Methods and systems described herein may comprise a neutron generator tube; a gas replenisher; and a heat blanket applied to the neutron generator tube configured to insulate the gas replenisher. In addition, the heat blanket comprises an acrylic polymer-based elastomer. Further, the acrylic polymer-based elastomer is cross-linked with mineral fillers to form a composite material.
H05B 3/34 - Heating elements having extended surface area substantially in a two-dimensional plane, e.g. plate-heater flexible, e.g. heating nets or webs
G01V 5/10 - Prospecting or detecting by the use of ionising radiation, e.g. of natural or induced radioactivity specially adapted for well-logging using primary nuclear radiation sources or X-rays using neutron sources
2.
DOWNHOLE TOOL EMPLOYING A WHIPSTOCK ASSEMBLY, PACKER ASSEMBLY AND DOWNHOLE POWER UNIT
Provided, in one aspect, is a downhole tool, a well system, and a method. The downhole tool, in one aspect, includes a whipstock assembly, the whipstock assembly including a whipface. The downhole tool, in one aspect, further includes a packer assembly coupled to the whipstock assembly, the packer assembly including a packer element configured to move between a radially retracted state and a radially expanded state. The downhole tool, in one aspect, may further include a downhole power unit coupled to the packer assembly, the downhole power unit configured to move the packer element between the radially retracted state and the radially expanded state.
Disclosed embodiments relate to electric safety valves for a well, which may be configured to close in the event of a power loss for example. In embodiments, the electric safety valve may include an electro-magnetic tooth brake system. For example, a plurality of teeth may be coupled to a translating sleeve disposed within an outer housing, a pinion may be mounted within the outer housing and configured to mesh with the plurality of teeth, and an electric tooth brake may have brake teeth configured to engage the pinion upon activation of an electro-magnet. Thus, when the electro-magnet is powered and the teeth are engaged/meshing, the translating sleeve may be held in position to hold open the valve. A loss of power may disengage the teeth, releasing the translating sleeve and allowing the valve to close. Related methods and systems are also disclosed.
Some implementations include a system comprising a first tubular fluidically connected with one or more frac pumps and one or more first flow control devices that are fluidically connected to a second tubular that is fluidically connected to a wellhead. The system also may include a third tubular fluidically connected with the first tubular and one or more second flow control devices that are connected with a fourth tubular that is fluidically independent of the wellhead.
Aspects of the disclosed technology provide solutions for optimizing pumps in hydraulic fracturing and, in particular, for determining optimal pump rate setpoints for a plurality of fracturing pumps. A process of the disclosed technology can include steps for coupling a plurality of fracking pumps to a respective controller and coupling a manifold to each of the fracking pumps. The process can further include steps for coupling a control system to each of the respective controllers, wherein the control system is configured to perform operations for receiving a total pump rate for the manifold and determining a plurality of pump rate setpoints for each of the plurality of fracking pumps and transmitting the plurality of pump rate setpoints to each of the respective controllers. Systems and machine-readable media are also provided.
A method comprises obtaining a fluid sample produced from a subsurface formation. The method comprises loading the fluid sample into a device configured with one or more cameras. The method comprises obtaining, via the one or more cameras, media content of the fluid sample. The method comprises determining, via a learning machine, one or more sample properties of the fluid sample based on the media content.
A method and a system comprising disposing an acoustic logging tool into a wellbore, wherein the acoustic logging tool comprises an acoustic transmitter, an acoustic transducer, and/or an acoustic receiver; transmitting one or more acoustic waveforms from the acoustic logging tool with the acoustic transmitter or the acoustic transducer. Additionally, the method and system may be configured for recording one or more reflected acoustic waveforms at the acoustic logging tool with the acoustic receiver or the acoustic transducer; separating a first echo segment and a reverberation segment of a reflected waveform from the one or more reflected acoustic waveforms; and performing an inversion on at least the first echo segment, wherein the inversion comprises: producing a casing thickness.
G01V 1/40 - SeismologySeismic or acoustic prospecting or detecting 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 33/14 - Methods or devices for cementing, for plugging holes, crevices or the like for cementing casings into boreholes
Disclosed herein is a perforating system including a perforating gun and, more particularly, disclosed are methods and apparatuses using a conical perforating assembly. In one aspect, embodiments relate to a perforating assembly, that includes a charge carrier, a liner disposed in the charge carrier, and an explosive charge disposed between the charge carrier and the liner and supported on the charge carrier, where the liner is supported on the explosive charge, where the perforating assembly has an asymmetric profile.
A method and a system comprising disposing an acoustic logging tool into a wellbore, wherein the acoustic logging tool comprises an acoustic transmitter, an acoustic transducer, and/or an acoustic receiver; transmitting one or more acoustic waveforms from the acoustic logging tool with the acoustic transmitter or the acoustic transducer. Additionally, the method and system may be configured for recording one or more reflected acoustic waveforms at the acoustic logging tool with the acoustic receiver or the acoustic transducer; separating a first echo segment and a reverberation segment of a reflected waveform from the one or more reflected acoustic waveforms; and performing an inversion on at least the first echo segment, wherein the inversion comprises: producing a casing thickness.
Provided, in one aspect, is a downhole tool, a well system, and a method. The downhole tool, in one aspect, includes a whipstock assembly, the whipstock assembly including a whipface. The downhole tool, in one aspect, further includes a packer assembly coupled to the whipstock assembly, the packer assembly including a packer element configured to move between a radially retracted state and a radially expanded state. The downhole tool, in one aspect, may further include a remote open/close valve positioned to allow fluid into the whipstock assembly.
A method comprises retrieving geoscience data of a subsurface formation into which a wellbore is being drilled and retrieving drilling operation data for drilling the wellbore. The method includes determining at least one of an optimized target trajectory of a path of the wellbore to be drilled or a series of control operations for the drilling in order to follow the path of the wellbore to be drilled, independent of using waypoints as input and based the geoscience data and the drilling operation data. The method includes modifying geosteering of the drilling of the wellbore based on the at least one of the optimized target trajectory or the series of the control operations.
E21B 44/00 - Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systemsSystems specially adapted for monitoring a plurality of drilling variables or conditions
E21B 47/005 - Monitoring or checking of cementation quality or level
12.
MANAGING SYSTEM PRESSURE WITHIN SHEAR INDUCED FRACTURE FIELD DURING HYDRUALIC FRACTURING OPERATIONS TO INCREASE THE EFFECTIVE ENERGY THAT CAN BE DELIVERED INTO THE RESERVOIR
A method comprises obtaining, via one or more sensors, measurements of a fracture system proximate one or more wellbores formed in a subsurface formation while hydraulically fracturing one or more wellbores. The method comprises identifying one or more shear induced fracture fields within the fracture system based on the measurements. The method comprises determining a pressure ceiling of the fracture system. The method comprises performing a wellbore operation to minimize wasted effective energy put into the subsurface formation, via the hydraulic fracturing, based on the shear induced fracture fields and the pressure ceiling.
E21B 47/09 - Locating or determining the position of objects in boreholes or wellsIdentifying the free or blocked portions of pipes
E21B 47/26 - Storing data down-hole, e.g. in a memory or on a record carrier
E21B 49/00 - Testing the nature of borehole wallsFormation testingMethods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
13.
ISOLATION SYSTEM FOR EQUIPMENT MAINTENANCE DURING WELL TREATMENT OPERTIONS
Disclosed embodiments include systems and methods for relatively safely providing maintenance for one bank of pumps of a pressurized wellbore services system, even while one or more other bank of pumps continues to operate (e.g. at high pressures). Further, disclosed embodiments may be configured to allow for essentially continuous pumping of fluid downhole in a well, even while maintenance is being performed. Embodiments may also allow relatively safe in situ maintenance operations without the need for separate barrier protection or shielding. For example, banks of pumps may be configured and managed/operated to address red zone concerns, providing relatively safe maintenance opportunities without the need for a barrier therebetween.
F04B 49/00 - Control of, or safety measures for, machines, pumps, or pumping installations, not otherwise provided for in, or of interest apart from, groups
F04B 47/02 - Pumps or pumping installations specially adapted for raising fluids from great depths, e.g. well pumps the driving mechanisms being situated at ground level
14.
DOWNHOLE TOOL EMPLOYING A WHIPSTOCK ASSEMBLY, PACKER ASSEMBLY AND LOWER COMPLETION
Provided, in one aspect, is a downhole tool, a well system, and a method. The downhole tool, in one aspect, includes a whipstock assembly, the whipstock assembly including a whipface. The downhole tool, in one aspect, further includes a packer assembly coupled to the whipstock assembly, the packer assembly including a packer element configured to move between a radially retracted state and a radially expanded state. The downhole tool, in one aspect, may further include a lower completion coupled downhole of the whipstock assembly.
A method comprises obtaining a fluid sample produced from a subsurface formation. The method comprises loading the fluid sample into a device configured with one or more cameras. The method comprises obtaining, via the one or more cameras, media content of the fluid sample. The method comprises determining, via a learning machine, one or more sample properties of the fluid sample based on the media content.
A method comprises retrieving geoscience data of a subsurface formation into which a wellbore is being drilled and retrieving drilling operation data for drilling the wellbore. The method includes determining at least one of an optimized target trajectory of a path of the wellbore to be drilled or a series of control operations for the drilling in order to follow the path of the wellbore to be drilled, independent of using waypoints as input and based the geoscience data and the drilling operation data. The method includes modifying geosteering of the drilling of the wellbore based on the at least one of the optimized target trajectory or the series of the control operations.
Drilling fluids for drilling a wellbore. An example drilling fluid includes an aqueous base fluid, a first fluid loss control additive that comprises a cross-linked polymer comprising N-vinylpyrrolidone as a monomer, and a second fluid loss control additive that comprises a cloud point glycol.
A method of monitoring a drilling operation of a drilling rig includes receiving one or more parameters of a drilling operation of a drilling rig. The one or more parameters are detected by one or more sensors. The method further includes recognizing, using a trained machine-learning model, a signature in the one or more parameters; determining a corrective action based on the recognized signature; and outputting a recommendation for performing the corrective action or autonomously executing the corrective action.
E21B 44/00 - Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systemsSystems specially adapted for monitoring a plurality of drilling variables or conditions
E21B 45/00 - Measuring the drilling time or rate of penetration
19.
Slip retention mechanism for downhole isolation device
Disclosed embodiments relate to isolation devices for use downhole in a wellbore, for example to isolate a zone of a well. Isolation device embodiments may include a slip, a wedge, a seal element, and a retaining mechanism. The slip may have a run-in position with respect to the wedge and a set position with respect to the wedge. The seal element may be configured to expand radially during movement from the run-in position to the set position. The retaining mechanism may be configured to allow movement of the slip from the run-in position towards the set position, but to lock the slip in the set position. In embodiments, the retaining mechanism may be configured to prevent dislocation of the slip when set, for example forming a retaining cage around the slip.
Probes with sensors can be positioned within a borehole. Certain types of sensor data is collected by placing the sensor against an inside surface of the borehole or casing. To help reduce the impact of fluid, solids, or other material in the borehole from affecting collected sensor data, a seal is used by the probe to separate the casing or subterranean formation from material in the borehole. The probe can be elliptical, rectangular, or other types of non-circular shapes. In some aspects, the probe can be rotated so the collected sensor data can be collected from different orientations improving the resolution of the data collected. In some aspects, the probe can be rotated until a tool-formation quality threshold is satisfied or until a determined or selected seal quality is achieved. The probe can be rotated by a specified number of degrees of rotation and rotate in one or both directions.
A method to improve performance of a pulsed power drilling tool includes determining energy transferred to a bit of a pulsed power drilling tool. In response to a determination that the energy transferred to the bit is not greater than an energy threshold within a threshold period of time, the method also includes monitoring voltage of a primary capacitor of the pulsed power drilling tool during a subsequent resonance cycle. In response to a determination that the voltage of the primary capacitor is above a voltage threshold, the method further includes toggling a primary switch that is electrically connected to the primary capacitor to maintain energy captured by the primary capacitor, charging the primary capacitor from a stored voltage to an operating voltage during a subsequent cycle.
A pulse generating system includes a primary capacitor positioned along a primary side of a pulse generating circuit, and configured to store electrical energy, and a primary switch positioned along the primary side. The pulse generating system also includes a pulse transformer configured to step up voltage from the primary side to a secondary side of the pulse generating circuit; an output capacitor; and a secondary switch positioned in the secondary side, wherein the output capacitor is electrically coupled to the pulse transformer through the secondary switch.
Disclosed herein is a perforating system including a perforating gun and, more particularly, disclosed are methods and apparatuses using a conical perforating assembly. In one aspect, embodiments relate to a perforating assembly, that includes a charge carrier, a liner disposed in the charge carrier, and an explosive charge disposed between the charge carrier and the liner and supported on the charge carrier, where the liner is supported on the explosive charge, where the perforating assembly has an asymmetric profile.
A method of controlling a pumping sequence of a fracturing fleet at a wellsite. A managing application executing on a computer in the control van can retrieve the pumping sequence from a local or remote storage computer. The managing application can establish an electronic communication link to receive sensor data from a plurality of fracturing units. The managing application can control the plurality of fracturing units with a stage script with multiple sequential instructions for a pumping stage of a pumping sequence while receiving one or more periodic data sets from the plurality of fracturing units wherein the data sets are indicative of the current state of the pumping stage of the pumping sequence.
G05B 19/416 - Numerical control [NC], i.e. automatically operating machines, in particular machine tools, e.g. in a manufacturing environment, so as to execute positioning, movement or co-ordinated operations by means of programme data in numerical form characterised by control of velocity, acceleration or deceleration
E21B 43/16 - Enhanced recovery methods for obtaining hydrocarbons
E21B 43/26 - Methods for stimulating production by forming crevices or fractures
E21B 44/00 - Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systemsSystems specially adapted for monitoring a plurality of drilling variables or conditions
F04B 47/02 - Pumps or pumping installations specially adapted for raising fluids from great depths, e.g. well pumps the driving mechanisms being situated at ground level
A well system and a related method are discussed. The well system, in one aspect, includes a wellbore extending through a subterranean hydrocarbon producing zone, as well as production tubing located in the wellbore, the production tubing including a first inflow control valve configured to regulate a first inflow of hydrocarbons from the subterranean hydrocarbon producing zone into the production tubing. The well system, in accordance with this aspect, further includes a flange coupled to the production tubing and having a fitting positioned proximate a downhole end thereof, and a fiber optic cable installed within the wellbore, an end connector of the fiber optic cable coupled end to end with the fitting of the flange to fix the fiber optic cable relative to the first inflow control valve.
E21B 47/01 - Devices for supporting measuring instruments on drill bits, pipes, rods or wirelinesProtecting measuring instruments in boreholes against heat, shock, pressure or the like
E21B 47/113 - Locating fluid leaks, intrusions or movements using electrical indicationsLocating fluid leaks, intrusions or movements using light radiation
26.
MACHINE LEARNING BASED PORE BODY TO PORE THROAT SIZE TRANSFORMATION FOR COMPLEX RESERVOIRS
G01V 3/32 - Electric or magnetic prospecting or detectingMeasuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for well-logging operating with electron or nuclear magnetic resonance
G01V 3/14 - Electric or magnetic prospecting or detectingMeasuring magnetic field characteristics of the earth, e.g. declination or deviation operating with electron or nuclear magnetic resonance
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
27.
ISOLATION DEVICE WITH MULTIPLE PRESSURE STAGES TO ISOLATE WELL INTERVAL
A well interval isolation device is disclosed. The wellbore isolation device may have a plurality of expandable elements that cooperate upon expansion downhole in a wellbore to create multiple isolated well intervals. At least two pairs of expandable elements that are spaced apart on a tool string are usable to create both a primary isolated well interval and at least one isolated guard interval on each of an uphole side and a downhole side of the primary isolated well interval. The isolated guard intervals function to further isolate the primary isolated well interval from surrounding well fluid, thereby allowing a difference between the pressure within the primary isolated well interval and the hydrostatic pressure of the well fluid (i.e., the differential pressure) to safely exceed the maximum differential pressure at which any of the individual expandable elements can operate while simultaneously maintaining isolation of the well intervals.
Probes with sensors can be positioned within a borehole. Certain types of sensor data is collected by placing the sensor against an inside surface of the borehole or casing. To help reduce the impact of fluid, solids, or other material in the borehole from affecting collected sensor data, a seal is used by the probe to separate the casing or subterranean formation from material in the borehole. The probe can be elliptical, rectangular, or other types of non-circular shapes. In some aspects, the probe can be rotated so the collected sensor data can be collected from different orientations improving the resolution of the data collected. In some aspects, the probe can be rotated until a tool-formation quality threshold is satisfied or until a determined or selected seal quality is achieved. The probe can be rotated by a specified number of degrees of rotation and rotate in one or both directions.
E21B 49/02 - Testing the nature of borehole wallsFormation testingMethods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells by mechanically taking samples of the soil
A pulse generating system includes a primary capacitor positioned along a primary side of a pulse generating circuit, and configured to store electrical energy, and a primary switch positioned along the primary side. The pulse generating system also includes a pulse transformer configured to step up voltage from the primary side to a secondary side of the pulse generating circuit; an output capacitor; and a secondary switch positioned in the secondary side, wherein the output capacitor is electrically coupled to the pulse transformer through the secondary switch.
E21B 7/24 - Drilling using vibrating or oscillating means, e.g. out-of-balance masses
E21B 7/15 - Drilling by use of heat, e.g. flame drilling of electrically generated heat
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 41/00 - Equipment or details not covered by groups
This disclosure relates to toe sleeve embodiments, for example for hydrocarbon wellbore casing, having a closure mechanism with at least two different operations for opening. For example, the closure mechanism may include a degradable element and a non-degradable element. The degradable element may be configured to maintain closure of the toe sleeve during pressure testing, while the non-degradable element may be rated to open at a lower pressure once the degradable element has degraded. This approach may allow effective pressure testing of the casing, while ensuring that the toe sleeve can be opened effectively without risk of damage to the casing. Related systems and method are also disclosed.
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
31.
LARGE LANGUAGE MODEL DRIVEN DESIGN VERIFICATIONS AND REVIEWS
A method for generating a compliance report that includes receiving, by a report generator, a technical plan and a compliance constraint, processing the technical plan and the compliance constraint, generating the compliance report based on the processing, and providing the compliance report to a user.
This disclosure relates to toe sleeve embodiments, for example for hydrocarbon wellbore casing, having a closure mechanism with at least two different operations for opening. For example, the closure mechanism may include a degradable element and a non-degradable element. The degradable element may be configured to maintain closure of the toe sleeve during pressure testing, while the non-degradable element may be rated to open at a lower pressure once the degradable element has degraded. This approach may allow effective pressure testing of the casing, while ensuring that the toe sleeve can be opened effectively without risk of damage to the casing. Related systems and method are also disclosed.
Disclosed herein are an apparatus, a system, and a method for actuating a downhole tool. In one embodiment, a system for use in a wellbore, comprises a downhole tool and an apparatus for activating the downhole tool. The apparatus comprises a metallic plate; an electromagnetic plate; and a spring positioned between the metallic plate and the electromagnetic plate. The apparatus is configured to actuate in response to application of an electrical signal to the electromagnetic plate, wherein actuation of the apparatus activates a downhole component. The downhole tool may be a disappearing plug wherein actuating of the apparatus initiates a flow of fluid to the plug and the plug activates in response to the flow of fluid. In other embodiments the downhole tool may be an autofill sub wherein the fill sub closes in response to actuation of the apparatus.
E21B 33/128 - PackersPlugs with a member expanded radially by axial pressure
E21B 33/1295 - PackersPlugs with mechanical slips for hooking into the casing actuated by fluid pressure
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 method to improve performance of a pulsed power drilling tool includes determining energy transferred to a bit of a pulsed power drilling tool. In response to a determination that the energy transferred to the bit is not greater than an energy threshold within a threshold period of time, the method also includes monitoring voltage of a primary capacitor of the pulsed power drilling tool during a subsequent resonance cycle. In response to a determination that the voltage of the primary capacitor is above a voltage threshold, the method further includes toggling a primary switch that is electrically connected to the primary capacitor to maintain energy captured by the primary capacitor, charging the primary capacitor from a stored voltage to an operating voltage during a subsequent cycle.
E21B 7/24 - Drilling using vibrating or oscillating means, e.g. out-of-balance masses
E21B 7/15 - Drilling by use of heat, e.g. flame drilling of electrically generated heat
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 41/00 - Equipment or details not covered by groups
An exemplary apparatus for use in a tubular string may include piston, a metering device, and a body having a longitudinal bore extending therethrough. When a valve of the apparatus is in an open position, the valve may seal the bore, and when the valve is in a closed position, the valve may allow fluid to flow through the bore. A fluid chamber may be formed between the body and the piston. A pressure activated mechanism may open fluid communication between the fluid chamber and the metering device, in response to pressure in the bore exceeding a threshold, to allow fluid in the fluid chamber to exit through the metering device. The piston may translate from a first position to a second position, as fluid exits the fluid chamber through the metering device, to drive the valve from the closed position to the open position.
E21B 43/10 - Setting of casings, screens or liners in wells
E21B 17/20 - Flexible or articulated drilling pipes
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
37.
Minimizing drivetrain damage from bad discharge valves on positive displacement pumps
A pumping system, comprising: a pump fluid end comprising a plurality of pump chambers, each pump chamber comprising a bore having a reciprocatable plunger disposed therein, a suction valve, and a discharge valve; a prime mover mechanically coupled to the fluid end [by a drivetrain] and configured to reciprocate the plungers; and a controller communicatively coupled to the prime mover, the fluid end, or both and configured to alert a user re a pump malfunction, initiate corrective action of the pump malfunction, or both in response to: (a) an indication of torque reversal during operation of the pumping system, (b) an indication of negative flow rate from the pump during operation of the pumping system, (c) an indication of leakage of (i) a single discharge valve in a 3-plunger pump or (ii) discharge valves associated with two plungers in adjacent firing order, or (d) any combination of (a)-(c).
F04B 51/00 - Testing machines, pumps, or pumping installations
E21B 43/26 - Methods for stimulating production by forming crevices or fractures
E21B 47/008 - Monitoring of down-hole pump systems, e.g. for the detection of "pumped-off" conditions
F04B 15/02 - Pumps adapted to handle specific fluids, e.g. by selection of specific materials for pumps or pump parts the fluids being viscous or non-homogeneous
F04B 17/03 - Pumps characterised by combination with, or adaptation to, specific driving engines or motors driven by electric motors
F04B 17/05 - Pumps characterised by combination with, or adaptation to, specific driving engines or motors driven by internal-combustion engines
F04B 47/02 - Pumps or pumping installations specially adapted for raising fluids from great depths, e.g. well pumps the driving mechanisms being situated at ground level
F04B 49/20 - Control of, or safety measures for, machines, pumps, or pumping installations, not otherwise provided for in, or of interest apart from, groups by changing the driving speed
38.
ELECTRIC CABLE WITH UNDULATED TUBING SEGMENTS FOR SUSPENSION IN A WELL SYSTEM AND METHOD OF ASSEMBLY THEREOF
An electric cable for powering a downhole tool in a wellbore. The electric cable includes a core including one or more electrically conductive wires and one or more electric insulating layers surrounding the conductive wires; a metal inner tube surrounding the core, where the metal inner tubing and the core includes one or more undulated segments with one or more curved outer extensions projecting outwards from a longitudinal axis of the electric cable; and an outer encapsulating tube surrounding the core and metal inner tube, where the outer surface of the metal inner tube has outermost portions at the curved outer extensions of the undulated segments that touch an inner surface of the outer encapsulating tube. A well system including the electric cable and a method of assembling the electric cable are also disclosed.
A method and systems for taking downhole measurements. The method may include selecting a pulsing scheme for taking one or more measurements using a pulsed neutron logging tool, selecting a neutron burst width for the pulsing scheme based at least in part on a neutron tube utilized by the pulsed neutron logging tool to form at least in part a neutron burst train, and selecting a decay window in which the one or more measurements are performed by the pulsed neutron logging tool. The method may further include selecting a starting time for a late gate in which the one or measurements are taken, disposing the pulsed neutron logging tool into a borehole, performing the neutron burst train with the pulsed neutron logging tool, and performing the one or more measurements with the pulsed neutron logging tool during the late gate.
G01V 5/10 - Prospecting or detecting by the use of ionising radiation, e.g. of natural or induced radioactivity specially adapted for well-logging using primary nuclear radiation sources or X-rays using neutron sources
40.
Universal Neutron Pulsing Scheme For Logging Operations
A method and system for creating a pulsing scheme. The method may include selecting a pulsing scheme for downhole measurements using a pulsed neutron logging tool and selecting a neutron burst width for the pulsing scheme based at least in part on a neutron tube utilized by the pulsed neutron logging tool during the downhole measurements. The method may further include selecting a carbon-oxygen ratio (CO) neutron burst train for the pulsing scheme to be utilized by the neutron tube, selecting a Sigma decay time for the pulsing scheme, and performing one or more measurements with the pulsed neutron logging tool using the pulsing scheme. The system may include a pulsed neutron logging tool. The pulsed neutron logging tool may include a neutron tube disposed in a pulsed neutron generator, one or more gamma ray scintillator detectors, and one or more thermal neutron detectors.
G01V 5/10 - Prospecting or detecting by the use of ionising radiation, e.g. of natural or induced radioactivity specially adapted for well-logging using primary nuclear radiation sources or X-rays using neutron sources
E21B 44/00 - Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systemsSystems specially adapted for monitoring a plurality of drilling variables or conditions
Provided is a downhole tool, a well system, and a method for forming a well system. The downhole tool, in at least one aspect, includes a two part drilling and running tool, the two part drilling and running tool including 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 downhole tool, in accordance with this aspect, further includes a whipstock assembly coupled to the two part drilling and running tool using a coupling mechanism, and a hydraulically actuated anchoring assembly coupled to a downhole end of the whipstock assembly.
E21B 10/32 - Drill bits with leading portion, i.e. drill bits with a pilot cutterDrill bits for enlarging the borehole, e.g. reamers with expansible cutting tools
E21B 10/44 - Bits with helical conveying portion, e.g. screw type bitsAugers with leading portion or with detachable parts
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
42.
RETROFITTING EXISTING RIG HARDWARE AND PERFORMING BIT FORENSIC FOR DULL BIT GRADING THROUGH SOFTWARE
The disclosure provides an automated process for determining the wear condition of a downhole tool that removes the subjectivity associated with manual observation. The automated process can advantageously evaluate a wear condition of a downhole tool using visual analytics and real-time analysis after the downhole tool has been extracted from the wellbore. An example of a method includes: (1) securing a downhole tool in a rig assembly. (2) obtaining, using sensors, surround tool data of the downhole tool in the rig assembly, wherein the surround tool data includes a first set of surround tool data obtained before a downhole operation by the downhole tool and a second set of surround tool data obtained after the downhole operation, and (3) automatically determining a wear condition of the downhole tool in real time by comparing the second set of surround tool data to the first set of surround tool data.
A perforating gun system for tubing conveyed perforation is provided. The perforating gun system includes a gun carrier, at least one free rotation device, a charge tube suspended on the at least one free rotation device, a stationary emitter coupled to the charge tube, and a sensor coupled to an interior surface of the gun carrier. The sensor can be configured to intermittently align with the stationary emitter when the charge tube is orienting independently of the rotation of the gun carrier.
L1SL2L2). In one aspect, a fluid chamber is defined between the first pressure output end and the second pressure receiving end. In one aspect, the pressure intensifier is configured to move the sliding element with an applied force.
E21B 33/1295 - PackersPlugs with mechanical slips for hooking into the casing actuated by fluid pressure
E21B 33/128 - PackersPlugs with a member expanded radially by axial pressure
E21B 23/06 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for setting packers
E21B 34/10 - Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole
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
45.
ELECTRIC CABLE WITH UNDULATED TUBING SEGMENTS FOR SUSPENSION IN A WELL SYSTEM AND METHOD OF ASSEMBLY THEREOF
An electric cable for powering a downhole tool in a wellbore. The electric cable includes a core including one or more electrically conductive wires and one or more electric insulating layers surrounding the conductive wires; a metal inner tube surrounding the core, where the metal inner tubing and the core includes one or more undulated segments with one or more curved outer extensions projecting outwards from a longitudinal axis of the electric cable; and an outer encapsulating tube surrounding the core and metal inner tube, where the outer surface of the metal inner tube has outermost portions at the curved outer extensions of the undulated segments that touch an inner surface of the outer encapsulating tube. A well system including the electric cable and a method of assembling the electric cable are also disclosed.
Disclosed herein are systems and methods to obtain representative formation pore pressure and formation mobility from pressure measurements with a formation testing tool. One of the methods for performing a pressure test includes measuring the pressure in the fluid passageway by a pressure sensor, performing a pre-test with the pressure sensor, measuring the drawdown pressure, measuring the buildup pressure, performing another pre-test when the drawdown pressure is superior to the buildup pressure, and validating a formation flow when the drawdown pressure is equal to the buildup pressure, wherein a measured pressure obtained at an asymptote of a pressure curve after the buildup pressure corresponds to the formation pore pressure.
Various well-perforating systems and methods are disclosed incorporating a self-shunting detonator. The detonator may include an electrically-conductive detonator body. A resistor initiator inside the detonator body includes first and second leads. A grounding element inside the detonator body couples the detonator body to the first lead. An electrically-conductive clip coupled to the second lead includes an arm biased to electrical contact with an external surface of the detonator body to shunt the detonator. The arm is moveable away from the detonator body to un-shunt the detonator, such as automatically in response to insertion into a detonator housing.
F42C 15/34 - Arming-means in fuzesSafety means for preventing premature detonation of fuzes or charges wherein the safety or arming action is effected by a blocking-member in the pyrotechnic or explosive train between primer and main charge
A method for generating a compliance report that includes receiving, by a report generator, a technical plan and a compliance constraint, processing the technical plan and the compliance constraint, generating the compliance report based on the processing, and providing the compliance report to a user.
G06F 30/27 - Design optimisation, verification or simulation using machine learning, e.g. artificial intelligence, neural networks, support vector machines [SVM] or training a model
49.
MACHINE LEARNING BASED PORE BODY TO PORE THROAT SIZE TRANSFORMATION FOR COMPLEX RESERVOIRS
A computer-implemented method is provided. The computer-implemented method can include receiving one or more input NMR measurements at a first neural network; transforming the one or more input NMR measurements to a predicted pore throat size distribution or one or more predicted pore throat size parameters; receiving the predicted pore throat size distribution or the one or more predicted pore throat size parameters at a second neural network; transforming the predicted pore throat size distribution or the one or more predicted pore throat size parameters to a predicted NMR T2 distribution or one or more predicted NMR T2 parameters; and applying one or more physics based equations to the predicted NMR T2 distribution or the one or more predicted NMR T2 parameters to forward model the predicted NMR T2 distribution or the one or more predicted NMR T2 parameters to one or more simulated NMR measurements.
G01V 3/38 - Processing data, e.g. for analysis, for interpretation or for correction
E21B 44/00 - Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systemsSystems specially adapted for monitoring a plurality of drilling variables or conditions
G01V 3/32 - Electric or magnetic prospecting or detectingMeasuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for well-logging operating with electron or nuclear magnetic resonance
A downhole tractor drive module is provided. The downhole tractor drive module includes a first bevel gearbox, a first drive arm coupled to the first bevel gearbox, a connecting shaft, a second bevel gearbox, and a second drive arm coupled to the second bevel gearbox. The first bevel gearbox can include an input shaft in communication with the motor, a first output shaft, and a second output shaft coupled to a connecting shaft input connection. The second bevel gearbox can have an input shaft coupled to a connecting shaft output connection and a first output shaft.
E21B 23/00 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells
E21B 23/14 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for displacing a cable or a cable-operated tool, e.g. for logging or perforating operations in deviated wells
51.
BOREHOLE RESONANCE MODE FOR CEMENT EVALUATION USING MACHINE LEARNING
Systems and methods are provided for evaluation of the cement bonding condition in a wellbore based on borehole resonance mode using machine learning. An example method can include transforming the return signal into a resonance signal based on feature extraction of the return signal, determining a segment of the resonance signal in a time domain, and determining, via a machine learning model, a predicted borehole cement bonding based on the segment of the resonance signal. The example method can further include generating a bonding log based on the predicted borehole cement bonding.
G01V 1/40 - SeismologySeismic 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
E21B 47/005 - Monitoring or checking of cementation quality or level
A method and systems for taking downhole measurements. The method may include selecting a pulsing scheme for taking one or more measurements using a pulsed neutron logging tool,selecting a neutron burst width for the pulsing scheme based at least in part on a neutron tube utilized by the pulsed neutron logging tool to form at least in part a neutron burst train, and selecting a decay window in which the one or more measurements are performed by the pulsed neutron logging tool. The method may further include selecting a starting time for a late gate in which the one or measurements are taken, disposing the pulsed neutron logging tool into a borehole, performing the neutron burst train with the pulsed neutron logging tool, and performing the one or more measurements with the pulsed neutron logging tool during the late gate.
G01V 5/10 - Prospecting or detecting by the use of ionising radiation, e.g. of natural or induced radioactivity specially adapted for well-logging using primary nuclear radiation sources or X-rays using neutron sources
G01V 5/12 - Prospecting or detecting by the use of ionising radiation, e.g. of natural or induced radioactivity specially adapted for well-logging using primary nuclear radiation sources or X-rays using gamma- or X-ray sources
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
In general, in one aspect, embodiments relate to a method, that includes lowering a tool string down into a wellbore extending into a subterranean formation, where the tool string includes perforating charges, and one or more acoustic emitters, energizing the one or more acoustic emitters to form at least an acoustic signal while the tool string is being drawn up-hole, detecting the acoustic signal with a sensing cable disposed within the wellbore, determining an angular orientation of the tool string relative to the sensing cable based at least in part on the acoustic signal, and detonating at least one of the perforating charges when its firing direction is not directed at the one or more sensing cables.
A method and system for creating a pulsing scheme. The method may include selecting a pulsing scheme for downhole measurements using a pulsed neutron logging tool and selecting a neutron burst width for the pulsing scheme based at least in part on a neutron tube utilized by the pulsed neutron logging tool during the downhole measurements. The method may further include selecting a carbon-oxygen ratio (CO) neutron burst train for the pulsing scheme to be utilized by the neutron tube, selecting a Sigma decay time for the pulsing scheme, and performing one or more measurements with the pulsed neutron logging tool using the pulsing scheme. The system may include a pulsed neutron logging tool. The pulsed neutron logging tool may include a neutron tube disposed in a pulsed neutron generator, one or more gamma ray scintillator detectors, and one or more thermal neutron detectors.
G01V 5/10 - Prospecting or detecting by the use of ionising radiation, e.g. of natural or induced radioactivity specially adapted for well-logging using primary nuclear radiation sources or X-rays using neutron sources
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
55.
Use Of Bending Moment On Bit Measurements And Simulations To Determine Health Condition Of Push-The-Bit Rotary Steerable Systems And Assess Directional Drilling Capability
A method and system for measuring health in a rotary steerable system (RSS). The method may include forming a bottom-hole assembly (BHA) model, taking a bending moment on bit (BOB) measurement from a sensor disposed in a BHA, and comparing the BOB measurement to the BHA model to determine if a steering actuator is malfunctioning, wherein the steering actuator is disposed on the BHA. The system may include at least one sensor disposed on the BHA, wherein the at least one sensor takes at least one bending moment on bit (BOB) measurement. Further, the system may include a plurality of steering actuators disposed on the BHA and an information handling system in communication with the BHA.
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
56.
SEALING ELEMENT HAVING A POLYMER BLEND FOR SUBSURFACE CARBON SEQUESTRATION
An apparatus comprises a sealing element for a carbon sequestration in a location that is within a subsurface formation, wherein the sealing element is composed of a non-polar elastomer blended and co-cured with a low temperature elastomer having a glass transition temperature that is lower than a glass transition temperature of the non-polar elastomer.
C09K 8/44 - Compositions for cementing, e.g. for cementing casings into boreholesCompositions for plugging, e.g. for killing wells containing organic binders only
E21B 41/00 - Equipment or details not covered by groups
A method and a system comprising: disposing a bottom hole assembly (BHA) into a wellbore, wherein the BHA comprises a measurement assembly; acquiring one or more measurements with the measurement assembly; acquiring historical data from the wellbore; extracting relevant information from the historical data; training a machine learning (ML) model with the relevant information to form a trained ML model; and providing an answer to a question utilizing the trained ML model.
E21B 47/024 - Determining slope or direction of devices in the borehole
E21B 49/00 - Testing the nature of borehole wallsFormation testingMethods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
58.
SYSTEMS AND METHODS FOR REAL TIME OIL TOOL ORIENTATION DETECTION
A perforating gun system for tubing conveyed perforation is provided. The perforating gun system includes a gun carrier, at least one free rotation device, a charge tube suspended on the at least one free rotation device, a stationary emitter coupled to the charge tube, and a sensor coupled to an interior surface of the gun carrier. The sensor can be configured to intermittently align with the stationary emitter when the charge tube is orienting independently of the rotation of the gun carrier.
E21B 43/119 - Details, e.g. for locating perforating place or direction
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
59.
BOREHOLE RESONANCE MODE FOR CEMENT EVALUATION USING MACHINE LEARNING
Systems and methods are provided for evaluation of the cement bonding condition in a wellbore based on borehole resonance mode using machine learning. An example method can include transforming the return signal into a resonance signal based on feature extraction of the return signal, determining a segment of the resonance signal in a time domain, and determining, via a machine learning model, a predicted borehole cement bonding based on the segment of the resonance signal. The example method can further include generating a bonding log based on the predicted borehole cement bonding.
Provided is a downhole tool, a well system, and a method. The downhole tool, in one aspect, includes a mandrel, a sliding element positioned radially about the mandrel, and a pressure intensifier positioned radially about the mandrel and coupled to the sliding element. In one aspect, the pressure intensifier includes a first piston having a first pressure receiving end with a larger piston surface area (AL1) and a first pressure output end with a smaller piston surface area (AS). In one aspect, the pressure intensifier includes a second piston coupled to the first piston, the second piston having a second pressure receiving end with a larger piston surface area (AL2). In one aspect, a fluid chamber is defined between the first pressure output end and the second pressure receiving end. In one aspect, the pressure intensifier is configured to move the sliding element with an applied force.
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 34/08 - Valve arrangements for boreholes or wells in wells responsive to flow or pressure of the fluid obtained
61.
AUTOMATICALLY DETECTING A KEY PARAMETER AFFECTING PUMP COMPONENTS
The life of internal components of a frack pump is affected by the frack fluid being pumped. The disclosure evaluates pump components and identifies parameters of frack pumps that may affect the remaining life of pump components based on pump models generated using flow type histories of the frack pumps. Pump related factors can also be used to identify the pump parameters. In one example, a method of evaluating pump components of a frack pump includes: (1) comparing a flow type history of the frack pump to at least one pump model, wherein the flow type history is automatically determined and is based on a proppant concentration of frack fluid pumped by the frack pump, (2) evaluating a condition of at least one component of the pump based on the comparing, and (3) changing a parameter of the pump based on the evaluating.
Disclosed herein are systems and methods to obtain representative formation pore pressure and formation mobility from pressure measurements with a formation testing tool. One of the methods for performing a pressure test includes measuring the pressure in the fluid passageway by a pressure sensor, performing a pre-test with the pressure sensor, measuring the drawdown pressure, measuring the buildup pressure, performing another pre-test when the drawdown pressure is superior to the buildup pressure, and validating a formation flow when the drawdown pressure is equal to the buildup pressure, wherein a measured pressure obtained at an asymptote of a pressure curve after the buildup pressure corresponds to the formation pore pressure.
Some implementations include a system configured for real-time well path optimization of a wellbore being drilled into a subsurface formation, the system comprising: a downhole tool including a resistivity sensor; a drilling assembly coupled to a drill bit, the drilling assembly including the downhole tool; and a learning machine configured to, compare an input image of a resistivity inversion against an archive of historical data; generate, based on the comparison, a real-time well path suggestion; and output the real-time well path suggestion to a user interface.
E21B 47/002 - Survey of boreholes or wells by visual inspection
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
The present disclosure provides a composition for improving the bonding of an elastomer to a metal surface for use in wellbore operations, the composition comprising polymers, including phenolic and acrylic based polymers, one or more fillers, one or more additives, one ore more curative agents, and an epoxide promotor. The method can include single or multilayer addition to a metal surface to promote the bonding of the thermoset rubber elastomer to the metal surface. The resultant bonding can provide a good sealing performance, including at moderate or low temperature to high temperature, and exhibit good chemical compatibility and resistance when exposed to common wellbore environments.
An anomaly in a cement layer of a wellbore can be identified by applying dimensionality reduction to acoustic data of the wellbore. For example, a computing system can receive the acoustic data from a downhole tool deployed downhole in the wellbore using a tool string positioned within a casing string of the wellbore. The computing system can decrease a number of dimensions associated with the acoustic data to generate a dimension-reduced dataset including a predetermined dimensionality. Subsequently, the computing system can analyze the dimension-reduced dataset to determine a likelihood of the anomaly being present in the cement layer of the wellbore. The computing system can output, via a user interface, a cement map based on the dimension-reduced dataset. The cement map can indicate a presence of the anomaly in the cement layer of the wellbore for use in adjusting a wellbore operation.
A downhole fluid sampling system with hydraulic actuation can be used to collect one or more samples of formation fluid during a well operation. The sampling system can be within a downhole tool deployed in a wellbore of the well operation. Then sampling system then can collect a first sample from the flow of formation fluid from the wellbore using a first sampling chamber of a sampling unit in the sampling system. The sampling unit can define a set of sampling chambers including the first sampling chamber and a second sampling chamber. A piston of the sampling system that actuates on hydraulic fluid can advance the sampling unit by a predefined distance from a first position associated with the first sampling chamber to a second position associated with the second sampling chamber. Subsequently, the second sampling chamber can collect a second sample from the flow of formation fluid.
Systems, methods, and apparatus, including computer programs encoded on computer-readable media, for detecting downhole measured depth of a borehole are disclosed. A downhole imaging tool of a drilling system may obtain azimuthal borehole images from at least a first sensor and a second sensor of the downhole imaging tool. Image cross-correlation is performed on the azimuthal borehole images. A time delay is determined based on the image cross-correlation on the azimuthal borehole images. A velocity of the downhole imaging tool is determined based on the time delay. A downhole measured depth of the downhole imaging tool within the borehole is determined based on the velocity. The downhole measured depth may be determined dynamically downhole by the downhole imaging tool without communications with surface equipment of the drilling system.
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
68.
FLUID SAMPLING TOOL AND SAMPLE CHAMBER FOR CHEMICALLY ACTIVE COMPONENT MEASUREMENT
A fluid sampling tool is locatable in a borehole for sampling formation fluid including a chemically active component from a formation. The fluid sampling tool includes a sample chamber including a fluid inlet and an interior, wherein the interior includes a substrate and a reagent attached to the substrate, and wherein the reagent is configured to react with the chemically active component of the formation fluid to form a reaction product. The fluid sampling tool also includes a pump operable to pump a sample of the formation fluid in from the formation through the probe and into the sample chamber. A formation fluid sample flows into the sample chamber and a chemically active component of the formation fluid sample reacts with the reagent to form the reaction product from which a presence and concentration of the chemically active component in the formation fluid sample is determinable.
E21B 49/08 - Obtaining fluid samples or testing fluids, in boreholes or wells
E21B 49/10 - Obtaining fluid samples or testing fluids, in boreholes or wells using side-wall fluid samplers or testers
E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
G01V 1/40 - SeismologySeismic or acoustic prospecting or detecting specially adapted for well-logging
G01V 3/18 - Electric or magnetic prospecting or detectingMeasuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for well-logging
69.
DETERMINISTIC ANALYSIS OF CONTAMINATION INFORMATION FLUID
Systems and methods for determining a level of contamination of a formation fluid by a drilling fluid are disclosed. The method includes defining a first curve of a range of values for a plurality of properties of the formation fluid in a multidimensional space, wherein each dimension is associated with one of the plurality of properties, defining a first point of the values of the plurality of properties for the drilling fluid in the multidimensional space, accessing measurements of the plurality of properties for a plurality of samples of a fluid being pumped out of a wellbore, defining a plurality of second points of the respective measured properties in the multidimensional space, and defining a vector from the first point through the plurality of second points to the first curve.
Systems and methods are provided for determining fabrics of a geological sample using three-dimensional segmentation. An example method can include receiving three-dimensional (3D) image of a geological sample, adjusting an initial size of the 3D image of the geological sample, and partitioning the resized 3D image of the geological sample into cubes. The example method can include, for each cube, generating orthogonal planes based on a center of mass of each cube and extracting, for the orthogonal planes associated with each cube, one or more features to represent texture of the geological sample. The example method can further include grouping the cubes into one or more clusters based on the one or more features and constructing a volume of the resized 3D image of the geological sample based on the one or more clusters for a texture analysis of the geological sample.
G01V 3/30 - Electric or magnetic prospecting or detectingMeasuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for well-logging operating with electromagnetic waves
E21B 47/002 - Survey of boreholes or wells by visual inspection
A high-voltage and high-current pulse switching system is disclosed. The pulse switching system includes one or more pulse switching modules. Each pulse switching module includes a baseplate, an electrically non-conductive substrate, and a thermally conductive material applied between the baseplate and the substrate. The pulse switching module also includes semiconductor devices having wide band gap properties arranged in series with respect to one another on the substrate. The pulse switching module also includes an encapsulant material deposited over the semiconductor devices and the substrate.
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
H03K 17/081 - Modifications for protecting switching circuit against overcurrent or overvoltage without feedback from the output circuit to the control circuit
H03K 17/14 - Modifications for compensating variations of physical values, e.g. of temperature
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
72.
SELECTIVE SLEEVE FOR USE WITH INFLOW CONTROL DEVICES
Apparatus and method for controlling flow back through a conduit. The apparatus includes a selective sleeve disposed within the conduit, a bottom sleeve coupled to the selective sleeve, the conduit comprising a check valve, and an inflow control device fluidically coupled to the conduit. A shearable element locks the bottom sleeve to the conduit. The check valve is covered by the selective sleeve when the apparatus is introduced into a wellbore. The selective sleeve shifts to close the check valve and open the inflow control device. The selective sleeve also shifts to close the check valve and the inflow control device.
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 34/08 - Valve arrangements for boreholes or wells in wells responsive to flow or pressure of the fluid obtained
E21B 23/06 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for setting packers
E21B 34/10 - Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole
A downhole sleeve includes a cylindrical housing having a hollow interior, the cylindrical housing configured to slide around a component. The downhole sleeve also includes a plurality of protrusions positioned around the cylindrical housing, each protrusion configured to: receive a radially-inward force applied to an exterior surface of the respective protrusion; and transfer the radially-inward force through an interior surface of the respective protrusion to hold the component in position.
A liquid additive composition comprising (i) a biopolymer gum and (ii) a latex, wherein a ratio of biopolymer gum to latex ranges from about 1:50 to about 1:500. A method of preparing a liquid additive composition comprising contacting a biopolymer gum and a latex to form a mixture wherein a ratio of biopolymer gum to latex ranges from about 1:60 to about 1:500. A method of servicing a wellbore penetrating a subterranean formation comprising placing a treatment fluid comprising (i) a biopolymer gum and (ii) a latex into the wellbore and/or the subterranean formation, wherein a ratio of biopolymer gum to latex ranges from about 1:50 to about 1:500.
A wellbore servicing fluid comprising (a) a fluid loss additive comprising (i) a biopolymer gum and (ii) a latex; and (b) a base fluid wherein a fluid loss in the wellbore servicing fluid is reduced by from about 50% to about 80% when compared to the fluid loss in the absence of the biopolymer gum. A method of preparing a wellbore servicing fluid comprising contacting a base fluid and a liquid fluid loss additive comprising a biopolymer gum and a latex, wherein a fluid loss in the wellbore servicing fluid is reduced by from about 50% to about 80% when compared to the fluid loss in the absence of the biopolymer gum. A method of servicing a wellbore penetrating a subterranean formation comprising placing a wellbore servicing fluid comprising (a) a fluid loss additive comprising (i) a biopolymer gum and (ii) a latex; and (b) a base fluid into a wellbore; and wherein a fluid loss in the wellbore servicing fluid is reduced by from about 50% to about 80%when compared to the fluid loss in the absence of the biopolymer gum. A method comprising contacting a base fluid, a cement, and a liquid fluid loss additive to form a pumpable cementitious slurry; wherein the liquid fluid loss additive comprises a biopolymer gum and a latex and wherein a fluid loss in the wellbore servicing fluid is reduced by from about 50% to about 80% when compared to the fluid loss in the absence of the biopolymer gum.
C09K 8/08 - Clay-free compositions containing natural organic compounds, e.g. polysaccharides, or derivatives thereof
C09K 8/12 - Clay-free compositions containing synthetic organic macromolecular compounds or their precursors
C09K 8/487 - Fluid loss control additivesAdditives for reducing or preventing circulation loss
E21B 33/13 - Methods or devices for cementing, for plugging holes, crevices or the like
76.
USE OF BENDING MOMENT ON BIT MEASUREMENTS AND SIMULATIONS TO DETERMINE HEALTH CONDITION OF PUSH-THE-BIT ROTARY STEERABLE SYSTEMS AND ASSESS DIRECTIONAL DRILLING CAPABILITY
A method and system for measuring health in a rotary steerable system (RSS). The method may include forming a bottom-hole assembly (BHA) model, taking a bending moment on bit (BOB) measurement from a sensor disposed in a BHA, and comparing the BOB measurement to the BHA model to determine if a steering actuator is malfunctioning, wherein the steering actuator is disposed on the BHA. The system may include at least one sensor disposed on the BHA, wherein the at least one sensor takes at least one bending moment on bit (BOB) measurement. Further, the system may include a plurality of steering actuators disposed on the BHA and an information handling system in communication with the BHA.
E21B 47/01 - Devices for supporting measuring instruments on drill bits, pipes, rods or wirelinesProtecting measuring instruments in boreholes against heat, shock, pressure or the like
Disclosed herein are methods and system for determining an elemental composition of a downhole formation using neutron-induced gamma ray spectroscopy and doping the borehole fluid with a neutron absorber to remove at least part of the borehole thermal neutron flux before it can capture borehole nuclei and emit gamma rays within a spectral range of interest. For example, a method for determining the elemental composition includes adding a dopant to a borehole fluid, wherein the dopant absorbs thermal neutrons in the borehole, lowering a logging tool comprising a gamma ray spectrometer, emitting neutrons into a downhole environment, generating neutron-induced gamma rays comprising borehole gamma rays and formation gamma rays, detecting gamma rays from the downhole formation, and extracting the elemental composition of the downhole formation. The dopant may not emit gamma rays above 0.5 MeV or their peaks background should be predictable and/or consistent to be removed during data processing.
G01V 5/10 - Prospecting or detecting by the use of ionising radiation, e.g. of natural or induced radioactivity specially adapted for well-logging using primary nuclear radiation sources or X-rays using neutron sources
G01V 5/12 - Prospecting or detecting by the use of ionising radiation, e.g. of natural or induced radioactivity specially adapted for well-logging using primary nuclear radiation sources or X-rays using gamma- or X-ray sources
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
Systems and methods are provided for performing directional drilling. An example method can include receiving, by a surface controller, a well plan for performing directional drilling of a wellbore; receiving, by the surface controller, an estimate for at least one drilling parameter that is based on a model of a bottom hole assembly (BHA) configured to perform directional drilling of the wellbore; and determining, by the surface controller, a steering force and a weight-on-bit (WOB) for drilling the wellbore, wherein the steering force and the WOB are based on the well plan and the estimate for the at least one drilling parameter.
A system and method for taking measurements in a formation. The system may include a quantum entangled photon source that entangles an idler particle and a probe particle, a transmitter disposed in a wellbore and connected to the quantum entangled photon source by a transmitter waveguide, a receiver disposed in the wellbore, and a carrier laser connected to the receiver by a carrier waveguide. The system may further comprise a detector connected to the carrier waveguide and an information handling system in communication with the quantum entangled photon source, the carrier laser, and the detector. The method may include broadcasting a probe particle from a transmitter into a formation, capturing the probe particle with at least one receiver after the probe particle has interacted with the formation, and measuring the probe particle during an interaction with the formation using an idler particle in a detector.
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 49/08 - Obtaining fluid samples or testing fluids, in boreholes or wells
G01V 9/00 - Prospecting or detecting by methods not provided for in groups
Systems and methods for downhole drilling and, more particularly, hydraulic control systems and methods for hydraulically locking and unlocking moveable elements of a drill bit are provided. A drill bit may include a body; a moveable element secured to the body, wherein the moveable element is configured to extend or retract from a surface of the drill bit; a communication channel from the moveable element to a bore in the body; and a hydraulic control system at least partially disposed in the body, wherein the hydraulic control system is configured to at least provide fluid communication from the bore to the communication channel to thereby lock or unlock the moveable element.
E21B 10/43 - Rotary drag type drill bits with teeth, blades or like cutting elements, e.g. fork-type bits, fish tail bits characterised by the arrangement of teeth or other cutting elements
E21B 44/00 - Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systemsSystems specially adapted for monitoring a plurality of drilling variables or conditions
81.
Neutron Absorbing Dopant For Reducing Borehole Fluid Background In Geochemical Logging
Disclosed herein are methods and system for determining an elemental composition of a downhole formation using neutron-induced gamma ray spectroscopy and doping the borehole fluid with a neutron absorber to remove at least part of the borehole thermal neutron flux before it can capture borehole nuclei and emit gamma rays within a spectral range of interest. For example, a method for determining the elemental composition includes adding a dopant to a borehole fluid, wherein the dopant absorbs thermal neutrons in the borehole, lowering a logging tool comprising a gamma ray spectrometer, emitting neutrons into a downhole environment, generating neutron-induced gamma rays comprising borehole gamma rays and formation gamma rays, detecting gamma rays from the downhole formation, and extracting the elemental composition of the downhole formation. The dopant may not emit gamma rays above 0.5 MeV or their peaks background should be predictable and/or consistent to be removed during data processing.
G01V 5/10 - Prospecting or detecting by the use of ionising radiation, e.g. of natural or induced radioactivity specially adapted for well-logging using primary nuclear radiation sources or X-rays using neutron sources
G01V 5/14 - Prospecting or detecting by the use of ionising radiation, e.g. of natural or induced radioactivity specially adapted for well-logging using primary nuclear radiation sources or X-rays using a combination of several sources, e.g. a neutron and a gamma source
82.
SYSTEMS AND METHODS FOR CHARACTERIZING A SUBTERRANEAN FORMATION HAVING A FORMATION BOUNDARY SURFACE
Systems and methods for characterizing a subterranean formation that include a drill bit for drilling a deviated wellbore through the formation and that repeatedly changes direction. Also included is a directional drilling system and measurement equipment to detect a property of the formation. A trajectory control system is operable to: receive a well log; determine a property of the wellbore; segment the well log based on the property; and correlate one of the segments with the well log previous to the segment to determine a matching score for the segment. If the matching score is equal to or greater than a minimum threshold, the segment was taken in the formation and at the same stratigraphical true vertical depth ("STVD"). If the matching score is less than the minimum threshold, the segment was not taken in the formation and not at the same STVD and the STVD is estimated.
E21B 44/00 - Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systemsSystems specially adapted for monitoring a plurality of drilling variables or conditions
E21B 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 49/00 - Testing the nature of borehole wallsFormation testingMethods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
83.
EXPANDABLE ELEMENT ASSEMBLY WITH EXTERNAL RIGID SUPPORT ELEMENT TO ISOLATE WELL INTERVAL
An expandable element isolation assembly and a well interval isolation device utilizing at least a pair of expandable element isolation assemblies to isolate a well interval are disclosed. An expandable element isolation assembly can comprise an expandable element, and at least one rigid support element that is located external to the expandable element and is positionable between at least part of the expandable element and an inner wall of a formation at an open-hole portion of a wellbore in response to expansion of the expandable element. The at least one rigid support element can reinforce the expanded expandable element, such as through physical contact therewith. A retraction mechanism may be provided to retract the at least one rigid support element upon contraction of the expandable element.
A method of cooling at least a portion of a downhole tool located within a drilled wellbore using a fluid pill configured to transfer heat away from a heat-generating segment of the downhole tool. The downhole tool may be a wireline logging tool. The fluid pill can comprise at least one fluid coolant and may include other additives such that the heat transfer properties of the fluid pill are superior to those of one or more fluids present in the drilled wellbore. The fluid pill can be introduced into residual drilling mud in the wellbore, and the downhole tool may thereafter be operated with the heat-generating segment thereof in fluid contact with the fluid pill, whereby heat generated by the heat-generating segment is transferred away from the downhole tool and toward a wall of the wellbore by the fluid pill.
Systems, methods, and apparatus including a downhole membrane potentiometer that may be used in well systems. The downhole membrane potentiometer may include a first circuit film having a resistance trace, a second circuit film having a collector trace, and an insulator spacer coupled between the first circuit film and the second circuit film. The insulator spacer may include one or more pressure vent holes in a first side of the insulator spacer and one or more pressure vent holes in a second side of the insulator spacer to minimize a differential pressure between the inside and outside of the downhole membrane potentiometer.
G01V 3/18 - Electric or magnetic prospecting or detectingMeasuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for well-logging
E21B 21/08 - Controlling or monitoring pressure or flow of drilling fluid, e.g. automatic filling of boreholes, automatic control of bottom pressure
Systems and methods for drilling a first borehole along a planned first path using a first bottom hole assembly (BHA) while drilling a second borehole using a second BHA along a second path having a defined spatial relationship to the first path. The method includes steps of measuring a distance and a direction of the first BHA relative to the second BHA, automatically adjusting the second path based in part on the measured distance and the measured direction so as to maintain the spatial relationship, and automatically steering the second BHA to follow the adjusted second path.
E21B 44/00 - Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systemsSystems specially adapted for monitoring a plurality of drilling variables or conditions
Described herein are systems and techniques for improving the transmission of data up a wellbore such that wellbore operations may be performed or controlled more efficiently. When a wellbore is drilled or otherwise used, sensors may be deployed in the wellbore to measure parameters that may include borehole pressure, annular pressure, weight-on-bit, torque-on-bit, temperature, or other borehole logging data, for example. Data sensed by the sensors or interpreted from received sensor data may be sent up-hole to electronics that may reside at the surface of the Earth. Since wellbore (borehole) logging data usually have moderate levels of continuity or consistency between respective samples, differences between data samples acquired over a period of time may be expected to have smaller amplitudes/deviations than the data samples themselves. As such, data compression can be achieved by transmitting data that identifies a difference between an initial data sample and a subsequent reference data sample.
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
An apparatus comprises a sealing element for a carbon sequestration in a location that is within a subsurface formation, wherein the sealing element is composed of a non-polar elastomer blended and co-cured with a low temperature elastomer having a glass transition temperature that is lower than a glass transition temperature of the non-polar elastomer.
A modular antenna sleeve assembly includes an antenna and an antenna sleeve having a wiring hole to receive wiring of the antenna. The modular antenna sleeve assembly also includes a protection sleeve disposed around the antenna sleeve and configured to shield the antenna. The modular antenna sleeve assembly further includes a locking sleeve disposed around the antenna sleeve and configured to hold the protection sleeve in position while the locking sleeve is in a locked position.
H01Q 1/04 - Adaptation for subterranean or subaqueous use
E21B 47/107 - Locating fluid leaks, intrusions or movements using acoustic means
G01V 3/30 - Electric or magnetic prospecting or detectingMeasuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for well-logging operating with electromagnetic waves
90.
METHODS TO PERFORM JOINT INVERSION OF FORMATION DATA AND JOINT INVERSION SYSTEMS
A computer-implemented method to perform joint inversion of formation data includes performing a first inversion of a formation surrounding a wellbore at a first frequency/spacing configuration, and performing a second inversion of the formation at a second frequency/spacing configuration that is different from the first configuration. The method also includes assigning a first fluctuating weight to the first inversion, and assigning a second fluctuating weight to the second inversion. The method further includes merging the first and second inversion based on a combination of the first and second fluctuating weights.
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 44/00 - Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systemsSystems specially adapted for monitoring a plurality of drilling variables or conditions
A fluid filter that includes a thermoelectric cooler with a cold side and a hot side, an impingement enclosure, disposed against the cold side that includes an inlet adapted to direct a fluid to flow towards the cold side at a first perpendicular angle, and an outlet adapted to direct the fluid to flow away the cold side at a second perpendicular angle, an outlet temperature sensor disposed at the outlet, and a controller operatively connected to the thermoelectric cooler, where the controller is configured to send a command to the thermoelectric cooler to change the power state of the thermoelectric cooler.
A method and a system comprising: disposing a bottom hole assembly (BHA) into a wellbore, wherein the BHA comprises a measurement assembly; acquiring one or more measurements with the measurement assembly; acquiring historical data from the wellbore; extracting relevant information from the historical data; training a machine learning (ML) model with the relevant information to form a trained ML model; and providing an answer to a question utilizing the trained ML model.
E21B 44/00 - Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systemsSystems specially adapted for monitoring a plurality of drilling variables or conditions
E21B 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 computer-implemented method to assess risk of gas breakout in a well includes determining a rate of migration of a gas injected into a well containing a section of cement. The method also includes predicting, based on the rate of migration, an amount of time for a breakout to occur, wherein the breakout occurs when the gas penetrates the section of the cement to a location of interest. The method further includes determining an effective diffusivity of the gas when the gas achieves breakout. The method further includes assessing a risk of a gas breakout based on the rate of migration and the effective diffusivity of the gas.
Embodiments of a downhole drilling tool, system, and method are disclosed herein. In one embodiment, A downhole sub, comprising: a housing; and at least one tunable stiffness member integrated with the housing, the tunable stiffness member comprising a programmable stiffness material; wherein a stiffness of the tunable stiffness member is adjusted in response to instructions from a control unit of a wellbore system. In another embodiment, a method is provided for adjusting the stiffness of a sub having one or more tunable stiffness members while the tool on which the sub is placed remains downhole.
E21B 47/01 - Devices for supporting measuring instruments on drill bits, pipes, rods or wirelinesProtecting measuring instruments in boreholes against heat, shock, pressure or the like
B65D 88/26 - Hoppers, i.e. containers having funnel-shaped discharge sections
B65D 88/56 - Large containers characterised by means facilitating filling or emptying by tilting
B65G 65/23 - Devices for tilting and emptying of containers
B65G 65/30 - Methods or devices for filling or emptying bunkers, hoppers, tanks, or like containers, of interest apart from their use in particular chemical or physical processes or their application in particular machines, e.g. not covered by a single other subclass
B65G 69/08 - Devices for emptying storage spaces as completely as possible
97.
CONTROL SYSTEM FOR REGULATING A GASEOUS FUEL SUPPLY TO AN ENGINE AT A WELLBORE
E21B 41/00 - Equipment or details not covered by groups
E21B 43/00 - Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
F01B 31/00 - Component parts, details or accessories not provided for in, or of interest apart from, other groups
F02B 77/00 - Component parts, details, or accessories, not otherwise provided for
F02D 9/08 - Throttle valves specially adapted thereforArrangements of such valves in conduits
F02D 29/04 - Controlling engines, such controlling being peculiar to the devices driven thereby, the devices being other than parts or accessories essential to engine operation, e.g. controlling of engines by signals external thereto peculiar to engines driving pumps
F02D 41/36 - Controlling fuel injection of the low pressure type with means for controlling distribution
B65G 65/30 - Methods or devices for filling or emptying bunkers, hoppers, tanks, or like containers, of interest apart from their use in particular chemical or physical processes or their application in particular machines, e.g. not covered by a single other subclass
E21B 41/00 - Equipment or details not covered by groups
E21B 43/26 - Methods for stimulating production by forming crevices or fractures
99.
MANAGING LUBRICATION OF HYDRAULIC FRACTURING PUMPS
A system can include a tubing positionable downhole in a wellbore and a tubing encapsulated conductor, where at least a portion of the tubing encapsulated conductor is positionable downhole in the wellbore. The tubing encapsulated conductor can include at least one interior wire positionable to transmit electric power from a power source associated with the wellbore to at least one piece of electrical equipment during a wellbore operation performed with respect to the wellbore. The tubing encapsulated conductor can also include a metal sheath positionable around the at least one interior wire and a ground wire positionable external to the metal sheath. Further, the tubing encapsulated conductor can include an encapsulation layer positionable to encoat the metal sheath and the ground wire to facilitate one or more electrical couplings between the metal sheath and the ground wire.
