at least one logging instrument and receive logging data.
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
G01V 1/40 - Seismology; Seismic or acoustic prospecting or detecting specially adapted for well-logging
E21B 47/26 - Storing data down-hole, e.g. in a memory or on a record carrier
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
18.
Method to predict overpressure uncertainty from normal compaction trendline uncertainty
A method for predicting a pressure window for drilling a borehole in a formation includes: obtaining a pore pressure related data value of the formation using a data acquisition tool; predicting pore pressure uncertainty from the pore pressure related data value of the formation using a processor; estimating uncertainty of a pressure window for drilling fluid using the predicted pore pressure uncertainty using a processor; and applying the estimated uncertainty to the pressure window to provide a modified pressure window using a processor.
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
20.
Display panel or screen with graphical user interface having virtual buttons
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
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
23.
Additive manufacturing controlled failure structure and method of making same
A downhole component including a first portion; a second portion; a controlled failure structure between the first portion and second portion. A method for improving efficiency in downhole components.
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
B23P 6/04 - Repairing fractures or cracked metal parts or products, e.g. castings
E21B 31/00 - Fishing for or freeing objects in boreholes or wells
G05B 19/4099 - Surface or curve machining, making 3D objects, e.g. desktop manufacturing
B23K 101/00 - Articles made by soldering, welding or cutting
B22F 5/00 - Manufacture of workpieces or articles from metallic powder characterised by the special shape of the product
B33Y 30/00 - ADDITIVE MANUFACTURING, i.e. MANUFACTURING OF THREE-DIMENSIONAL [3D] OBJECTS BY ADDITIVE DEPOSITION, ADDITIVE AGGLOMERATION OR ADDITIVE LAYERING, e.g. BY 3D PRINTING, STEREOLITHOGRAPHY OR SELECTIVE LASER SINTERING - Details thereof or accessories therefor
A stator for a downhole motor configured for use in a downhole environment. includes an inner tubular member formed from a first metallic material having an outer surface and a helically lobed inner surface, and an outer tubular member comprising a second metallic material that is different from the first metallic material. The inner tubular member is connected to the outer tubular member by compressive force passing from the outer tubular member through the inner tubular member to a rigid mandrel removably disposed within the inner tubular member. The inner tubular member and the outer tubular member form the stator of the downhole motor.
B21C 37/20 - Making helical or similar guides in or on tubes without removing material, e.g. by drawing same over mandrels, by pushing same through dies
F04C 2/107 - Rotary-piston machines or pumps of intermeshing-engagement type, i.e. with engagement of co-operating members similar to that of toothed gearing of internal-axis type with the outer member having more teeth or tooth-equivalents, e.g. rollers, than the inner member with helical teeth
25.
Integrating contextual information into workflow for wellbore operations
According to an embodiment, a computer-implemented method includes defining, by a processing device, the workflow as a plurality of steps. The method further includes defining, by the processing device, a contextual information field associated with at least one of the plurality of steps. The method further includes receiving, by the processing device, contextual information associated with the contextual information field. The method further includes displaying, by the processing device, the at least one of the plurality of steps of the workflow and the contextual information associated with the contextual information field by integrating the contextual information into the at least one of the plurality of steps.
E21B 41/00 - Equipment or details not covered by groups
G05B 15/02 - Systems controlled by a computer electric
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
26.
Downhole power generation system and optimized power control method thereof
A downhole power generation system is disclosed, which includes a turbine generator system. The turbine generator system includes a turbine, a generator coupled with the turbine and having an AC-DC rectifier, and an optimized power control unit. The turbine is driven by flow of a downhole fluid to rotate. The generator converts rotational energy from the turbine to electrical energy and outputting a direct current voltage. The turbine generator system is coupled to a load via the optimized power control unit. The optimized power control unit controls to regulate an output voltage of the generator and provides a regulated output voltage to the load so that the turbine generator system has an optimized power output. An optimized power control method for a downhole power generation system is also disclosed.
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
An apparatus for sensing a value of a property includes: an optical sensor having a single mode optical fiber responsive to the property; an optical interrogator having a tunable laser to transmit polarized light to the optical sensor, a photo-detector to receive sensor light, and a controller configured to process the received light and output the value of the property; and a passive random depolarizer disposed between the tunable laser and the single mode optical fiber and having (i) a first polarization maintaining (PM) optical fiber of length L1 having a first fast optical axis and a first slow optical axis and (ii) a second PM optical fiber of length L2 having a second fast optical axis and a second slow optical axis rotationally spliced to the first PM optical fiber in which the second fast and slow optical axes are offset from the first fast and slow optical axes.
G01D 5/353 - Mechanical means for transferring the output of a sensing member; Means for converting the output of a sensing member to another variable where the form or nature of the sensing member does not constrain the means for converting; Transducers not specially adapted for a specific variable using optical means, i.e. using infrared, visible or ultraviolet light with attenuation or whole or partial obturation of beams of light the beams of light being detected by photocells influencing the transmission properties of an optical fibre
G01L 1/24 - Measuring force or stress, in general by measuring variations of optical properties of material when it is stressed, e.g. by photoelastic stress analysis
E21B 47/135 - 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 using light waves, e.g. infrared or ultraviolet waves
32.
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.
A probe driver may include a coupling that interfaces with a conduit section at a first position of the conduit section. A probe driver may also have one or more positioning elements to reposition the conduit section to interface with the coupling at a second position of conduit section in response to one or more commands based on a recorded inspection, where through completing the one or more commands is configured to initiate a second inspection identical to the recorded inspection.
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.
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.
An apparatus for transmitting and/or receiving energy in a borehole penetrating a subsurface formation includes a tubular assembly having a tubing mandrel and a sleeve at least partially surrounding a circumference of the tubing mandrel, wherein the tubing mandrel includes a cavity and the sleeve defines at least a portion of an opening over the cavity. The apparatus also includes a transducer assembly disposed in the cavity and configured for transmitting and/or receiving the energy, wherein the transducer assembly upon relative movement of the tubing mandrel with respect to the sleeve is displaced radially.
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 41/00 - Equipment or details not covered by groups
A wellbore cleanout system including a first tubular, and a pump member including a stator and a rotor. The stator has a first end, a second end, an outer surface, and an inner surface defining an internal passage. The rotor is arranged within the internal passage and includes a first end portion connected to the first tubular and a second end portion. The rotor is coupled for rotation with the first tubular. A drag system including at least one drag member is fixedly mounted to the outer surface of the stator. A second tubular is connected to the second end of the rotor. The second tubular is coupled for rotation with the first tubular.
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
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.
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
Methods and apparatuses for controlling a trajectory of a borehole being drilled into the earth are provided. The apparatus includes a drilling system including a drill tubular, a disintegrating device, and a steering system coupled to the drill tubular configured to steer the drilling system, the drilling system configured to drill the borehole by receiving control outputs from at least one control unit for controlling parameters of the drilling system, the at least one control unit configured to provide the control outputs to the steering system, the at least one control unit being configured to provide a depth-based control output.
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 47/024 - Determining slope or direction of devices in the borehole
E21B 47/12 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
G05B 15/02 - Systems controlled by a computer electric
E21B 21/08 - Controlling or monitoring pressure or flow of drilling fluid, e.g. automatic filling of boreholes, automatic control of bottom 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
G01B 21/18 - Measuring arrangements or details thereof, where the measuring technique is not covered by the other groups of this subclass, unspecified or not relevant for measuring depth
E21B 19/08 - Apparatus for feeding the rods or cables; Apparatus for increasing or decreasing the pressure on the drilling tool; Apparatus for counterbalancing the weight of the rods
A tubular for reservoir fines control includes a body having an outer surface and an inner surface defining a flow path. A plurality of openings is formed in the body connecting the outer surface and the flow path. A pre-formed member including a material mesh is overlaid onto the outer surface. The material mesh is formed from a material swellable upon exposure to a selected fluid. The material mesh has a selected porosity allowing methane to pass into the flow path while preventing passage of fines.
A tubing pressure insensitive failsafe wireline retrievable safety valve including a tool housing, a flow tube disposed within the tool housing, an actuation piston disposed in the tool housing and operably connected to the flow tube, the actuation piston having an actuation pressure side and a relatively lower pressure chamber side, a fluid pathway between a potential leak site for the valve and the relatively lower pressure chamber side of the piston. A borehole system having a tubing pressure insensitive failsafe wireline retrievable safety valve. A tubing pressure insensitive failsafe wireline retrievable safety valve.
E21B 34/14 - Valve arrangements for boreholes or wells in wells operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools
E21B 34/10 - Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole
E21B 34/06 - Valve arrangements for boreholes or wells in wells
46.
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.
An embodiment of a method of predicting a location of one or more features of an earth formation during a downhole operation includes acquiring reference data and identifying one or more reference data sections, each reference data section corresponding to a feature of interest and having an associated depth or depth interval, deploying a drilling assembly and drilling a target borehole in the earth formation, and performing measurements during the operation by a downhole measurement device to generate measurement data. The method also includes performing one or more correlations of the one or more measurement data sections with one or more reference data sections; and predicting at least one of a depth of a subsequent feature of interest located beyond a current carrier depth and a point in time of a future event associated with the subsequent feature of interest based on the correlation.
A switch driving circuit includes an output coil having a first end and a second end and configured to receive positive or negative pulses from an input coil and a drive portion that includes a holding capacitor coupled across the output coil. The circuit also includes a discharge circuit that includes a discharge switch connected across the output coil, the discharge circuit having a discharge resistor and a discharge capacitor connected in parallel with each other and across control terminals of the discharge switch and a shunt circuit connected across the output coil that shorts the first end to the second end after a positive pulse is received.
H03K 17/687 - Electronic switching or gating, i.e. not by contact-making and -breaking characterised by the use of specified components by the use, as active elements, of semiconductor devices the devices being field-effect transistors
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
H02M 3/156 - Conversion of dc power input into dc power output without intermediate conversion into ac by static converters using discharge tubes with control electrode or semiconductor devices with control electrode using devices of a triode or transistor type requiring continuous application of a control signal using semiconductor devices only with automatic control of output voltage or current, e.g. switching regulators
50.
Connector for connecting to a downhole longitudinal member
A connector (10) is provided. The connector (10) is for connecting to a downhole longitudinal member (12). The connector (10) comprises a gripping sleeve (14) defining an internal bore (16) for receiving the longitudinal member (12) therewithin, wherein the gripping sleeve (14) is configured to grip or to increase grip on the longitudinal member (12) by lengthening the gripping sleeve (14). Also provided area system in which the connector (10) is used, and a method of connecting a connector (10) to a downhole longitudinal member (12).
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
54.
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
55.
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.
An operating system for a barrier valve or safety valve is responsive to increments in annulus or tubing pressure. An indexing device controls valves that selectively direct pressure applied to one side of an operating piston or the other for attaining the open and closed positions of the barrier valve. One such indexing device can be a j-slot. Other devices that operate a pair of hydraulic valves in tandem for pressure direction to one side of an actuation piston or another are contemplated. The system needs no electric power and there are no control lines needed to run below the production packer in the case of using annulus pressure to actuate the piston or at all if access to tubing pressure is provided from the vicinity of the barrier valve components.
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 23/00 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells
E21B 34/08 - Valve arrangements for boreholes or wells in wells responsive to flow or pressure of the fluid obtained
E21B 34/10 - Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole
57.
Sleeve control valve for high temperature drilling applications
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
E21B 47/18 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling using acoustic waves through the well fluid
A non-destructive testing (NDT) system can provide a tree model of an inspection on a display of an NDT device and on a web page configured in a web browser on a computing device coupled to the NDT device. Inspection data acquired using the NDT device can be provided in real-time as the inspection data is associated with a node configured in the tree model. The NDT system can generate an inspection tree model based on an inspection template including a template tree model. Defect properties, inspection instructions, and/or image transforms can be applied to nodes of the template tree model such that the generated inspection tree model includes the applied defect properties, inspection instructions, and/or image transforms, which can then be applied to the inspection data acquired at the inspection point location corresponding to each node.
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
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
61.
Time synchronization of bottom hole assembly components via powerline communication
An example method for performing a time synchronization among a plurality of electronic components within a bottom hole assembly (BHA) includes modifying a preamble of a digital signal by adding symbols to the preamble of the digital signal to mark a moment in time. The method further includes generating a physical waveform that includes the modified preamble and transmitting the physical waveform over a powerline, using a powerline interface, to other of the plurality of electronic components. The method further includes transmitting an absolute time value to the other of the other of the plurality of electronic components. The method further includes performing, by at least one of the other of the plurality of electronic components, the time synchronization by detecting the physical waveform, determining a local time drift compared to the moment in time and the absolute time value, and adjusting a local clock to the absolute time value.
H04B 3/54 - Systems for transmission via power distribution lines
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
62.
Methods and systems for online monitoring using a variable data
A method for online monitoring of a physical environment using a variable data sampling rate is implemented by a computing device. The method includes sampling, at the computing device, at least one data set using at least one sampling rate. The method also includes processing the at least one data set with condition assessment rules. The method further includes determining whether the at least one data set indicates a change in state of the physical environment. The method additionally includes updating the at least one sampling rate.
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.
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.
G01L 19/00 - MEASURING FORCE, STRESS, TORQUE, WORK, MECHANICAL POWER, MECHANICAL EFFICIENCY, OR FLUID PRESSURE - Details of, or accessories for, apparatus for measuring steady or quasi-steady pressure of a fluent medium insofar as such details or accessories are not special to particular types of pressure gauges
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
70.
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.
An ultrasonic sensor assembly includes a flexible supporting material that has flexibility configured for allowing bending of the supporting material to conform to a cylindrical shape of a pipe. The assembly includes a plurality of operable sensor elements arranged in a matrix formation upon the flexible supporting material. The matrix formation includes a plurality of rows of the sensor elements and a plurality of columns of the sensor elements. The flexible supporting material is configured for placement of the columns of the matrix formation to extend along the elongation of the pipe and the flexible supporting material is configured for placement of the rows of the matrix formation to extend transverse to the elongation of the pipe. The flexible support material is configured to flex for positioning the sensor elements within each row in a respective arc that follows a curve of the cylinder shape of the pipe.
G01N 29/22 - 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 - Details
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
73.
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 and methods are provided for increasing the efficiency of liquefied natural gas production and heavy hydrocarbon distillation. Air within an LNG production facility can be utilized as a heat source to provide heat to HHC liquid for distillation in a HHC distillation system. The mechanism of heat transfer from the air can be natural convection. Heat provided by natural gas, or compressed natural gas, can be also used for HHC distillation. Various other liquids can further be used to transfer heat to HHC liquid for distillation.
F25J 1/02 - Processes or apparatus for liquefying or solidifying gases or gaseous mixtures requiring the use of refrigeration, e.g. of helium or hydrogen
F25J 1/00 - Processes or apparatus for liquefying or solidifying gases or gaseous mixtures
F25J 3/02 - Processes or apparatus for separating the constituents of gaseous mixtures involving the use of liquefaction or solidification by rectification, i.e. by continuous interchange of heat and material between a vapour stream and a liquid stream
76.
JUST-IN-TIME DATA PROVISION BASED ON PREDICTED CACHE POLICIES
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
79.
Multi-frequency acoustic interrogation for azimuthal orientation of downhole tools
An apparatus for detecting a location of an optical fiber having an acoustic sensor disposed subsurface to the earth includes an acoustic emitter configured to emit a first signal having a first frequency and a second signal having a second frequency that is higher than the first frequency, the first and second emitted acoustic signals being azimuthally rotated around the borehole and an optical interrogator configured to interrogate the optical fiber to receive an acoustic measurement that provides a corresponding first received signal and a corresponding second received signal. The apparatus also includes a processor configured to (i) frequency-multiply the first received signal to provide a third signal having a third frequency within a selected range of the second frequency, (ii) estimate a phase difference between the second received signal and the third signal, and (iii) correlate the phase difference to the location of the optical fiber.
E21B 47/095 - Locating or determining the position of objects in boreholes or wells; Identifying the free or blocked portions of pipes by detecting acoustic anomalies, e.g. using mud-pressure pulses
G01V 1/22 - Transmitting seismic signals to recording or processing apparatus
A method of treating and producing formation fluids includes introducing a first drop ball into a string of tubulars, pumping the first drop ball to a first ball seat, applying pressure to the first drop ball to shift a first sleeve exposing an outlet port, introducing a second drop ball into the string of tubulars, pumping the second drop ball to a second ball seat, applying pressure to the second drop ball to shift a second sleeve closing the outlet port and opening an inlet port, and introducing a fluid through at least one of a first injection port directly onto the first drop ball and a second injection port directly onto the second drop ball. The first injection port is arranged upwardly of the first sleeve and the second injection port is arranged upwardly of the second sleeve.
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 21/10 - Valves arrangements in drilling-fluid circulation systems
E21B 21/00 - Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
E21B 33/124 - Units with longitudinally-spaced plugs for isolating the intermediate space
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.
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 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 44/04 - Automatic control of the tool feed in response to the torque of the drive
E21B 45/00 - Measuring the drilling time or rate of penetration
G01V 11/00 - Prospecting or detecting by methods combining techniques covered by two or more of main groups
E21B 49/08 - Obtaining fluid samples or testing fluids, in boreholes or wells
84.
Electrical downhole communication connection for downhole drilling
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 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 49/08 - Obtaining fluid samples or testing fluids, in boreholes or wells
F16L 15/00 - Screw-threaded joints; Forms of screw-threads for such joints
F16L 25/01 - Construction or details of pipe joints not provided for in, or of interest apart from, groups specially adapted for realising electrical conduction between the two pipe ends of the joint or between parts thereof
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 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 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
90.
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
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.
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 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.
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
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
95.
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
96.
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.
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.
