Disclosed is an apparatus when installed with an Electrical Submersible Pump for fluid production protects the motor from the effect of solids on the mechanical shaft seal. The invention provides enhanced features to the apparatus that dynamically filters the solids and prevents them from contacting or accumulating at the vicinity of the mechanical shaft seal.
In some embodiments, a method for controlling fluid flow through a downhole pump system in a borehole includes moving, via a downhole pump residing below a tubular in the borehole, a first fluid through the tubular, wherein the first fluid includes a compressible fluid. The method may further include increasing an intake pressure of the downhole pump while the first fluid is moving via a control valve system comprising a throttling valve.
A sag detection apparatus comprises an oven containing a sample cell supported by a cell support structure, a thermal conductivity sensor including a sensor housing, and a roller with a first end supported by a first bearing and fixedly coupled to a first end of the cell support structure and a second end supported by a second bearing and fixedly coupled to a second end of the cell support structure. Temperature sensor wires electrically connect a temperature sensor and first fixed contact via stationary contacts configured to remain fixed during rotation of the roller and rotating contacts configured to rotate with rotation of the roller. Heat source wires electrically connect a heat source and a second fixed contact via stationary contacts configured to remain fixed during rotation of the roller and rotating contacts configured to rotate with rotation of the roller.
E21B 47/125 - 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 earth as an electrical conductor
Aspects of the subject technology relate to systems, methods, and computer-readable media for corrosion analysis using magnetic flux leakage measurements. The present technology can magnetic flux leakage data obtained by a magnetic flux leakage tool placed in a pipe within a wellbore and convert the magnetic flux leakage data into image data. Further, the present technology can provide the image data to a machine learning model. The machine learning model is configured to identify one or more physical parameters associated with corrosion present on the pipe.
E21B 47/092 - Locating or determining the position of objects in boreholes or wells; Identifying the free or blocked portions of pipes by detecting magnetic anomalies
G01N 27/82 - Investigating or analysing materials by the use of electric, electrochemical, or magnetic means by investigating magnetic variables for investigating the presence of flaws
A method for forming a model of a bottom hole assembly (BHA) in a borehole, wherein the BHA is connected to a drill string. The method may further comprise segmenting the model into one or more segments and solving a multipoint boundary value problem (BVP) based at least in part on the one or more segments.
E21B 44/00 - Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systems; Systems specially adapted for monitoring a plurality of drilling variables or conditions
A method and non-transitory storage computer-readable medium for performing a neural operator on one or more wellbore measurements. The method may comprise o obtaining one or more measurements, performing a measurement normalization on the one or more measurements to form one or more normalized measurements, forming a material function with the one or more normalized measurements, and forming a neural operator generated physical response with a neural operator and the material function. The method may further comprise forming a beamforming map with the one or more measurements, and forming a neural operator leak source location map with a neural operator and the one or more measurements.
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 3/12 - Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination or deviation operating with electromagnetic waves
G01V 1/44 - Seismology; Seismic or acoustic prospecting or detecting specially adapted for well-logging using generators and receivers in the same well
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
7.
CONTACT CHAMBER FLUSHING APPARTUS FOR CONCENTRIC ELECTRICAL WET CONNECT
A downhole tool for coupling an electrical connection in the wellbore comprising a locator sub and a receptacle sub. The locator sub can be conveyed into the wellbore with a workstring. The receptacle sub can be coupled to a lower completion with at least one downhole tool. Workstring manipulation can insert the locator sub into the receptacle sub to provide an electrical connection between a resilient connector on the locator sub and ring connector within the receptacle sub. A fluid source fluidically connected to the electrical connection can flush out trapped wellbore fluids via a fluid pathway. The electrical connection can electrically couple to a control system at surface to the at least one downhole tool.
Systems and methods of the present disclosure relate to downhole tools including expandable liner hangers that used a foam member to increase fluid volume in voids defined by the hanger and the casing. A system comprises a downhole tool comprising a tubular body, ribs extending along a circumference of the tubular body, and at least one foam member disposed on the tubular body and between the ribs. The system also includes a conduit. The downhole tool is disposed in the conduit. A void is defined by the tubular body, the ribs, and the conduit, and the foam member is disposed in the void.
A metal can include a metallic substrate and an alloy coating. The alloy coating may have a higher entropy than the entropy of the metallic substrate. The alloy coating may coat an external surface of the metallic substrate. The metal coated by the higher entropy alloy on an external surface of the metallic substrate may serve to increase resistance of the metal to hydrogen-induced cracking in a downhole environment.
C23C 24/10 - Coating starting from inorganic powder by application of heat or pressure and heat with intermediate formation of a liquid phase in the layer
C23C 24/08 - Coating starting from inorganic powder by application of heat or pressure and heat
C23C 26/02 - Coating not provided for in groups applying molten material to the substrate
C23C 30/00 - Coating with metallic material characterised only by the composition of the metallic material, i.e. not characterised by the coating process
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
10.
INTEGRATION OF STORED KINETIC ENERGY IN DOWNHOLE ELECTRICAL INTERVAL CONTROL VALVES
Systems and methods of the present disclosure relate to actuator assemblies for downhole tools. An actuator assembly comprises a motor, a spring and a hammer. The spring is adjacent to the hammer, and the hammer operable to compress the spring. The spring is operable to expand. The assembly also includes an anvil adjacent to the hammer. The anvil is operable to move a portion of the downhole tool.
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 liner hanger system for use in a subterranean well is disclosed. The liner hanger system comprises a well casing and a liner hanger. The liner hanger comprises a spike extending in an annular ring around an outer perimeter of the liner hanger. The spike comprises an annular groove defined therein. The liner hanger further comprises an annular seal positioned at least partially within the annular groove. The liner hanger is expandable to transition between an initial state where the spike is not in contact with the well casing and an expanded state where the spike is in contact with the well casing. The spike and the annular seal are configured to seal an uphole well portion from a downhole well portion when the liner hanger is in the expanded state.
Determining one or more of a fluid composition, a cement state, or a cement quality of a material located downhole a borehole by using a capacitive sensor or an inductive sensor. The sensors can be located on a pipe positioned downhole or within a swell packer. More than one sensor can be used, for example, as a set of sensor systems. The sensors can be of different sizes, utilize different frequencies, or be spaced unevenly to analyze different shaped areas and depths from the sensors. More than one set of sensors can be employed, such as axially or circumferentially spaced along the pipe or swell packer. The relative dielectric permittivity of the various downhole material can be used to determine when pumped cement has displaced the borehole fluid and when the cement has cured. The process can determine if a micro annulus or crack exists in the cement.
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
E21B 47/005 - Monitoring or checking of cementation quality or level
E21B 33/124 - Units with longitudinally-spaced plugs for isolating the intermediate space
G01V 3/38 - Processing data, e.g. for analysis, for interpretation or for correction
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
Provided is a retrievable safety valve insert, a safety valve, a well system, and a method. The retrievable safety valve insert, in one aspect, includes an outer housing including an outer housing central bore extending axially therethrough, the outer housing central bore operable to convey subsurface production fluids there through. The insert, according to this aspect, may further include a lock mandrel having a lock mandrel profile extending radially outward from the outer housing, the lock mandrel profile movable between a radially retracted state and a radially expanded state configured to engage with an end sub profile of an end sub. The insert, according to this aspect, may further include a safety valve insert closure mechanism coupled to the outer housing proximate a downhole end of the outer housing central bore, the safety valve insert closure mechanism movable between an outer housing closed state and an outer housing open state.
Systems and methods of the present disclosure relate to control of a downhole tool via at least one radio isotope. The radio isotope(s) is pumped from the surface to contact an isotopic analyzer of the tool. The isotopic analyzer reads the isotope and directs the tool to perform a specific action(s) in the wellbore based on the type of isotope read by the analyzer.
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 3/12 - Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination or deviation operating with electromagnetic waves
E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
G01V 3/38 - Processing data, e.g. for analysis, for interpretation or for correction
E21B 41/00 - Equipment or details not covered by groups
E21B 23/06 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for setting packers
A washpipe free feature may include a housing defining a chamber having a bypass portion and a securing portion. The housing has first and second bores to put the bypass portion in fluid communication with an annulus of a wellbore and a central bore of a downhole tubular, respectively. Further, the washpipe free feature includes a magnet secured in the bypass portion, a ferromagnetic ball disposed within the bypass portion, and a piston disposed within the chamber. A distal end of the piston blocks the ball from contacting the magnet in a run-in position such that the ball may plug the first bore in response to fluid flow from the tubular toward the annulus. Additionally, the piston is slideable to an open position such that the magnet may hold the ball out of a flow path between the first bore and the second bore in the bypass portion.
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 23/04 - 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 34/10 - Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole
E21B 37/08 - Methods or apparatus for cleaning boreholes or wells cleaning in situ of down-hole filters, screens, or gravel packs
16.
DOWNHOLE POWER MANAGEMENT SYSTEM WITH RECHARGEABLE BATTERIES AND GENERATORS
The disclosure provides a downhole power system that includes a combination of different power sources, which includes downhole power generators and rechargeable batteries that can be recharged downhole, a downhole bus and a bus power controller that manages the distribution of power from the different power sources to downhole tools connected to the downhole bus, such as tools of a BHA. The different power sources can be strategically positioned along the downhole bus / BHA. An example of a downhole distributed power system includes: (1) a downhole bus, (2) different power sources connected to and strategically positioned on the downhole bus, and (3) one or more controllers to perform operations that includes managing distribution of power, from the different power sources, to downhole tools connected to the downhole bus, wherein the different power sources include one or more power generators and one or more rechargeable batteries that are chargeable downhole.
H02J 3/00 - Circuit arrangements for ac mains or ac distribution networks
H02J 7/14 - Circuit arrangements for charging or depolarising batteries or for supplying loads from batteries for charging batteries from dynamo-electric generators driven at varying speed, e.g. on vehicle
E21B 41/00 - Equipment or details not covered by groups
The present disclosure, in at least one aspect, provides a production sub, a well system, and a method. The production sub, in one aspect, includes a tubular having a length (l), an inside diameter (ID), an outside diameter (OD), and a sidewall thickness (t), a plurality of production ports extending through the sidewall thickness (t) and coupling the inside diameter (ID) and the outside diameter (OD), and a fluid flow assembly positioned in each of the plurality of production ports. Each fluid flow assembly, in one aspect, includes a radially interior burst disc, as well as a degradable fluid flow orifice positioned radially outside of the radially interior burst disk, the degradable fluid flow orifice configured to degrade over time after the radially interior burst disc has burst to increase a flow volume through the production port.
E21B 34/06 - Valve arrangements for boreholes or wells in wells
E21B 34/10 - Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole
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 33/14 - Methods or devices for cementing, for plugging holes, crevices, or the like for cementing casings into boreholes
18.
PERFORATING SYSTEM ORIENTATION APPARATUS AND METHOD OF ORIENTING PERFORATING GUNS
A system for landing a perforating gun in a particular orientation may include a landing housing securable within a wellbore and having at least one key slot extending into an inner surface of the landing housing. The system further includes a latch assembly configured to couple to the landing housing in a particular orientation. The latch assembly includes a tubular support structure and at least one key feature configured to extend and retract radially through a sidewall of the tubular support structure. The latch assembly further includes a biasing mechanism configured to bias the at least one key feature into the at least one key slot to couple the latch assembly to the landing housing. Additionally, the system includes a perforating gun system secured to the latch assembly such that the orientation of the latch assembly aims the perforating gun system in the wellbore.
Systems and methods of the present disclosure relate to signal attenuation for acoustic logging tools. An acoustic logging tool includes acoustic transducers. Each acoustic transducer includes a body, a piezoelectric element disposed on a first end of the body to receive or transmit at least one signal, and a wedge-cut disposed on an opposite end of the body. The wedge-cut defines a sloped portion operable to attenuate signals.
G01V 1/44 - Seismology; Seismic or acoustic prospecting or detecting specially adapted for well-logging using generators and receivers in the same well
E21B 47/14 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling using acoustic waves
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
A treatment operation can be performed in a wellbore. A zonal isolation device, such as a frac plug, can be set within a tubing string in the wellbore to isolate one zone from another zone. The plug can include a slip system and a sealing element located circumferentially around an inner mandrel of the plug. The sealing element can include an outer shell that surrounds an inner core. The outer shell can be made from a material having a high Young's modulus, while the inner core can have a very low Young's modulus. The outer shell can prevent premature deformation and expansion of the sealing element during run in. The outer shell and inner core can wholly or partially disintegrate in a desired a period of time after setting of the plug in the tubing string.
E21B 33/129 - Packers; Plugs with mechanical slips for hooking into the casing
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
21.
A LATCH COLLET INCLUDING UNIQUE COLLET PROP BUTTONS
Provided is a latch collet, a well system, and a method for forming a well system. The latch collet, in one aspect, includes a collet body, the collet body having a plurality of collet fingers. The latch collet, according to this aspect, further includes a collet prop button located on a radial interior of each of the plurality of collet fingers, the collet prop button configured to engage with a profile of a mandrel for running the latch collet downhole, and configured to be propped radially outward by the mandrel to cause torque buttons located on a radial exterior of each of the plurality of fingers to remain engaged with associated alignment profiles in a latch coupling when positioned at an acceptable position downhole.
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 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 41/00 - Equipment or details not covered by groups
22.
A LATCH COUPLING INCLUDING UNIQUE AXIAL ALIGNMENT SLOTS
Provided is a latch coupling, a well system, and a method for forming a well system. The latch coupling, in one aspect, includes a housing having an outside diameter (OD) and an inside diameter (ID). The latch coupling, according to this aspect, further includes a plurality of axial alignment slots located along the inside diameter (ID) of the housing, wherein a width (WAS) of each of the plurality of axial alignment slots is within 10% of each other.
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 33/129 - Packers; Plugs with mechanical slips for hooking into the casing
E21B 41/00 - Equipment or details not covered by groups
cbcb) thereof and a plurality of collet fingers, as well as a mandrel positioned within the collet body, the mandrel having a mandrel slot therein. The downhole tool, according to this aspect, further includes a bore sensor positioned within the collet body opening and the mandrel slot, the bore sensor configured remain in a radially extended state when the latch collet is in too large size casing and configured to be pushed to a radially compressed state when the latch collet is in the correct size casing and thereby not prevent the collet body and the mandrel from sliding relative to one another.
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
mm) thereof, and a running tool collet located within the mandrel, the running tool collet having a running tool collet slot on a radial exterior surface thereof. The downhole tool, according to this aspect, further includes a locking dog positioned within the mandrel opening.
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 34/10 - Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole
E21B 41/00 - Equipment or details not covered by groups
Provided is a downhole tool, a well system, and a method for forming a well system. The downhole tool, in one aspect, includes a whipstock assembly, and a completion assembly. The downhole tool, according to this aspect, further includes a fluid loss device positioned between the whipstock assembly and the completion assembly.
E21B 29/06 - Cutting windows, e.g. directional window cutters for whipstock operations
E21B 41/00 - Equipment or details not covered by groups
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
26.
A TWO-PART DRILLING AND RUNNING TOOL INCLUDING A ONE WAY MECHANISM
Provided is a two-part drilling and running tool, a well system, and a method for forming a well system. The two-part drilling and running tool, in one aspect, includes a conveyance, a smaller assembly coupled to an end of the conveyance, and a larger bit assembly slidably coupled to the conveyance, the smaller assembly and larger bit assembly configured to slidingly engage one another downhole to form a combined bit assembly. The two-part drilling and running tool, according to this aspect, further includes a one way mechanism coupled between the smaller assembly and the larger bit assembly, the one way mechanism configured to allow the smaller assembly and larger bit assembly to axially slide in one direction relative to one another and prevent the smaller assembly and larger bit assembly from axially sliding in an opposite direction relative to one another.
E21B 10/64 - Drill bits characterised by the whole or part thereof being insertable into or removable from the borehole without withdrawing the drilling pipe
E21B 10/62 - Drill bits characterised by parts, e.g. cutting elements, which are detachable or adjustable
27.
A DOWNHOLE TOOL INCLUDING A PACKER ASSEMBLY, A COMPLETION ASSEMBLY, AND A FIXEDLY COUPLED WHIPSTOCK ASSEMBLY
Provided is a downhole tool, and a method for forming a well system. The downhole tool, in one aspect, includes a whipstock assembly, a packer assembly fixedly coupled to the whipstock assembly, and an anchor assembly coupled to the packer assembly. The downhole tool, according to this aspect, further includes a completion assembly coupled to the anchor assembly, the whipstock assembly, packer assembly, anchor assembly and the completion assembly configured to be run-in-hole in a single trip.
E21B 23/06 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for setting packers
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 41/00 - Equipment or details not covered by groups
28.
A DOWNHOLE TOOL INCLUDING A PACKER ASSEMBLY, A COMPLETION ASSEMBLY, AND A REMOVABLY COUPLED WHIPSTOCK ASSEMBLY
Provided is a downhole tool, and a method for forming a well system. The downhole tool, in one aspect, includes a whipstock assembly, a packer assembly removably coupled to the to the whipstock assembly, and an anchor assembly coupled to the packer assembly. The downhole tool, according to this aspect, further includes a completion assembly coupled to the anchor assembly, the whipstock assembly, packer assembly, anchor assembly and the completion assembly configured to be run-in-hole in a single trip.
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
29.
PRODUCTION SUB INCLUDING A FLUID FLOW ASSEMBLY HAVING A PAIR OF RADIAL BURST DISCS
The present disclosure, in at least one aspect, provides a production sub, a well system, and a method. The production sub, in one aspect, includes a tubular having a length (l), an inside ID, an OD, and a sidewall thickness (t), a plurality of production ports extending through the sidewall thickness (t) and coupling the inside diameter (ID) and the outside diameter (OD), and a fluid flow assembly positioned in each of the plurality of production ports. Each fluid flow assembly, in one aspect, includes a radially interior burst disc, a radially exterior burst disc, a sealing member positioned in a chamber created between the radially interior burst disc and the radially exterior burst disc, and a sealing member seat located in the chamber proximate the radially exterior burst disc, the sealing member configured to engage with the sealing member seat as fluid is pushing the sealing member radially outward.
E21B 34/06 - Valve arrangements for boreholes or wells in wells
E21B 34/10 - Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole
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 33/14 - Methods or devices for cementing, for plugging holes, crevices, or the like for cementing casings into boreholes
Systems and methods to determine angular offset between reference points on a drill string are achieved automatically using an electronic device, such as a handheld device. A first orientation value corresponding to the first highside reference point is obtained using the electronic device. A second a second orientation value corresponding the second highside reference point is obtained. The electronic device then calculates the angular offset between the first and second orientation values.
A tubing retrievable safety valve assembly and related methods are disclosed herein. The assembly includes a primary flapper, a secondary flapper, a flow tube, and a protective sleeve. The flow tube is shiftable between a downhole position that holds the primary flapper in an open position and an uphole position that allows the primary flapper to move to a closed position. The protective sleeve, when positioned in an uphole position, holds the secondary flapper valve in an open position. The protective sleeve is shiftable to a downhole position to allow the secondary flapper to move to a closed position, for example, upon failure of the primary flapper.
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 34/12 - Valve arrangements for boreholes or wells in wells operated by movement of casings or tubings
A computer-implemented method for determining flow information of a well producing fluid from a subsurface formation comprising. The method comprises obtaining at least one first production measurement from the well. The method comprises obtaining, with a sensor, a first measurement generated by the fluid flowing through a device. The method comprises inputting the first measurement and the at least one first production measurement into a virtual flow meter. The method comprises determining, via the virtual flow meter, a multi-phase flow rate of the fluid based on the first measurement and the at least one first production measurement.
Aspects of the subject technology relate to systems, methods, and computer-readable media for identifying a wellbore pressure based on a predicted pump intake loss. A pump intake pressure after an intake for a submersible pump deployed downhole in a wellbore is identified. An intake loss prediction model for identifying a virtual intake loss associated with the intake for the submersible pump as a function of one or more intake loss parameters is accessed. The virtual intake loss is identified by applying the intake loss prediction model based on intake loss prediction input of the one or more intake loss parameters. A pump intake pressure before the intake for the submersible pump is determined based on the virtual intake loss and the identified pump intake pressure after the intake.
Provided is a latch collet, a well system, and a method for forming a well system. The latch collet, in one aspect, includes a collet body, the collet body having a plurality of collet fingers. The latch collet, according to this aspect, further includes a torque button located on a radial exterior of each of the plurality of collet fingers, wherein a width (WTB) of each of the torque buttons is within 10% of each other.
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
Provided is a downhole tool, a well system, and a method for forming a well system. The downhole tool, in one aspect, includes a latch collet including a collet body, the collet body having a plurality of collet fingers, and a mandrel positioned within the collet body. The downhole tool, according to this aspect, further includes a packer assembly positioned axially between the collet body and the mandrel, the packer assembly configured to move from a radially retracted state when the mandrel and collet body are being run-in-hole to a radially extended state when the collet body has engaged with a latching profile and weight is placed down upon the packer assembly.
A method includes operating a neutron generator in a loading mode by ionizing ionizable gas within an ion source of the neutron generator to create a plurality of ions, and accelerating the plurality of ions by providing a first voltage to a target rod that supports the target to create a first ion beam that bombards a target of the neutron generator. The method also includes operating the neutron generator in a generating mode to generate a plurality of neutrons by accelerating the plurality of ions by providing a second voltage to the target rod to create a second ion beam that bombards the target. The second voltage is greater than the first voltage.
G01V 5/08 - Prospecting or detecting by the use of nuclear radiation, e.g. of natural or induced radioactivity specially adapted for well-logging using primary nuclear radiation sources or X-rays
G01V 9/00 - Prospecting or detecting by methods not provided for in groups
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 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 perforating gun system may include a central support structure and a plurality of charges secured to the central support structure. Each charge of the plurality of charges is configured to perforate a casing and/or sidewall of a wellbore upon detonation. Further, the plurality of charges comprises a first group of charges and a second group of charges, and each charge of the second group of charges is radially offset from each charge of the first group of charges with respect to the central support structure.
A downhole tool has a tubular body defining an outer wall. A port is defined in the outer wall and a plug is received in the port. The plug is detachably connected to the outer wall and expellable into an annulus between the tubular body and a wellbore in which the downhole tool is placed upon the application of pressure in an interior of the tubular body
E21B 33/16 - Methods or devices for cementing, for plugging holes, crevices, or the like for cementing casings into boreholes using plugs for isolating cement charge; Plugs therefor
E21B 33/14 - Methods or devices for cementing, for plugging holes, crevices, or the like for cementing casings into boreholes
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
A method for configuring a learning machine to predict a flow rate of at least one phase of a fluid. The method comprises determining a feature set for the learning machine, the feature set including information derived from a signal generated by a flow of the fluid interacting with a fluidic oscillator in a wellbore. The method comprises configuring the learning machine with the feature set including information derived from the signal.
In some embodiments, a downhole logging tool configured for placement in a wellbore comprises a first magnet configured to activate a first volume of ferromagnetic fluid disposed between the downhole logging tool and the wellbore to achieve a first seal between a primary analysis region of the downhole logging tool and a wellbore fluid.
G01V 1/40 - Seismology; Seismic or acoustic prospecting or detecting specially adapted for well-logging
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 5/04 - Prospecting or detecting by the use of nuclear radiation, e.g. of natural or induced radioactivity specially adapted for well-logging
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 37/08 - Methods or apparatus for cleaning boreholes or wells cleaning in situ of down-hole filters, screens, or gravel packs
41.
BOREHOLE CORRECTION FOR RESISTIVITY LWD TOOLS WITH ULTRASONIC LOG WHILE DRILLING CALIPER
Aspects of the subject technology relate to systems, methods, and computer-readable media for identifying a borehole correction factor for determining a true resistivity by selecting a model to apply in identifying the borehole correction factor and applying the model to an apparent resistivity to identify the borehole correction factor. To perform borehole correction, a multiplicative coefficient is needed to apply to the apparent resistivity. A database of this multiplicative coefficient, called the borehole correction factor, is generated based on the borehole correction model. The technology described herein allows operators to avoid time-consuming variable borehole diameter sweeps and complex borehole diameter inversion current used in resistivity logging software.
G01V 1/40 - Seismology; Seismic or acoustic prospecting or detecting specially adapted for well-logging
E21B 47/14 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling using acoustic waves
42.
METHOD OF DRILLING A WELLBORE PENETRATING A SUBTERRANEAN FORMATION
A method of drilling a wellbore penetrating a subterranean formation, the method including: drilling the wellbore to a first location in a non-production zone of the subterranean formation while circulating a first drilling fluid composition having a first bridging agent with a first predetermined particle size; and drilling the wellbore to a second location in a production zone of the subterranean formation while circulating a second drilling fluid composition having a second bridging agent with a second predetermined particle size; wherein the second location is downhole the first location, and the first bridging agent transitions to the second bridging agent as the second bridging agent is added to the drilling fluid at the surface.
An electric submersible pump (ESP) assembly. The ESP assembly comprises an electric motor; a seal section coupled to the electric motor; a fluid intake coupled to an uphole end of the seal section, wherein the fluid intake defines a plurality of inlet ports; a gas separator comprising a plurality of gas phase discharge ports, and at least one liquid phase discharge port, wherein the gas separator is located uphole of the fluid intake; a centrifugal pump comprising a fluid inlet at a downhole end, wherein the at least one liquid phase discharge port of the gas separator is fluidically coupled to the fluid inlet of the centrifugal pump; and an inverted shroud assembly, wherein a downhole end of the inverted shroud assembly is coupled to an outside of the gas separator downhole of the gas phase discharge ports of the gas separator and uphole of the fluid intake.
An electric submersible pump (ESP) assembly. The ESP assembly comprises an electric motor; a seal section coupled to an uphole end of the electric motor; a fluid intake coupled to an uphole end of the seal section, wherein the fluid intake defines a plurality of inlet ports; a gas separator coupled to an uphole end of the fluid intake, wherein the gas separator has a plurality of gas phase discharge ports; a pump assembly coupled to an uphole end of the gas separator; and an intake extension tubular, wherein an uphole end of the intake extension tubular is coupled to the fluid intake uphole of the inlet ports, and wherein an annulus defined between an inside of the intake extension tubular and an outside of the seal section defines a fluid flow path from a downhole end of the intake extension tubular to the inlet ports of the fluid intake.
A stand-alone packer has a compressible packer element having an upper end and a lower end disposed about a packer body. A setting sleeve is disposed about the packer body above the compressible packer element. A packer stop having a flat annular upper face is positioned on the packer body below the compressible packer element and a sliding sleeve is disposed in the packer body and detachably connected to the setting sleeve.
A method and system for generating an acoustic log. The method may comprise disposing an acoustic logging tool in a wellbore, broadcasting a shaped signal with the acoustic logging tool such that the shaped signal interacts with a boundary of a casing and a material, recording a result signal from the boundary with the acoustic logging tool, and decomposing the result signal into a resonance mode. The method may further comprise applying a bandpass filter to the resonance mode to form a filtered signal, selecting a baseline signal from the filtered signal, removing the baseline signal from the filtered signal, and generating a log from the filtered signal. The system may comprise an acoustic logging tool. The acoustic logging tool may comprise at least one transmitter and at least one receiver. The system may further comprise a conveyance and an information handling system communicatively connected to the acoustic logging tool.
G01V 1/44 - Seismology; Seismic or acoustic prospecting or detecting specially adapted for well-logging using generators and receivers in the same well
E21B 47/14 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling using acoustic waves
47.
AUTONOMOUS UNCERTAINTY-AWARE ENGINE FOR PRESSURE GRADIENT IDENTIFICATION USING A DISCRETE OPTIMIZATION FRAMEWORK
A method and system for identifying a fluid within a subterranean formation. The method may comprise obtaining one or more pressure measurements at one or more depths with a downhole fluid sampling tool, forming a depth-pressure measurement set form the one or more pressure measurements, creating a solution novelty threshold from at least the depth-pressure measurement set, constraining a solution space with the solution novelty threshold, and finding a solution-space-inscribed simplex within the solution novelty threshold. The method may further comprise generating a simplicial decomposition for a convex hull of the solution-space-inscribed simplex up to the solution novelty threshold, identifying at least one inscribed simplex within the convex hull of the solution-space-inscribed simplex, determining a novel simplex interior with the at least one inscribed simplex, and forming a plurality of solutions with the novel simplex interior.
A rotating ball valve may be employed in a liner hanger setting tool. A rotating ball member maintains contact with a valve seat throughout the operation of the rotating ball valve, thereby preventing debris from settling on the valve seat and compromising the integrity of a seal through a fluid flow path defined through the setting tool. The rotating ball valve may be actuated by selectively applying fluid pressure to the flow path, or by mechanical manipulation. Once the fluid flow path is closed, a latch may be activated to maintain the rotating ball valve in the closed configuration and a pressure may be applied against the closed rotating ball member. A downhole movement be induced by the applied pressure to drive an expansion cone through an expandable liner hanger, to secure a liner in the wellbore.
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 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 34/10 - Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole
A detonator housing facilitates assembly of detonator components of a perforating gun. In an example, the detonator housing comprises a housing body configured for coupling to a charge tube of a perforating gun. A detonator receptacle is formed on the housing body for receiving a detonator. A detonating cord receptacle is formed on the housing body adjacent the detonator receptacle for receiving an end portion of a detonating cord in an overlapping relationship with the detonator. A detonating cord stop is formed on the detonating cord receptacle to limit an insertion depth of the detonating cord within the detonating cord receptacle.
Aspects of the subject technology relate to systems and methods for identifying the quality of cement bonding of an exterior surface of a wellbore casing to an Earth formation. Methods of the present disclosure may allow for bond indexes to be identified in real-time as a cementing operation is performed even when tools that perform the cementing operation generate acoustic noise that interfere with measurements used to evaluate cement bonding quality. These methods may include transmitting acoustic signals, receiving acoustic signals, filtering the received acoustic signals, identifying magnitude and attenuation values to associate with the received acoustic signals, and comparing trends in the magnitudes with the identified attenuation values. These methods may also include correcting attenuation values associated with measured data based on a set of correction rules such that bond indexes can be identified. Such correction rules may be associated with data generated by a computer model.
E21B 47/14 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling using acoustic waves
A shifting sleeve tieback seal system may include a body portion and a swellable material disposed about a circumference of the body portion. The swellable material is configured to expand in response to exposure to wellbore fluids. Further, the system may include an upper end ring disposed in a position axially above the swellable material, a lower end ring disposed in a position axially below the swellable material, and a sleeve disposed radially outward from the swellable material and sealed against the upper end ring and/or the lower end ring in a run-in position to isolate the swellable material from wellbore fluids. The sleeve is configured to contact a downhole feature in a setting position and contact with the downhole feature is configured to move the sleeve to expose the swellable material to wellbore fluids such that the swellable material expands to seal against a downhole tubular.
A method comprising transmitting, by an electric conductor disposed in a wellbore, a time-varying electric signal to a first reflector wirelessly coupled to the electric conductor and a sensor, wherein the sensor is wirelessly coupled to the electric conductor via the first reflector, receiving a first reflected signal from the first reflector, analyzing the first reflected signal to determine a sensor value for the sensor, and determining, based on the sensor value, one or more downhole parameters.
E21B 47/125 - 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 earth as an electrical conductor
A method and system for identifying scale. The method may include disposing a fluid sampling tool into a wellbore. The fluid sampling tool may comprise at least one probe configured to fluidly connect the fluid sampling tool to a formation in the wellbore and at least one passageway that passes through the at least one probe and into the fluid sampling tool. The method may further comprise drawing a formation fluid, as a fluid sample, through the at least one probe and through the at least one passageway, perturbing the formation fluid, and analyzing the fluid sample in the fluid sampling tool for one or more indications of scale.
Cement bonding evaluation and logging in a wellbore environment are described. The cement bonding evaluation is performed using data associated with and processed from the measurement of sonic waves directed to and dissipated by the casing present in the wellbore.
E21B 47/005 - Monitoring or checking of cementation quality or level
E21B 47/14 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling using acoustic waves
55.
MULTILATERAL JUNCTION INCLUDING A NON-THREADED COUPLING
Provided is a multilateral junction and a well system. The multilateral junction, in one aspect, includes a housing, the housing including a first housing end and a second housing end, a bore extending through the housing from the first housing end to the second housing end, and a bore coupling profile located along an inside surface of the bore proximate the second housing end. The multilateral junction, according to this aspect, further includes a multilateral bore leg extending into the bore, the multilateral bore leg including a tubular having a first tubular end and a second tubular end, and a tubular coupling profile located along an outside surface of the tubular proximate the first tubular end. The multilateral junction, according to this aspect, further includes an arced coupling located between the bore and the tubular and engaged with the bore coupling profile and the tubular coupling profile.
Provided is a multilateral junction and a well system. The multilateral junction, in one aspect, includes a housing, the housing including a first housing end and a second housing end, a bore extending through the housing from the first housing end to the second housing end, and a toothed coupling profile located along an inside surface of the bore proximate the second housing end. The multilateral junction, according to this aspect, further includes a multilateral bore leg extending into the bore, the multilateral bore leg including a tubular having a first tubular end and a second tubular end. The multilateral junction, according to this aspect, further includes a toothed coupling located between the bore and the tubular and engaged with the toothed coupling profile and the tubular to axially fix the housing and the multilateral bore leg relative to one another.
Systems and methods are provided for determining the wideband spectrum of downhole fluids based on downhole optical measurements. In some aspects, a plurality of optical data measurements associated with a subsurface fluid can be obtained from a subsurface optical measurement device. In some cases, a comparison can be made between the plurality of optical data measurements associated with the subsurface fluid and one or more sets of optical data stored in an optical data library. In some examples, the one or more sets of optical data can correspond to a plurality of different fluid samples. In some instances, a first fluid sample from the plurality of fluid samples that corresponds to at least a portion of the subsurface fluid can be identified based on the comparison. In some aspects, an absorbance spectrum of the subsurface fluid can be determined based on the first fluid sample.
A flow control system for use in controlling flow of a fluid composition in a subterranean well is disclosed. The flow control system includes a flow chamber that includes an inlet and an outlet oriented such that the fluid composition flows circuitously through the chamber, forming a vortex at least at the outlet. The flow control system further comprises at least one flow control structure shaped and positioned in the flow chamber such that a velocity of the circuitous flow is reduced and the vortex is eliminated or substantially reduced.
An acoustic actuator for scale removal and prevention in a wellbore is described herein. For example, a system can include a tubing string deployed downhole in a wellbore. A downhole tool can be coupled to the tubing string. An acoustic actuator can be coupled to the tubing string and positioned proximate to the downhole tool. The acoustic actuator can generate an acoustic signal that can vibrate the tubing string to generate a fluidic disturbance in downhole fluid within the tubing string for removing contaminants from, or preventing formation of contaminants, on the downhole tool.
E21B 47/14 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling using acoustic waves
E21B 34/10 - Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole
B06B 1/02 - Processes or apparatus for generating mechanical vibrations of infrasonic, sonic or ultrasonic frequency making use of electrical energy
60.
ELECTROMAGNETIC ATTRACTION ON THE FLOW SLEEVE OF TRSVS
Provided is a subsurface safety valve (SSSV), a well system, and a method. The subsurface safety valve (SSSV), in one aspect, includes an outer housing, a valve closure mechanism coupled to the outer housing, and a bore flow management actuator disposed in the central bore, the bore flow management actuator configured to slide from a first state to a second state to move the valve closure mechanism between a closed state and an open state. The subsurface safety valve (SSSV), in this aspect, additionally includes an electromagnet positioned at: 1) a first location, the first location in the outer housing proximate where the bore flow management actuator resides when the bore flow management actuator is in the second state; or 2) a second location, the second location coupled proximate a downhole end of the bore flow management actuator.
Injection into a subterranean formation is optimized using a computation model to optimize injection. An optimization objective is to maximize the cumulative fluid mass rates injection that span over the remaining life of the field, while maintaining a dense or supercritical phase and operating within the equipment operational parameters. The phase at each location may be determined based on pressure and temperature, and flow is dynamically adjusted to maintain a phase having at least a threshold density of the carbon dioxide injected at each injection location.
A downhole transducer can include at least one single-crystal piezoelectric material, the at least one single-crystal piezoelectric material being positioned in the downhole transducer that is deployed downhole in a wellbore. Additionally, the downhole transducer can include at least one pair of electrodes positioned adjacent to the at least one single-crystal piezoelectric material for determining wellbore parameter measurements using one or more acoustic signals transmitted in the wellbore. The single-crystal piezoelectric material can include PIN-PZN-PT.
G01V 1/44 - Seismology; Seismic or acoustic prospecting or detecting specially adapted for well-logging using generators and receivers in the same well
E21B 47/14 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling using acoustic waves
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
63.
REAL-TIME CEMENT BOND LOGGING BASED ON CORRELATION
Aspects of the subject technology relate to systems and methods for identifying the quality of cement bonding of an exterior surface of a wellbore casing to an Earth formation. Methods of the present disclosure may allow for bond indexes to be identified in real-time as a cementing operation is performed even when tools that perform the cementing operation generate acoustic noise that interfere with measurements used to evaluate cement bonding quality. These methods may include transmitting acoustic signals, receiving acoustic signals, filtering the received acoustic signals, identifying magnitude and attenuation values to associate with the received acoustic signals, and comparing trends in the magnitudes with the identified attenuation values. These methods may also include correcting attenuation values associated with measured data based on a set of correction rules such that bond indexes can be identified. Such correction rules may be associated with data generated by a computer model.
G01V 1/40 - Seismology; Seismic or acoustic prospecting or detecting specially adapted for well-logging
E21B 47/14 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling using acoustic waves
64.
FLUID TIGHT FLOAT FOR USE IN A DOWNHOLE ENVIRONMENT
Provided is a float for use with a fluid flow control device, a fluid flow control device, a method for manufacturing a float, and a well system. The float, in one aspect, includes a fluid tight enclosure. The float, according to this aspect, further includes density specific material located within the fluid tight enclosure, the fluid tight enclosure and the density specific material creating a net density for the float that is between a first density of a desired fluid and a second density of an undesired fluid, such that the float may control fluid flow through a flow control device when encountering the desired fluid or the undesired fluid.
A method may include: introducing a resin modified cement slurry into a wellbore penetrating a subterranean formation, the subterranean formation comprising a caprock and a carbon dioxide injection zone, the resin modified cement slurry comprising: a resin; a hardener; a hydraulic cement; and water; and setting the resin modified cement slurry to form a set cement wherein the set cement forms a carbonation-resistant barrier in the carbon dioxide injection zone in the subterranean formation.
E21B 33/13 - Methods or devices for cementing, for plugging holes, crevices, or the like
E21B 43/16 - Enhanced recovery methods for obtaining hydrocarbons
C09K 8/467 - Compositions for cementing, e.g. for cementing casings into boreholes; Compositions for plugging, e.g. for killing wells containing inorganic binders, e.g. Portland cement containing additives for specific purposes
66.
DETERMINATION OF LOCATION AND TYPE OF RESERVOIR FLUIDS BASED ON DOWNHOLE PRESSURE GRADIENT IDENTIFICATION
A method comprises receiving a measurement of a pressure in a subsurface formation at a number of depths in a wellbore formed in the subsurface formation across a sampling depth range of the subsurface formation to generate a number of pressure-depth measurement pairs and partitioning the sampling depth range into a number of fluid depth ranges. The method comprises performing a fitting operation over each of the number of fluid depth ranges to determine a fluid gradient for the type of the reservoir fluid for each of the number of fluid depth ranges. The method comprises generating a solution set of one or more solutions based on the fluid gradient of the reservoir fluid for each of the number of fluid depth ranges determined from performing the fitting operation, wherein each solution defines a partitioning of the sampling depth range and the fluid gradient of each fluid depth range.
A system can display confidence values in a wellbore inversion model using a visual indicator. The system can receive downhole data relating to the wellbore from a downhole tool deployed in a wellbore of a geological formation during a wellbore operation. The system can additionally generate an inversion model of the geological formation by performing inversion processing on the downhole data. Furthermore, the system can determine confidence values for the downhole data in the inversion model. Additionally, the system can determine a depth of detection limit for the downhole data based on the confidence values. The system can output the inversion model, the depth of detection limit, and a visual indicator based on the confidence values for display at a display device for use in adjusting the wellbore operation.
A cement slurry including graphene, a cementitious material, and water; the graphene comprises bioderived renewable graphene (BRG). The cement slurry can comprise from about 0.01 to about 20, from about 0.1 to about 15, from about 0.5 to about 5 percent graphene by weight of cementitious material (% graphene bwoc). The cement slurry can have enhanced stability, as evidenced by a uniform density of the slurry and a reduction in free fluid, according to API 10B-2, relative to a same cement slurry absent the graphene.
C09K 8/467 - Compositions for cementing, e.g. for cementing casings into boreholes; Compositions for plugging, e.g. for killing wells containing inorganic binders, e.g. Portland cement containing additives for specific purposes
C04B 28/02 - Compositions of mortars, concrete or artificial stone, containing inorganic binders or the reaction product of an inorganic and an organic binder, e.g. polycarboxylate cements containing hydraulic cements other than calcium sulfates
A cement slurry including graphene, a cement, and water; the graphene comprises bioderived renewable graphene (BRG). The cement slurry has reduced transient gel formation relative to a same cement slurry absent the graphene. Methods of mitigating transient gels in cement are also provided.
E21B 33/14 - Methods or devices for cementing, for plugging holes, crevices, or the like for cementing casings into boreholes
E21B 21/06 - Arrangements for treating drilling fluids outside the borehole
E21B 43/26 - Methods for stimulating production by forming crevices or fractures
C09K 8/46 - Compositions for cementing, e.g. for cementing casings into boreholes; Compositions for plugging, e.g. for killing wells containing inorganic binders, e.g. Portland cement
A cement slurry includes a set retarder comprising graphene, a cementitious material, and water; the graphene comprises bioderived renewable graphene (BRG). The cement slurry has from about 0.01 to about 20, from about 0.1 to about 15, or from about 0.5 to about 5 percent graphene by weight of cementitious material (% graphene bwoc). The cement slurry has an increased thickening time relative to a same cement slurry absent the graphene.
C09K 8/467 - Compositions for cementing, e.g. for cementing casings into boreholes; Compositions for plugging, e.g. for killing wells containing inorganic binders, e.g. Portland cement containing additives for specific purposes
C04B 28/02 - Compositions of mortars, concrete or artificial stone, containing inorganic binders or the reaction product of an inorganic and an organic binder, e.g. polycarboxylate cements containing hydraulic cements other than calcium sulfates
Systems and techniques are described for a fluid diode. In some examples, a fluid diode can include a first fluid path for a first flow of fluid to traverse the fluid diode via a first flow direction and a second fluid path for a second flow of fluid to traverse the fluid diode via a second flow direction. The first flow direction can be associated with a first pressure drop and the second flow direction can be associated with a second pressure drop that is different than the first pressure drop. Moreover, the first fluid path and the second fluid path can be configured to remain open to the first flow and the second flow in the first flow direction and the second flow direction.
A drilling assembly control system is designed to mitigate drilling vibration by detecting and classifying lateral vibrations. Vibrations are detected along a bottom hole assembly using one or more inertial measurement units, those vibration measurements are classified by lateral vibration type, and mitigating actions are determined.
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
A composition including a particulate, water, and a suspension aid comprising graphene, wherein the graphene comprises bioderived renewable graphene (BRG) and wherein the particulate is suspended in the composition. Methods of making and using the composition are also provided.
The disclosure presents processes to determine one or more recommendations to well construction operations, generated by analyzing impacts on well construction operations. The impacts can include impacts to the drilling assembly, impacts of the subterranean formation characteristics, impacts on cost, time and performance of the well construction operation, impacts on the service quality, impacts to system integrity, impacts to surface equipment, as well as other impact types, such as geological surveys, seismic surveys, stratigraphic analysis, or reservoir estimations. Each impact can be analyzed using an impact parameter and a softness parameter. An impact map can be computed for each of the parameters, and then the impact maps can be combined to compute one or more integrated impact maps from which the recommendations can be determined. The recommendations can be communicated to a well construction system, such as a geo-steering system, a user system, a well site controller, or other systems.
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 47/12 - 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 sealed enclosure can include a glass portion that can be positioned with respect to an electromagnetic component that is in an area defined by the sealed enclosure. The enclosure can prevent fluid from a wellbore environment from contacting the electromagnetic component and to allow the electromagnetic component to wirelessly communicate with a component external to the sealed enclosure. A second portion interfaces with the glass portion for preventing the fluid from the wellbore environment from contacting the electromagnetic component.
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
E21B 47/13 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling by electromagnetic energy, e.g. of radio frequency range
E21B 47/01 - Devices for supporting measuring instruments on drill bits, pipes, rods or wirelines; Protecting measuring instruments in boreholes against heat, shock, pressure or the like
A mechanical clutch allows for transfer of torque downhole that may avoid the need for a hydraulic electrical coil-driven piston. In one or more examples, an anti-rotation guide for a downhole clutch includes a guide track and a follower moveable along the guide track for guiding relative movement between an upper armature and a lower armature. The guide track includes an axially-extending portion terminating in a circumferential loop. The axially extending portion guides the upper armature into axial engagement with the lower armature in response to rotation of the input shaft. The circumferential loop thereafter allows rotation of the upper and lower armatures together in response to further rotation of the input shaft.
A downhole tool can include a position sensor comprising a first set of magnets and an internal slider. The downhole tool can also include a valve magnet assembly comprising a second set of magnets magnetically couplable to the first set of magnets. The second set of magnets can be positionable circumferentially around an outer diameter of the position sensor. The valve magnet assembly can be configured to move in response to a fluid valve. The valve magnet assembly can be configured to cause the internal slider of the position sensor to move in response to movement of the valve magnet assembly.
E21B 34/10 - Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole
E21B 34/08 - Valve arrangements for boreholes or wells in wells responsive to flow or pressure of the fluid obtained
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
Systems and methods of the present disclosure relate to actuator assemblies for downhole tools. An actuator assembly comprises a ball screw; a ball nut disposed around the ball screw; a cam disposed around the ball nut; a rail disposed adjacent to the cam, the rail operable to stop rotation of the cam to extend the cam axially as the ball nut traverses the ball screw.
A system can be used for generating a pressure signal in a flow path defined by a tubular. The system can include a pressure source, a valve, and a controller. The controller can output a command to control the pressure source for outputting a fluid hammer, according to the command, through the valve and into a flow path defined by a wellbore tubular. The system can be positioned external to the flow path. The system can determine, based on the reflection signal, a presence of a deposition, a blockage, or a leak within the flowline while the flowline is in operation.
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
Aspects of the subject technology relate to systems, methods, and computer-readable media for identifying a relative permeability of a core sample through a computerized representation of a pore structure of the sample. Specifically, a computerized representation of a three-dimensional (3D) pore structure of a core sample can be accessed. A relative permeability of oil through the 3D pore structure can be determined in three dimensions. Further, a relative permeability of water through the 3D pore structure can be determined in the three dimensions. Average relative permeabilities of oil and water of the 3D pore structure can be identified based on the relative permeability of the oil in the three dimensions and the relative permeability of the water in the three dimensions.
E21B 49/02 - 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
G01N 15/08 - Investigating permeability, pore volume, or surface area of porous materials
81.
DENSITY SENSOR FOR QUANTIFYING PRODUCTION FLUID CONTENT
Provided is a density sensor, a downhole tool, and a well system. The density sensor, in one aspect, includes one or more float chambers, and two or more floats located within the one or more float chambers. In one aspect, the two or more floats have a density ranging from.08 sg to 2.1 sg, and further a first of the two or more floats has a first known density (ρ1) and a second of the two or more floats has a second known density (ρ2) greater than the first known density (ρ1). The density sensor, according to this aspect, may further include one or more sensors located proximate the one or more float chambers, the one or more sensors configured to sense whether ones of the two or more floats sink or float within production fluid having an unknown density (ρf).
E21B 47/10 - Locating fluid leaks, intrusions or movements
E21B 41/00 - Equipment or details not covered by groups
E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in 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
82.
SENSOR FOR QUANTIFYING PRODUCTION FLUID PERCENTAGE CONTENT
1go2oww). The downhole tool, according to this aspect, further includes two or more non-contact proximity sensors configured to sense a radial location of the two or more floats to determine a gas:oil ratio and oil:water ratio.
E21B 47/10 - Locating fluid leaks, intrusions or movements
E21B 41/00 - Equipment or details not covered by groups
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 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
A body of a shear pin can be positioned in a pad stopper of a steering pad of a rotary steerable system. The rotary steerable system can be used to steer a drill in a wellbore. The steering pad can be positioned on the rotary steerable system such that a head of the shear pin is coupled with a lateral pad of the rotary steerable system. The head of the shear pin can deactivate the steering pad by preventing the steering pad from actuating. A fluid pulse can be output in the wellbore to break the shear pin for enabling the steering pad to actuate to cause the rotary steerable system to steer the drill in the wellbore.
A rotary steerable drilling system can be positioned in a subterranean formation to steer a drill to form a wellbore in the subterranean formation. An orientation of a steering valve, which is positioned in the rotary steerable drilling system, can be adjusted to cover each channel of one or more channels of a valve seat adjacent the steering valve to deactivate each steering pad of one or more steering pads of the rotary steerable drilling system. The orientation of the steering valve can be adjusted to activate at least one steering pad of the one or more steering pads of the rotary steerable drilling system.
E21B 44/00 - Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systems; Systems specially adapted for monitoring a plurality of drilling variables or conditions
A method for controlling, tailoring, monitoring and executing a pumping operation of a wellbore treatment into a wellbore with an advisory process accessing pumping simulation results from a pumping model group. The advisory process can determine a change in the wellbore environment by comparing periodic datasets indicative of a pumping operation to a set of operational threshold values. The advisory process can identify the change in the wellbore environment from pumping simulation results generated by a pumping model group with pumping model inputs comprising portions of the periodic datasets. The advisory process can generate a modified pumping procedure in response to the identification of the change in the wellbore environment. The pumping model group can generate and forecast a probability of the pumping operation achieving a job objective.
E21B 33/14 - Methods or devices for cementing, for plugging holes, crevices, or the like for cementing casings into boreholes
E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
E21B 47/005 - Monitoring or checking of cementation quality or level
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
86.
UTILIZING RESISTIVITY DISTRIBUTION CURVES TO IMPROVE GEO-STEERING
Processes utilize collected resistivity data from an ultra-deep resistivity tool located downhole a borehole. A machine learning system (MLS) can be utilized to analyze and process the resistivity data. Directions can be generated using the resistivity data that is communicated to other systems, such as a geo-steering, an evaluation, or other borehole systems. In some aspects, a recommendation can be generated that includes subterranean formation characteristics with the directions. The recommendation can be used by a user system to approve or reject the directions prior to being communicated to a borehole system or geo-steering system. In some aspects, a confidence level can be generated with the directions or recommendation, and the confidence level can be evaluated whether it satisfies a confidence level threshold. In some aspects, when the confidence level threshold is satisfied, the directions can be automatically communicated to the geo-steering system without user review.
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
E21B 44/00 - Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systems; Systems specially adapted for monitoring a plurality of drilling variables or conditions
A controllable downhole scraper includes a fluid reservoir having a pressure wall positioned and movable within the fluid reservoir defining a first portion of the fluid reservoir including a first fluid. The pressure wall exerts a force on the first fluid to maintain a first pressure. A scraper blade is movable between a retracted and an extended position. A sleeve is positioned on a tubular and slidable between a first position engaging the scraper blade to move into the retracted position, and a second position engaging the scraper blade to move into the extended position. The sleeve is configured to move between the two positions through a reduction in the first pressure in the first fluid. A restrictor is fluidly coupled between the fluid reservoir and a pressure reservoir. A gas reservoir, fluidly coupled to the first fluid, is selectively operable to reduce the first pressure in the first fluid.
E21B 10/32 - Drill bits with leading portion, i.e. drill bits with a pilot cutter; Drill bits for enlarging the borehole, e.g. reamers with expansible cutting tools
88.
SENSOR AND ACTUATOR FOR AUTONOMOUSLY DETECTING RESISTIVITY DERIVATIVES OF WELLBORE FLUIDS AND CLOSING FLUID PATH
A sensor device can be used to detect the presence of a cement composition in a reverse cementing operation. The sensor device can include a resistivity sensor, an acquisition and measurement apparatus, and an actuator. The actual derivative of resistivity of the drilling mud, spacer fluid, and cement composition to be used can be pre-determined. The acquisition and measurement apparatus can be pre-programmed with a slope change derivative of resistivity profile for the fluids. The resistivity sensor can measure the resistivity of the fluids as they flow past the resistivity sensor in the wellbore. When the acquisition and measurement apparatus receives a desired slope change reading within the slope change derivative of resistivity profile, instructions can be sent to the actuator to close a valve and block fluid flow through the casing or tubing string.
A method, includes: detecting one or more properties of a waveguide having a downhole end and an uphole end; and responsive to the detected one or more properties, positioning into a passage of a wellbore the waveguide to minimize tension thereof.
E21B 47/125 - 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 earth as an electrical conductor
The disclosure provides a data clustering process for interpreting formation data, such as delineating reservoirs in well placement models. The data clustering process can be used with correlating offset well data and high angle or horizontal (HAHZ) target well data. Facies distribution and thus stratigraphy and the position of a borehole within the stratigraphic setting can also be assessed using the data clustering process via unsupervised computer learning techniques. A method of performing a well operation associated with a wellbore and an automated directional drilling system are provided herein. In one example, the method includes: (1) obtaining target well data from a wellbore in a subterranean formation, (2) generating a facies cluster model for the subterranean formation using a clustering process on the target well data, and (3) performing a well operation associated with the wellbore using the facies cluster model.
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
Aspects of the disclosed technology provide solutions for facilitating user visualization and control the path of a new wellbore in three-dimensions (3D). This may include displaying visualizations that show a current well path, a well plan, all nearby offset well paths, and well path projections in a manner that may use different projection methods. These visualizations may also include boundaries where a drilling tool should not go, such "No-Go-Zones" may be shown in a 3D spatial visualization. Visualizations may be displayed continuously along the well path, at survey stations, and at user-defined depth positions during a drilling process. Such visualizations may include projections that show an anticipated wellbore path, based on current settings of a drilling control system. Alerts may be triggered to warn users of various issues that may affect a new well being drilled. Systems, methods, and computer-readable media are provided.
Systems and methods are provided for determining the end of a reverse cementing operation based on one or more pressure measurements. In some aspects, a cement composition can be delivered to an annulus formed between a casing and a wellbore for reverse cementing the casing. In some cases, a determination that the cement composition has reached a shoe joint at a bottom portion of the casing can be based on a threshold change in a pressure measurement obtained while delivering the cement composition. In some instances, a trigger can be initiated for closing the shoe joint after determining that the cement composition has reached the shoe joint.
A downhole apparatus has a sleeve body sleeve body defining a sleeve body inner surface. The sleeve body has an internal thread on at least a portion thereof. The internal thread defining having a thread minor diameter. A plug seat is pressed into the threaded portion of the sleeve body. The plug seat has an unthreaded outer surface defining a plug seat outer diameter. The plug seat outer diameter is greater than the thread minor diameter.
E21B 33/05 - Cementing-heads, e.g. having provision for introducing cementing plugs
E21B 33/16 - Methods or devices for cementing, for plugging holes, crevices, or the like for cementing casings into boreholes using plugs for isolating cement charge; Plugs therefor
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 17/042 - Couplings; Joints between rod and bit, or between rod and rod threaded
94.
METHOD OF GROUT SELECTION FOR LONG TERM INTEGRITY OF ANCHORING PILES
A method of designing a grout material for an anchoring pile system based on the analysis of a stress state of the anchoring pile constructed into a subterranean formation. An advisory process can utilize a model to produce a numerical model of the anchoring pile, a model to determine the operational loads, a model to determine the grout material, and a model to determine the stress state of the grout interfaces. The group of models can determine a probability of failure of the grout material, a probability of failure of a grout interface, and a predicted lifespan of the grout materials.
E02D 27/42 - Foundations for poles, masts, or chimneys
G06F 30/28 - Design optimisation, verification or simulation using fluid dynamics, e.g. using Navier-Stokes equations or computational fluid dynamics [CFD]
G06F 30/13 - Architectural design, e.g. computer-aided architectural design [CAAD] related to design of buildings, bridges, landscapes, production plants or roads
Provided is an inner sleeve, a downhole tool, and a method for cementing. The inner sleeve, in at least one aspect, includes a tubular having an inside tubular surface and an outside tubular surface. The inner sleeve, according to this aspect, further includes a collet including two or more collet fingers coupled to one end of the tubular, the collet having an inside collet surface and an outside collet surface, and further wherein the inside collet surface flares outward from the inside tubular surface by an angle (?0) when the collet is in its natural state.
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 23/04 - 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 33/14 - Methods or devices for cementing, for plugging holes, crevices, or the like for cementing casings into boreholes
96.
MAGNETIC SENSOR ASSEMBLY HAVING A NON-FLAT SHAPE PLUG FOR CEMENT SLURRY SENSING
Disclosed herein are embodiments of a sensor assembly apparatus, system, and method. In one embodiment, an apparatus comprises a sensor assembly adapted to be integrated into a casing to be positioned in a wellbore, the sensor assembly comprising a housing; a magnet located within the housing; a magnetic sensor located within the housing to measure a magnetic measurement change resulting from a force between the magnet and magnetic particles flowing with a cement slurry inside the casing from a reverse cementing; and a sensor plug having a side with a non-flat shape that is to be in contact with the slurry flowing in the casing of the wellbore; a processor communicatively coupled to the magnetic sensor and configured to determine whether the magnetic measurement change exceeds a magnetic threshold; and determine that the slurry is flowing back up internal to the casing at or beyond a location in the wellbore.
E21B 47/005 - Monitoring or checking of cementation quality or level
E21B 33/16 - Methods or devices for cementing, for plugging holes, crevices, or the like for cementing casings into boreholes using plugs for isolating cement charge; Plugs therefor
A fiber optic sensing (FOS) system may include a Brillouin Optical Time Domain Analyzer (BOTDA) unit, a first fiber optical cable optically connected to the BOTDA interrogator unit at a first end, and an optical feedthrough system (OFS) optically connected the first fiber optical cable at a second end of the first fiber optical cable. The FOS system may further comprise a fiber optic cable forming a loop within a wellbore that is optically connected to the first fiber optical cable at the OFS and a second fiber optical cable optically connected to the loop at the OFS and wherein the second fiber optical cable is optically connected to the BOTDA interrogator unit.
E21B 47/125 - 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 earth as an electrical conductor
E21B 47/14 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling using acoustic waves
Some implementations relate to a computer-implemented method for creating digital acoustic sensing (DAS) related training data for a learning machine. The method may include moving a first optimal microseismic event location to a first perturbed microseismic event location in each of a plurality of first images. The method also may include modifying first shear waves and first compressional waves in each of the first images based on one or more signal travel times between the first perturbed microseismic event location and a fiber optic cable to form a plurality of training images configured to train a learning machine.
Aspects of the subject technology relate to systems and methods for configuring links or switches that connect analog circuit elements. These analog circuit elements may be connected to a plurality of sensors that may sense different types of data. For example, these sensors may sense acoustic data, electromagnetic (EM) data, temperature, pressure, and possibly other metrics that may be located in a wellbore of an oil or gas well. These analog circuits may be configured as needed (e.g., on-the-fly) to perform optimized types of computations that may include the solving of differential equations. Examples of analog circuits that may be incorporated into a sensing system include yet are not limited to operational amplifier circuits or memcomputing devices, other components, or combinations thereof. Configured analog circuits may be coupled to digital electronics that perform other functions.
G01V 1/40 - Seismology; Seismic or acoustic prospecting or detecting 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
A stage cementing tool for a wellbore comprises a tool body defining a flow port in a wall thereof. The tool body and wellbore define an annulus therebetween. A setting sleeve compresses a packer element as it moves from the first to the second position. The packer element expands radially outwardly to engage the wellbore as a result of the compression applied by the setting sleeve. A pump-out plug in the tool body is expellable into the annulus upon the application of pressure in the tool body after the packer element engages the wellbore.
E21B 33/14 - Methods or devices for cementing, for plugging holes, crevices, or the like for cementing casings into boreholes
E21B 33/16 - Methods or devices for cementing, for plugging holes, crevices, or the like for cementing casings into boreholes using plugs for isolating cement charge; Plugs therefor
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
patents
