Described herein are methods and materials for increasing the scavenging efficiency of hydrogen sulfide collected or produced in subterranean formations during wellbore environments. The methods can include first identifying a location that may include a concentration of production fluid that may contain high concentrations of H2S gas. The production fluid may be initially collected and tested to determine the concentration of H2S gas within the production fluid mixture. The production fluid, after testing, may then be treated, using in-line injection methods including a concentration of scavenging material to scavenge H2S gas from the production fluid and produce a cleaner gas after treatment.
A system comprising a power cable to be positioned downhole in a wellbore formed in a subsurface formation, wherein the power cable generates a magnetic field. The system comprises a first energy harvesting device coupled with the power cable and configured to harvest power from the magnetic field, wherein the power is to be supplied to one or more downhole devices.
Systems, methods, and apparatus, including computer programs encoded on computer-readable media, for implementing an optical marker for fiber optic cable identification and well system calibration and automation. A well system may include a fiber optic cable and an optical marker device. The optical marker device may include a fiber optic line configured to couple to the fiber optic cable of the well system. The optical marker device may include one or more attenuators coupled with the fiber optic line. The one or more attenuators are configurable to set an optical marker that uniquely identifies the fiber optic cable. The optical marker device that implements the optical marker may be positioned at a known location of the well system for use in the calibration and automation of the well system.
E21B 47/09 - Locating or determining the position of objects in boreholes or wellsIdentifying the free or blocked portions of pipes
E21B 43/26 - Methods for stimulating production by forming crevices or fractures
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 47/135 - 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 49/00 - Testing the nature of borehole wallsFormation testingMethods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
G01V 1/22 - Transmitting seismic signals to recording or processing apparatus
G01V 1/28 - Processing seismic data, e.g. for interpretation or for event detection
G01V 13/00 - Manufacturing, calibrating, cleaning, or repairing instruments or devices covered by groups
Described herein are methods and materials for increasing the scavenging efficiency of hydrogen sulfide collected or produced in subterranean formations during wellbore environments. The methods can include first identifying a location that may include a concentration of gas that may contain high concentrations of H2S gas. The gas may be initially collected and tested to determine the concentration of gas within the gas mixtures. The gas mixture, after testing, may then be passed through a bubble tower reactor that includes a concentration of scavenging material to scavenge H2S gas from the gas mixture and produce a cleaner gas after treatment.
A method may include injecting a sealing material into an annulus formed between a tubular and a wellbore wall. The sealing material is configured to surround at least a portion of a control line disposed in the annulus. Further, the method includes making at least one orbital cut, via a cutting device, through the tubular, the sealing material in the annulus, and the control line surrounded by the sealing material. Additionally, the method includes filling the at least one orbital cut and at least a portion of a central bore of the tubular with additional sealing material to seal the wellbore.
A pile can include: an elongated member; and a grout at least partially coupled to and for anchoring the elongated member, comprising: a resin; and a boron nitride nanotube structure comprising a boron nitride nanotube having a hexagonal boron nitride structure epitaxial to the boron nitride nanotube, wherein the grout has a first volume substantially free of the boron nitride nanotube structure, and a second volume comprising the boron nitride nanotube structure.
Described herein are methods and materials for increasing the scavenging efficiency of carbon dioxide, such as produced during combustion operations. The gas may be initially collected and tested to determine the concentration of gas within the gas mixtures. The gas mixture, after testing, may then be passed through a bubble tower reactor that includes a concentration of scavenging material to scavenge CO2 gas from the gas mixture and generate a cleaner gas and a carbon-rich liquid after treatment.
B01D 53/78 - Liquid phase processes with gas-liquid contact
B01D 53/14 - Separation of gases or vapoursRecovering vapours of volatile solvents from gasesChemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases or aerosols by absorption
Mobile downhole tools with fairings and methods of using the same. A mobile downhole tool is introduced into a wellbore. The mobile downhole tool has a housing with a thickness sufficient to support a pressure differential between an interior surface of the housing and an exterior surface of the housing when the mobile downhole tool is disposed in the wellbore, and a fairing coupled to the exterior surface of the housing. The fairing is structurally distinct from the housing and is not connected to the interior surface of the housing. The fairing curves in a first direction that is away from the housing. The mobile downhole tool is propelled in the wellbore as the wellbore is produced such that the mobile downhole tool descends downhole against the upstream flow of a wellbore fluid.
The embodiments herein provide a ball valve assembly comprising a ball with an external piston that is biased against the ball to create an external seat at a surface of the ball on the down hole side of the ball as well as an internal piston that is biased against the ball to create an internal seat at a surface of the ball also on the down hole side of the ball. Some embodiments also provide an external gasket that seals between the external piston and the internal piston and an internal gasket that seals between the internal piston and a stationary body. Some embodiments also provide an external spring positioned between the internal piston and the external piston and an internal spring positioned between a stationary body and the internal piston. In some embodiments, the external spring force is the only force acting on the external piston when the valve is sealing off downhole fluid.
A method and system for identifying anisotropy properties in a formation. The method may include disposing a logging tool into a formation, wherein the logging tool may include an electromagnetic transmitter antenna and an electromagnetic receiver antenna. The method may further include transmitting an electric field signal into the formation from the electromagnetic transmitter antenna, receiving a reflected electric field signal or a magnetic field signal from the formation with the electromagnetic receiver antenna, measuring the reflected electric field signal or the magnetic field signal from the formation with the electromagnetic receiver antenna, and identifying one or more anisotropy properties of adjacent layers in the formation from the reflected electric field signal or the magnetic field signal.
G01V 3/28 - Electric or magnetic prospecting or detectingMeasuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for well-logging operating with magnetic or electric fields produced or modified either by the surrounding earth formation or by the detecting device using induction coils
11.
Spiral Waveform Analysis For Behind Pipe Cement Evaluation, Well Abandonment Operations And Complex Annular Environments
In general, in one aspect, embodiments relate to a method and/or system that includes disposing a cement bond logging tool into a wellbore. The method and/or system comprising: a cement bond logging tool comprising: two or more transmitters configured to transmit an acoustic wave from cement bond logging tool; and an array of receivers configured to receive a refracted waveform; and an information handling system configured to process the refracted waveform from the array of receivers into a cement bond property log.
E21B 47/005 - Monitoring or checking of cementation quality or level
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
Some implementations include a modular gun system for use in a wellbore comprising one or more charge segments each including a first electrical conductor having a first set of integrated electrical contacts.
An exemplary rotor assembly for an electric submersible pump may include a drive shaft, a journal sleeve concentrically disposed about and rotationally fixed to the drive shaft, a bushing concentrically disposed about and configured to rotate with respect to the journal sleeve, and a thrust washer, or component integrating the thrust washer, encircling the drive shaft. Concavities may be formed in an axial face of the bushing or an axial face of the thrust washer. The axial face of the bushing may be disposed proximate to the axial face of the thrust washer. The concavities may be configured to influence flow of lubrication fluid between the bushing and the thrust washer to create a hydrodynamic force against the bushing and the thrust washer when the drive shaft rotates to prevent axial contact.
DOWNHOLE TOOL, WELL SYSTEM, AND METHOD EMPLOYING A SENSOR POSITIONED PROXIMATE A SIGNAL NOISE SOURCE POWERED BY A DOWNHOLE POWER SOURCE, THE SENSOR CONFIGURED TO SENSE FOR NOISE AND SEND UPHOLE OPERATIONAL DATA EMBEDDED WITHIN THE NOISE
Provided is a downhole tool, a well system, and a method. The downhole tool, in one aspect, includes a downhole device located proximate a downhole power source, the downhole device having circuitry coupled thereto, the circuitry configured to receive power from the downhole power source and measure operational data of the downhole device or downhole power source. The downhole tool, in accordance with another aspect, includes a signal noise source coupled with the circuitry, the signal noise source configured to receive the measured operational data from the circuitry and embed the operational data as noise. The downhole tool, in accordance with another aspect, includes a sensor positioned proximate the signal noise source, the sensor configured to sense for the noise and send uphole the operational data embedded within the noise.
E21B 47/107 - Locating fluid leaks, intrusions or movements using acoustic means
E21B 34/06 - Valve arrangements for boreholes or wells in wells
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 49/08 - Obtaining fluid samples or testing fluids, in boreholes or wells
15.
ELECTRIC SUBMERSIBLE PUMP ROTOR ASSEMBLY WITH BEARING SPACER CONFIGURED FOR THRUST WASHER SUPPORT
An exemplary rotor assembly for an ESP motor can comprise a rotor module concentrically disposed on a drive shaft; a bearing assembly concentrically disposed about the drive shaft in proximity to the rotor module; a thrust washer concentrically disposed about the drive shaft and axially between the bearing assembly and the rotor module; and an axial support flange disposed concentrically about the drive shaft and axially between the thrust washer and the rotor module. In some embodiments, the axial support flange can abut the thrust washer. Disclosed embodiments may reduce dishing of the thrust washer when the motor is in operation, which can be particularly useful in embodiments having concavities formed in an axial face of the bearing bushing or the thrust washer which can influence flow of lubrication fluid between the bushing and the thrust washer to create a hydrodynamic force.
Systems and techniques are provided for determining a time zero echo of a nuclear magnetic resonance (NMR) sequence. An example method includes obtaining, via an NMR tool in a borehole, echo waveforms associated with refocusing pulses and a free induction decay (FID) waveform associated with an excitation pulse; determining echo values based on the echo waveforms and an apparent time-zero echo value based on the FID waveform, the apparent time-zero echo value representing a time zero echo; applying a correction factor to the apparent time-zero echo value to yield a corrected time zero echo value; and determining a spectrum associated with a sample based on an inversion performed on the corrected time zero echo values and the set of echo values before or after a conversion of the corrected time zero echo value and the set of echo values to porosity units, the conversion of the corrected time zero echo value and the set of echo values being based on one or more conversion factors.
G01N 24/08 - Investigating or analysing materials by the use of nuclear magnetic resonance, electron paramagnetic resonance or other spin effects by using nuclear magnetic resonance
G01R 33/44 - Arrangements or instruments for measuring magnetic variables involving magnetic resonance using nuclear magnetic resonance [NMR]
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
Provided are embodiments of a multi-sensor apparatus for use downhole in a wellbore, a system, and a method for using a multi-sensor apparatus. In one embodiment, an apparatus for use in a wellbore, comprises a manifold, the manifold having a plurality of ports; a housing connected with the manifold; at least three sensors positioned within the housing; and a first internal channel and a second internal channel for enabling fluid flow through the manifold. In another embodiment, a system includes a removable downhole tool and a multi-sensor apparatus coupled with the removable downhole tool.
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
18.
DOWNHOLE ISOLATION TOOL INCLUDING AN ISOLATION SLEEVE AND SACRIFICIAL PLUG MEMBER
Provided is a downhole isolation tool, a well system, and a method. The downhole isolation tool, in one aspect, includes an outer housing, the outer housing having a fluid passageway extending along a length thereof, an outer housing exterior surface, and an outer housing interior surface, as well as one or more fluid flow ports connecting the fluid passageway and the outer housing exterior surface. The downhole isolation tool, in one aspect, further includes an isolation sleeve positioned within the fluid passageway, the isolation sleeve configured to shift between an open state and a closed state covering the one or more fluid flow ports and obstructing fluid flow between the fluid passageway and the outer housing exterior surface, as well as a sacrificial plug member fluidly coupled with the fluid passageway, the sacrificial plug member configured to seal fluid flow through the fluid passageway.
E21B 34/14 - Valve arrangements for boreholes or wells in wells operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools
E21B 23/00 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells
A downhole system may include a downhole tubular having a body portion formed between a central bore and a radially outer surface of the downhole tubular, a neutron generator housed within the body portion and configured to emit neutrons, and a gamma ray detector housed within the body portion and configured to detect gamma rays formed via interactions between the emitted neutrons and a downhole formation. The downhole system may also include a sleeve disposed about the radially outer surface of the downhole tubular. The sleeve may be axially positioned over at least a portion of the gamma ray detector. Additionally, the downhole system may include a thermal neutron absorption layer disposed between a radially outer surface of the sleeve and the gamma ray detector.
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
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
20.
DOWNHOLE TOOL, WELL SYSTEM, AND METHOD EMPLOYING A SENSOR POSITIONED PROXIMATE A FLOW CONTROL DEVICE, THE SENSOR CONFIGURED TO SENSE FOR A CHANGE IN NOISE EMANATING FROM THE FLOW CONTROL DEVICE
Provided is a downhole tool, a well system, and a method. The downhole tool, in one aspect, includes a flow control device coupleable with a tubing string, the flow control device configured to allow fluid to pass between an outside diameter (OD) of the tubing string and an inside diameter (ID) of the tubing string. The downhole tool, in accordance with another aspect, includes a sensor positioned proximate the flow control device, the sensor configured to sense for and send uphole operational data originating from the flow control device, the operational data in a form of a change in noise emanating from the flow control device.
DOWNHOLE TOOL, WELL SYSTEM, AND METHOD EMPLOYING A SENSOR POSITIONED PROXIMATE A SPINNING FEATURE OF A DOWNHOLE DEVICE, THE SENSOR CONFIGURED TO SENSE FOR A CHANGE IN NOISE EMANATING FROM THE SPINNING FEATURE
Provided is a downhole tool, a well system, and a method. The downhole tool, in one aspect, includes a downhole device, the downhole device including a spinning feature associated therewith. The downhole tool, in accordance with another aspect, includes a sensor positioned proximate the spinning feature of the downhole device, the sensor configured to sense for and send uphole operational data originating from the spinning feature of the downhole device, the operational data in the form of a change in noise emanating from the spinning feature of the downhole device.
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
G01D 5/26 - Mechanical means for transferring the output of a sensing memberMeans for converting the output of a sensing member to another variable where the form or nature of the sensing member does not constrain the means for convertingTransducers not specially adapted for a specific variable using optical means, i.e. using infrared, visible or ultraviolet light
22.
FLUIDIC MANIFOLD FOR OPENING AND CLOSING A DOWNHOLE VALVE
A system may include a production valve secured in a production fluid line of a downhole tubular. The production valve is configured to control flow through the production fluid line between a wellbore annulus and a central bore of the downhole tubular. The system may further include a pilot line extending at least to the production valve from the annulus. A flow restrictor disposed within the pilot line is configured to increase fluid pressure in the pilot line. Further, the system may include a solenoid valve secured within the pilot line and configured to actuate between an open state and a closed state in response to instructions from a controller. Pressure in the pilot line is configured to rise above an actuation threshold pressure configured to close the production valve in response to formation fluid flowing through the solenoid valve in the open state of the solenoid valve.
A rotating machine. The rotating machine comprises a tubular housing; a drive shaft disposed at least partly inside the tubular housing; a component disposed inside of the tubular housing that is coupled to the drive shaft and configured to do work as the drive shaft rotates; and a shaft stop assembly coupled to the drive shaft comprising a collet disposed around the drive shaft, a compressor flange disposed around the collet and around the drive shaft and engaging with the collet to compress the collet to form a friction fit with the drive shaft, and a compression stop disposed around the compressor flange and around the drive shaft, wherein a first axial end of the compression stop abuts an end of the collet.
A method of controlling a pumping sequence of a fracturing fleet at a wellsite with three or more wellbores comprising determining first, second, and third pumping sequences for a first, second, and third wellbore. The pumping sequences are comprised of a plurality of pump stages that are intervals based on time or volume. The intervals of the first, second, and third pumping sequences are overlapped into a combined pumping sequence. Each of the plurality of intervals of the modified combined pumping sequence is below an operating limit of at least one fracturing unit of the fracturing fleet. The method can include identifying at least one interval wherein the combined pumping sequence exceeds an operating limit of at least one fracturing unit of the fracturing fleet, wherein the at least one interval of the modified combined pumping sequence is below the operating limit.
E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
E21B 43/26 - Methods for stimulating production by forming crevices or fractures
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
25.
DOWNHOLE WELL TOOL HAVING A CONNECTOR MECHANISM WITH A CLEANING DIELECTRIC CHAMBER FOR WELL SYSTEMS
Systems, methods, and apparatus for establishing a downhole connection between a first well tool and a second well tool. The first well tool may include a mandrel, a first connector assembly, and an elongated protection sleeve. The protection sleeve may form a hydraulic chamber over the mandrel when positioned in a closed position, and the hydraulic chamber may include a dielectric cleaning material. The elongated protection sleeve may be configured to mechanically move to an open position when engaging with a second well tool downhole to release the dielectric cleaning material and connect with the second well tool via the first connector assembly. The dielectric cleaning material may be injected into a cavity between the first connector assembly of the first well tool and a second connector assembly of the second well tool to clean and displace downhole fluids and debris located in the cavity and establish the connection.
E21B 37/06 - Methods or apparatus for cleaning boreholes or wells using chemical means for preventing or limiting the deposition of paraffins or like substances
Wellbore systems include one or more sensing devices configured to sense physical parameters before, during, and/or after fluid injection procedures are performed to inject fluid into a subterranean formation. Seismic vibrations may be induced into the subterranean formation and detected at the injection wellbore or in a remote monitoring wellbore as part of monitoring and evaluation of the fluid injection operations. The one or more sensing devices may also be configured to monitor well production and/or formation conditions in and around a single wellbore and/or in multiple wellbore systems.
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
G01V 1/22 - Transmitting seismic signals to recording or processing apparatus
G01V 1/42 - SeismologySeismic or acoustic prospecting or detecting specially adapted for well-logging using generators in one well and receivers elsewhere or vice-versa
27.
LOCK SYSTEM FOR TRANSPORT CONTAINERS AND METHOD OF ASSEMBLY THEREOF
A lock system for holding transport containers, the system including one or more pairs of brackets, each bracket including frame guides, axle guides and gusset plates. The frame guides are coupled to a major surface of a bracket body of the bracket and have guide walls projecting perpendicularly from the major surface to form frame openings. The axle guides are coupled to and project perpendicularly from the major surface and each of the axle guides surround first thru-holes in the bracket body. The gusset plates couple one of the guide walls to the major surface and the gusset plates have one or more second thru holes therein. A method of assembling the system is also disclosed.
An apparatus comprising a gravel pack assembly positioned in a wellbore formed in a subsurface formation. The apparatus comprising a lower completion assembly positioned at a depth in the wellbore deeper than the gravel pack assembly, wherein the lower completion assembly is configured with a wet mate housing to communicatively couple a first line positioned in the wellbore and a second line positioned on an upper completion assembly.
Disclosed herein are systems and methods of controlling downhole production flow from one or more production zones of a well. A system may include at least one downhole power generator, at least one sensor, at least one electronic assembly, and at least one production valve. In some systems, the downhole power generator, the sensor, the electronic assembly, and the production valve are incorporated within the same module. The downhole power generator is fluidically connected to the fluid inside the production tubing string. The sensor is electrically connected to the downhole power generator, wherein the sensor measures a phase of the fluid. The electronic assembly is connected to the downhole power generator and the sensor. The production valve is electrically connected to the electronic assembly and fluidly connected to the fluid inside the production tubing string.
E21B 41/00 - Equipment or details not covered by groups
E21B 34/06 - Valve arrangements for boreholes or wells in wells
E21B 47/10 - Locating fluid leaks, intrusions or movements
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
30.
DOWNHOLE ANOMALY LOCALIZATION AND INTERPRETATION USING ACOUSTIC AND ELECTROMAGNETIC LOGGING
Disclosed are systems and methods for detecting a downhole anomaly. The method can include receiving one or more acoustic measurements at a plurality of corresponding depths in a casing, determining a presence of a flow at one or more flow depths, receiving one or more electromagnetic measurements at each of the one or more flow depths in the casing, determining an integrity of the casing at each of the one or more flow depths in the casing, and determining a presence or absence of a leak at each of the one or more flow depths in the casing based on the integrity of the casing at each of the one or more flow depths.
A puddle job can be performed in a wellbore to secure a liner within an open-hole wellbore. A resin in liquid form can be spotted at the bottom of the wellbore. The liner can be lowered into the wellbore to displace the resin up into an annulus between the outside of the liner and the wellbore wall. The resin can be contacted with a solid or liquid activator to cause the resin to set. The activator can cause the resin to set via a polymerization reaction such as ROMP, FRP, or step polymerization. The resin can be contacted with the activator as the liner is being lowered or afterwards. The resin/activator can be used instead of a cement composition.
E21B 33/05 - Cementing-heads, e.g. having provision for introducing cementing plugs
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 43/16 - Enhanced recovery methods for obtaining hydrocarbons
A gas separator for an electric submersible pump includes an inlet, an outlet, and a first portion including a first inner circumferential surface and a first outer circumferential surface having a first diameter. The first portion is disposed between the inlet and the outlet. The gas separator further includes a second portion including a second inner circumferential surface and a second outer circumferential surface having a second diameter. The second portion is disposed between the first portion and the outlet. The first diameter is less than the second diameter.
A puddle job can be performed in a wellbore to secure a liner within an open-hole wellbore. A resin in liquid form can be spotted at the bottom of the wellbore. The liner can be lowered into the wellbore to displace the resin up into an annulus between the outside of the liner and the wellbore wall. The resin can be contacted with a solid or liquid initiator to cause the resin to set. The resin can be contacted with the initiator as the liner is being lowered or afterwards. The resin/initiator can be used instead of a cement composition.
A blending unit is provided. The blending unit comprises two or more discharge pumps. Each of the two or more discharge pumps has a suction inlet fluidly connected to a common proppant fluid supply via a concentrated proppant inlet line, and a discharge outlet fluidly connected to a blender outlet line. Each of the two or more discharge pumps also has an injection port upstream of the discharge pump and configured to inject substantially proppant-free fluid into the concentrated proppant inlet line, an injection port downstream from the discharge pump and configured to inject substantially proppant-free fluid into the blender outlet line, or both the injection port upstream of the discharge pump and the injection port downstream from the discharge pump.
A proportioner comprising one or more proportioner inlets configured to receive a common concentrated proppant fluid comprising a proppant; two or more flow lines fluidly connected to the one or more proportioner inlets; two or more proportioner outlets, each of the two or more proportioner outlets associated with one of the two or more flow lines; one or more fluid inlets, each of the one or more fluid inlets configured to introduce a proppant-free fluid to the proportioner; and a metering system associated with at least one of the two or more flow lines, each at least one metering system upstream of the proportioner outlet of the flow line with which it is associated and each metering system fluidly connected with at least one of the one or more fluid inlets and configured for proportioning one of the proppant-free fluids into the associated flow line at an injection point.
Some implementations include a method comprising positioning a fluoroplastic sleeve on a body of a liner hanger configured for insertion in a borehole. The method also may include heating the fluoroplastic sleeve.
In general, in one aspect, embodiments relate to a downhole tool assembly, that includes a rotary mechanism, a pulsing mechanism, that includes a rotary disc in mechanical communication with the rotary mechanism, where a window of the rotary disc periodically aligns with a corresponding window of the downhole tool assembly to generate a pressure pulse based on a periodicity of the rotary mechanism, and a discharge port configured to discharge fluid as the fluid is being pulsed by the pulsing mechanism.
E21B 47/24 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling using acoustic waves through the well fluid by positive mud pulses using a flow restricting valve within the drill pipe
E21B 33/13 - Methods or devices for cementing, for plugging holes, crevices or the like
38.
Method and composition for treating lost circulation
An invert emulsion is used to form a hydrated flocculated polymer useful in reducing fluid loss in downhole operations. The invert emulsion can be sheared to form the hydrated flocculated polymer, which can be introduced downhole into the fluid loss flow path in a subterranean formation and allowed to accumulate at the pore throat to reduce fluid loss.
A debris collection tool that includes a swirl generator that includes a first opening disposed on an exterior of the debris collection tool, and a second opening disposed inside the debris collection tool, where the first opening and the second opening are disposed at opposite axial ends of the swirl generator.
Board of Regents, The University of Texas System (USA)
Inventor
Xu, Jiamin
Zhang, He
Tian, Kaixiao
Demirer, Nazli
Liu, Yang
Bhaidasna, Ketan C.
Darbe, Robert P.
Chen, Dongmei
Abstract
In directional drilling, a nonlinear Delay Differential Equation (DDE) model may be used for its high precision in predicting how a borehole may be drilled according to a well plan. To address challenges associated with real-time control of a drill drilling wellbore, techniques of generalized feedback linearization, finite element concept, and zero-order hold discretization may be used to transform a nonlinear DDE model into discretized domain with a linear Ordinary Differential Equation (ODE) form. Following this transformation, a novel optimization framework may be used to concurrently determine optimal control inputs and solve a linear complementarity problem (LCP). The validity of both the discretized model and the optimization strategy may be verified by comparing modeled results with real-world results. Subsequent closed-loop simulations demonstrate the ability of the proposed model predictive control to maintain alignment of a drill string with a planned well trajectory, even in the presence of disturbances and noise.
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 packer assembly can be used to create a seal against an inside of a tubing string. The packer assembly can be used in high-temperature, high-pressure wellbores. The packer assembly can include a first and second sealing element with a spacer located between. The spacer can be made from a deformable material such that during mechanical or hydraulic actuation of the sealing elements, the spacer expands to make contact with the inside of the tubing string and keeps at least a portion of the inside edges of the sealing elements separated. The deformable spacer can reduce the amount of elongation strain the sealing elements commonly encounter at the vicinity of current metal spacer designs during setting below a value that would cause a loss of structural integrity to the sealing elements.
Systems, methods, and apparatus, including computer programs encoded on computer-readable media, for performing a seismic survey and characterization of a subsurface formation. Seismic sources coupled to a wellbore of a well system may emit source seismic signals. Seismic sensors coupled to the wellbore may detect seismic signals associated with the plurality of source seismic signals. The detected seismic signals may be reflected seismic signals, refracted seismic signals, or both. A seismic characterization of the subsurface formation may be performed based on analysis of the detected seismic signals and the plurality of source seismic signals. A change in a fluid front of the subsurface formation may be detected based on the seismic characterization of the subsurface formation. Inflow control devices that control fluid flow in a plurality of zones of the wellbore may be controlled based on the seismic characterization and a detected change in the fluid front.
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
43.
PRODUCING FLUID FROM A WELL USING DISTRIBUTED ACOUSTIC SENSING AND AN ELECTRICAL SUBMERSIBLE PUMP
In some embodiments, a system for producing fluid from a well can include an electrical submersible pump (ESP) disposed in a wellbore of the well and configured to pump the fluid. The system may further include a distributed acoustic sensing (DAS) system, for example having an interrogator unit and a fiber optic cable extending downhole in the wellbore. An end of the fiber optic cable can be disposed downhole relative to the ESP. In embodiments, the system may further include a controller configured to receive data from the DAS system, process the data to detect a slug, determine a parameter of the detected slug, and alter operation of the ESP in response to determining that the parameter exceeds a threshold.
Drilling fluids for drilling a wellbore. An example drilling fluid includes an aqueous base fluid, a first fluid loss control additive that is a cross-linked polymer comprising N-vinylpyrrolidone as a monomer, and a second fluid loss control additive that is a cross-linked copolymer comprising a first comonomer of 2-acrylamido-2-methylpropanesulfonic acid in a first comonomer concentration of at least 50 mol % of the copolymer. The second fluid loss control additive additionally includes a second comonomer of an N-vinyl amine-containing monomer, a terminal double bound-containing monomer, or a combination of an N-vinyl amine-containing monomer and a terminal double bound-containing monomer. The second comonomer is present in a total second comonomer concentration of 50 mol % or less of the copolymer.
A system and method for installing an energy storage system, the energy storage system including an electrical load and a cement capacitor electrically connected to the electrical load. The cement capacitor includes a first cement electrode; a second cement electrode; and a separator between the first cement electrode and the second cement electrode, wherein the separator electrically insulates the first cement electrode from the second cement electrode. The cement capacitor is charged by passing electricity to the cement capacitor via the electrical load. The cement capacitor is discharged by passing electricity from the cement capacitor to the electrical load.
An apparatus for sealing an annular space proximate to an end of a sand screen on a downhole tubular may include a flexible seal configured to encircle the tubular. The flexible seal may include a first state in which an outer diameter of the flexible seal is less than a diameter of a wellbore, and a second state in which the outer diameter of the flexible seal is the same as the diameter of the wellbore. The apparatus may further include a deployment mechanism configured to cause the flexible seal to transition from the first state to the second state.
An array of hydrophones may be deployed in a wellbore to collect sounds that may be used to identify whether a wellbore is safe to operate. This hydrophone array may include acoustic sensors that sense noises indicative of a defect that could lead to catastrophic failure of a wellbore and other noises that may be considered unwanted background noises. Techniques of the present disclosure may classify noises indicative of a defect as being “signals of interest.” The presence of “background noise” may interfere with the collection and/or evaluation of “signals of interest.” Because of this, evaluations performed on data that includes “background noise” and “signals of interest” may result in inaccurate determinations being made regarding the safety of a wellbore. As such, systems and methods of the present disclosure are directed to improving safety of a wellbore by removing “background noise” more effectively while increasing quality of “signals of interest.”
G01V 1/36 - Effecting static or dynamic corrections on records, e.g. correcting spreadCorrelating seismic signalsEliminating effects of unwanted energy
G01V 1/18 - Receiving elements, e.g. seismometer, geophone
A hydrophone may be deployed in a wellbore to collect sounds that may be used to identify whether a wellbore is safe to operate. This hydrophone may include acoustic sensors that sense noise generated by motion of the hydrophone and may sense noise indicative of a defect that could lead to catastrophic failure of a wellbore. Noise generated by movement of the hydrophone may be classified as “road noise” and noise associated with wellbore defects may be classified being “signals of interest.” The presence of “road noise” may interfere with the collection of “signals of interest” and because of this, evaluations performed on data that includes “road noise” may result in inaccurate determinations and a decrease in safety. As such, systems and methods of the present disclosure are directed to improving safety of a wellbore by removing “road noise” more effectively while increasing quality of “signals of interest.”
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.
An example control system includes a hydraulic pump disposed in a wellbore, a valve bank disposed in the wellbore, and an unpressurized hydraulic fluid reservoir. The hydraulic pump is fluidically connected with the valve bank. The valve bank is fluidically connected with the unpressurized hydraulic fluid reservoir. The unpressurized hydraulic fluid reservoir is fluidically connected with the hydraulic pump. The control system is configured to flow pressurized hydraulic fluid exiting from the hydraulic pump to the valve bank to be distributed from the valve bank to the wellbore equipment.
Provided is a frac window system, a well system, and a wellbore stimulation method. The frac window system, in one aspect, includes an elongated tubular having a first end and a second end with an opening defined in a wall of the elongated tubular between the first end and the second end, the wall having an inner surface and an outer surface, wherein the opening in the wall is configured to align with a window of a wellbore casing. The frac window system, according to this aspect, may further include a polished bore receptacle coupled to the first end of the elongated tubular, the polished bore receptacle having an inside diameter (ID1) sufficient to engage with a high-pressure frac string.
A method comprises obtaining, via one or more pressure measurement devices, measurements of a pressure of a fluid when a force is applied to one or more elements of a downhole tool positioned in a wellbore formed in a subsurface formation. The method comprises determining the force applied to the one or more elements based on the pressure of the fluid.
Provided is a method for setting a downhole tool, and a downhole tool, and a well system employing the same. The method, in at least one aspect, includes positioning a downhole tool within a wellbore, the downhole tool including expandable metal configured to expand in response to hydrolysis, and subjecting the expandable metal to a wellbore fluid to expand the expandable metal into contact with one or more surfaces. The method, in at least one aspect, further includes applying a voltage to the expandable metal while the expandable metal is being subjected to the wellbore fluid.
Provided is a method for setting a downhole tool, and a downhole localized heater. The method, in at least one aspect, includes positioning a downhole tool within a wellbore, the downhole tool including expandable metal configured to expand in response to hydrolysis, and positioning a downhole localized heater within the wellbore, the downhole localized heater being proximate the expandable metal. The method additionally includes subjecting the expandable metal to a wellbore fluid to expand the expandable metal into contact with one or more surfaces while activating the downhole localized heater to create a temperature spike and accelerate an expansion of the expandable metal.
This disclosure presents an apparatus to improve the position sensing of a moving mechanism, such as a fluid valve located within a borehole. The apparatus can utilize a light beam or an optical fiber to measure changes in the position sensor. The smaller and lighter apparatus can improve the accuracy of the sensing mechanism. In addition, three systems are presented. The first system utilizes a vibration sensor, such as a MEMS, and an accelerometer to calculate changes in the mechanism position of the moving mechanism. The second system utilizes a radiation source and detector combination, along with a moving radiation shield to provide more accurate position sensing than conventional techniques. In addition, a lens-based system is presented, that when combined with a radiation source, can calculate position information by detecting the diffusion or dispersal of the radiation against a radiation detector.
E21B 47/09 - Locating or determining the position of objects in boreholes or wellsIdentifying the free or blocked portions of pipes
F16K 37/00 - Special means in or on valves or other cut-off apparatus for indicating or recording operation thereof, or for enabling an alarm to be given
56.
Subsurface safety valve including two or more oppositely poled electromagnets and two or more oppositely poled permanent magnets
Provided is an SSSV, a well system, and a method. The SSSV, in one aspect, includes two or more electromagnets fixedly coupled to a housing, a first of the two or more electromagnets having its north pole facing a first electromagnet direction and a second of the two or more electromagnets having is south pole facing first electromagnet direction. The SSSV, in accordance with this aspect, further includes two or more permanent magnets coupled to the flow tube, a first of the two or more permanent magnets having its south pole facing a first permanent magnet direction and a second of the two or more permanent magnets having its north pole facing the first permanent magnet direction, the two or more permanent magnets configured to axially move with a flow tube.
Provided is an SSSV, a well system, and a method. The SSSV, in one aspect, includes an electromagnet fixedly coupled to a housing, a target positioned proximate the electromagnet, and a radially compressible member located radially between a flow tube and the housing. In one aspect, the radially compressible member is engageable with the target and is configured to move between: 1) a radially extended state when the electromagnet is not energized and the target is in an axially distal position to allow the flow tube to move between a closed state and an open state, and 2) a radially compressed state when the electromagnet is energized and the target is in an axially proximal position to hold the flow tube in a flow state.
Systems, methods, and apparatus, including computer programs encoded on computer-readable media, for validating well system measurements. Sample datasets for a plurality of measurement channels of a first channel set are obtained from one or more well devices of a well system. A comparison operation is performed of a first sample dataset associated with a first sample unit of measure of a first measurement channel of a first channel set with historical datasets of one or more historical units of measure of one or more matched historical measurement channels. A frequency of occurrence operation is performed for the first sample unit of measure and the one or more historical units of measure across the plurality of measurement channels of the first channel set. A validation process is performed based on the comparison operation or the frequency of occurrence operation, or both the comparison operation and the frequency of occurrence operation.
Provided is a magnet for use with an SSSV, an SSSV, a well system, and a method. The magnet, in one aspect, includes an electropermanent magnet. The magnet, in accordance with this aspect, further includes a self-powered protection circuit coupled to the electropermanent magnet, the self-powered protection circuit configured to switch the electropermanent magnet to the OFF state when the SSSV loses power.
Disclosed herein are methods and systems of evaluating cement integrity behind a coated casing string using acoustic signals. The methods include disposing an acoustic logging tool inside a coated casing string, wherein the coated casing string is disposed in a wellbore to form an annulus between the coated casing string and the wellbore, and is at least in part bonded to the wellbore by a cement. Further, the methods include transmitting an acoustic signal into at least part of the coated casing string to form a Lamb wave mode, measuring an attribute of a Lamb wave mode, and determining if the coated casing string is fully or partially bonded to the cement or is free pipe or is partially bonded to a formation based at least in part on the Lamb wave mode.
G01N 29/22 - Investigating or analysing materials by the use of ultrasonic, sonic or infrasonic wavesVisualisation of the interior of objects by transmitting ultrasonic or sonic waves through the object Details
A binder composition, and methods relating thereto, can comprise a poly-epoxy glycerol-based oil, a crosslinker, and a soluble organic acid with two or more acid groups. The binder composition has an activation temperature of from about 25° C. to about 400° C. The binder material can be used, for example, to bind particulate material to form consolidated particulate material in a wellbore or subterranean formation.
An elastomeric material that includes a silicon-based polymer can be positioned in a wellbore to provide fluid control with respect to the wellbore, such as by isolating a well interval of the wellbore. The elastomeric material can be formed using a mixture of a matrix polymer and a heterobifunctional siloxane polymer that can be incorporated into the matrix polymer. The elastomeric material can be positioned in a wellbore tool to form a seal in the wellbore.
Systems and methods for interpreting one or more borehole features are provided herein. The method can include deploying an azimuthal borehole measurement tool into a borehole, obtaining at least one azimuthal borehole image, generating a synthetic image by sparse convolution of a weight function and a plurality of feature kernels, determining an optimal weight function that minimizes a difference between the synthetic image and the at least one azimuthal borehole image, and determining one or more geological characteristics of the borehole based on the optimal weight function and the feature functional representation.
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
G01V 3/38 - Processing data, e.g. for analysis, for interpretation or for correction
A method that may comprise disposing a bottom hole assembly into a formation, wherein the bottom hole assembly comprises a mud motor, identifying a first segmented data set for a slide mode of the mud motor, and identifying a second segmented data set for a rotate mode of the mud motor. The method may further comprise calibrating the mud motor at least in part using a Reversible Jump Markov Chain Monte Carlo (RJMCMC), wherein the RJMCMC uses at least in part the first segmented data set and the second segmented data set.
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
65.
System and Method for Controlling Hybrid and Grid Power in an Electric Fracturing Spread
A load phase back system for controlling a plurality of electrical loads in an electric fracturing spread. The load phase back system comprises monitoring circuitry configured to monitor input power received from an electric power source. The monitoring circuitry determines a measured voltage and a measured frequency of the input power. A controller controls the power applied to the plurality of electrical loads from a power bus according to a value of the measured voltage and a value of the measured frequency of the input power. The controller reduces power applied to selected ones of the plurality of electrical loads from the power bus when at least one of the measured voltage is less than a first threshold and the measured frequency is less than a second threshold.
H02P 27/04 - Arrangements or methods for the control of AC motors characterised by the kind of supply voltage using variable-frequency supply voltage, e.g. inverter or converter supply voltage
E21B 43/26 - Methods for stimulating production by forming crevices or fractures
66.
Sensing a DC power parameter of an electromagnetic assembly of a downhole device to estimate the status or health thereof
Provided is a downhole device, a well system, and a method. The downhole device, in one aspect, includes an electromagnetic assembly, as well as a magnetic target positioned proximate the electromagnetic assembly, wherein one of the magnetic target or the electromagnetic assembly is coupled with a movable feature of the downhole device, the movable feature configured to move to physically couple or physically decouple the electromagnetic assembly and the magnetic target. The downhole device, according to this aspect, further includes a sensor electrically coupled to the electromagnetic assembly, the sensor configured to sense for a change in a DC power parameter powering the electromagnetic assembly as the electromagnetic assembly and magnetic target physically couple to or physically decouple from one another, the sensed change representative of a change of impedance within a coil of the electromagnetic assembly and employable to estimate the status or health of the downhole device.
E21B 34/06 - Valve arrangements for boreholes or wells in wells
F16K 31/02 - Operating meansReleasing devices electricOperating meansReleasing devices magnetic
F16K 37/00 - Special means in or on valves or other cut-off apparatus for indicating or recording operation thereof, or for enabling an alarm to be given
A method for detecting the presence of an insulation gas in a housing. The method may include setting a high voltage power supply to a first voltage, wherein the first voltage flows through a ladder disposed in a pulsed neutron logging tool. The method may further include taking one or more measurements of a current flowing through the ladder and comparing the one or more measurements of the current to a threshold.
G01M 3/40 - Investigating fluid tightness of structures by using electric means, e.g. by observing electric discharges
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
A downhole system may include an insert frame securable within a central bore of a tubing retrievable safety valve that has driver magnet configured to project a magnetic field and move axially along a control line in the tubing retrievable safety valve. The downhole system may include an insert flapper connected to the insert frame and configured to actuate between an open position and a closed position to control fluid flow through the central bore. The downhole system may include an insert flow tube configured to move along the central bore to drive the insert flapper between the closed position and the open position. Further, the downhole system may include a follower magnet secured to the insert flow tube and magnetically engaged with the driver magnet. The follower magnet is configured to move in response to movement of the driver magnet to drive movement of the insert flow tube.
A downhole sealing tool and method use a swellable material (e.g., a swellable rubber or a swellable metallic material) with increased surface area for faster reaction with an activation fluid. In one example, a swellable metallic sealing element and actuator are carried on a tool mandrel for lowering into a wellbore on a conveyance. The sealing element includes a plurality of expandable metal wires supported along the tool mandrel. The expandable metal wires comprise a swellable metallic material that swells in response to exposure to an activation fluid. The actuator is used to separate at least a portion of the expandable metal wires, to increase a surface area exposed to the activation fluid and thereby accelerate the reaction.
Disclosed is generating an acquisition request of a component, using a probabilistic model based on current and planned life consumption, to maintain a usable component inventory, by: determining planned consumption of the component; retrieving historical lifetime data associated with the component; determining the associated normalized current life consumed for historical specimens at failure based on a power law equivalency model; determining a probability of survival distribution associated with the component; determine a probability of future failure of each component in inventory given planned consumption of the component; determine a projected number of component failures prior to completion of the job associated with the component; generate the at least one acquisition request to acquire a quantity of new components at least equal to the projected number of specific component failures prior to completion of the job; wherein the usable inventory of the component includes at least the quantity of new components.
A method comprises obtaining a first drilling dataset corresponding to a first bottom hole assembly drilling a first wellbore. The method comprises determining mapping parameters based on the first drilling dataset and elastic properties of the first wellbore. The method comprises obtaining a second drilling dataset corresponding to a second bottom hole assembly drilling a second wellbore. The method comprises determining the elastic properties of the second wellbore based on the second drilling data and the mapping parameters.
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
72.
ORGANIC ESTERS WITH ELECTRON WITHDRAWING GROUPS FOR USE IN SUBTERRANEAN FORMATIONS
Methods and compositions involving certain organic esters that release an organic acid for use in the subterranean formation are provided. In some embodiments, the methods include: providing a treatment fluid including an aqueous base fluid and at least one organic ester that includes at least one electron withdrawing group selected from the group consisting of F, Cl, Br, I, NO2, a vinyl group, an acetylenic group, an aromatic group, a carbonyl group, an alkoxyl group, a cyano functional group (C≡N), and any derivative thereof; and introducing the treatment fluid into at least a portion of a wellbore penetrating at least a portion of a subterranean formation.
E21B 37/06 - Methods or apparatus for cleaning boreholes or wells using chemical means for preventing or limiting the deposition of paraffins or like substances
E21B 43/27 - Methods for stimulating production by forming crevices or fractures by use of eroding chemicals, e.g. acids
Some implementations include an apparatus comprising a finned insert configured for placement within at least a portion of an inner circumference of a slotted compressible tubular, the finned insert having a plurality of fins, wherein each fin of the plurality of fins is configured to fit within a slot of the slotted compressible tubular.
A method comprises obtaining drilling data of a drill bit while drilling a wellbore in a formation with the drill bit. The method comprises generating stress representatives and strain representatives via a bit-rock interaction model configured with parameters to map the drilling data. The method comprises determining one or more elastic properties of the formation based on the stress representatives and the strain representatives.
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
75.
Flow Control System for Use in a Subterranean Well
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.
Disclosed herein are methods and systems for capturing a large collection of downhole fluid samples and, more particularly, disclosed are methods and systems for using at least two hydraulic pressure lines to alternatingly actuate hydraulic valves disposed in an interlinked series to obtain any large collection of hydraulically actuated components to be energized in sequence. A large collection of downhole fluid samples may be defined as any number of downhole fluid samples wherein the number of downhole fluid samples is larger than the number of actuators.
Disclosed herein are methods and systems for capturing a large collection of downhole fluid samples and, more particularly, disclosed are methods and systems for using at least two hydraulic pressure lines to alternatingly actuate hydraulic valves disposed in an interlinked series to obtain any large collection of hydraulically actuated components to be energized in sequence. A large collection of downhole fluid samples may be defined as any number of downhole fluid samples wherein the number of downhole fluid samples is larger than the number of actuators.
Systems and methods of separating multiphase flows in a flowline of a downhole fluid sampling and analysis tool, measuring target ions in the water phase, and separating between formation water and injection water are described. The system to separate the multiphase flows includes a three-dimensional barrier permeable to water and repelling oil and/or drilling mud filtrate into at least one bypass channel within the flowline of the downhole fluid sampling and analysis tool. For instance, the system to measure the targeted ions includes the system to separate the multiphase flows and an optical sensor, wherein the three-dimensional barrier has an aperture inside the three-dimensional barrier to let a light from an optical sensor go through perpendicular to the flowline.
G01N 21/78 - Systems in which material is subjected to a chemical reaction, the progress or the result of the reaction being investigated by observing the effect on a chemical indicator producing a change of colour
79.
CROSS-CORRELATION FILTER FOR DISTRIBUTED ACOUSTIC SENSING SYSTEM FOR WELLBORE
A system can include a distributed acoustic sensing (DAS) system and a computing device coupled with the DAS system. The DAS system can include a pulse generator and a sensing fiber that can be positioned in a wellbore. The system can generate a light pulse to be transmitted into the sensing fiber to make one or more measurements relating to a wellbore operation involving the wellbore. The system can receive an initial pulse that includes a reflection of the light pulse prior to the light pulse entering the sensing fiber. The system can apply a cross-correlation filter to one or more subsequently received pulse reflections originating from the sensing fiber. The cross-correlation filter can include the initial pulse reflection or synthetic initial pulse. The system can generate, based on applying the cross-correlation filter, an output signal that can be used to control the wellbore operation.
G01V 1/36 - Effecting static or dynamic corrections on records, e.g. correcting spreadCorrelating seismic signalsEliminating effects of unwanted energy
E21B 43/26 - Methods for stimulating production by forming crevices or fractures
G01V 1/22 - Transmitting seismic signals to recording or processing apparatus
A computing system executing a surface software application as part of a decoupled software architecture includes detecting that an update is available for a software plugin component of the surface software application. Each software plugin component is associated with a respective feature of the surface software application and in communication with a respective firmware component and a respective hardware component. A dependency matrix mapping compatibilities with plugin components, hardware components, and firmware components is evaluated to determine whether the update is compatible with the respective hardware component. The update is installed upon a determination that the plugin is compatible.
A system can include a continuous circulation subcomponent, a robotic device, and a control system. The subcomponent can include a receiving area and can be associated with a drilling operation for forming a wellbore. The robotic device can include an end effector that can include a sensing device and tools corresponding to operations to facilitate continuous circulation in the wellbore. The control system can cause the robotic device to perform operations. The robotic device can align the end effector with the receiving area. The robotic device can determine whether a leak is present at the receiving area. The robotic device can connect, disconnect, or a combination thereof the diversion line with the receiving area to allow the continuous circulation during the drilling operation.
A method can be used to determine the optimal inputs for a bottle test performed by a user for separating water from oil. The bottle test model for predicting inputs to achieve desired KPIs may decrease times required for a user to predict a demulsifier composition. The methods and model may then be utilized for predicting a demulsifier composition based upon inputs of a crude oil product to predict a demulsifier composition for most efficiently separating the oil from water for new production sites.
A variety of methods and apparatus are disclosed, including, in one embodiment, a pulsed neutron logging tool for a borehole in a subterranean formation, including: a pulsed neutron generator to broadcast neutrons into the subterranean formation; and a gamma ray scintillator detector comprising cerium bromide (CeBr3), wherein the pulsed neutron logging tool (e.g., as lowered into the borehole) is configured to detect neutron-induced gamma rays from the subterranean formation and natural gamma rays from the subterranean formation.
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 5/04 - Prospecting or detecting by the use of ionising radiation, e.g. of natural or induced radioactivity specially adapted for well-logging
84.
GENERATING DYNAMIC MULTI-DISTRIBUTION INVERSION MODELS TO FACILITATE WELLBORE OPERATIONS
A system can provide a dynamic multi-distribution model to facilitate a wellbore operation. For example, the system can receive, from a downhole tool deployed in a wellbore during a drilling operation, resistivity data for a geological formation associated with an interval of the wellbore. The system can further execute a resistivity inversion algorithm to generate distribution outputs of a resistivity inversion model using the resistivity data. Additionally, the system can select a section of each of the distribution outputs. Each section of each distribution output can correspond with a different segment of the interval of the wellbore. The system can then generate a dynamic multi-distribution model. The dynamic multi-distribution model can include the sections selected from each of the distribution outputs. The system can further output, by a user interface, the dynamic distribution output, which can be used to adjust the drilling operation.
A system for controlling intelligent completion valves (ICVs) used in a hydrocarbon well operation is disclosed. The ICVs can be located downhole in a wellbore, and an outflow of pressurized injection fluid from the wellbore may be used to drive hydrocarbons toward one or more offset producing wells. A trained machine-learning model can be generated by training a machine-learning model on training data comprising acoustic signal data generated by a pressurized injection fluid flowing through the ICVs at various flow rates and ICV positions. When applied to new acoustic sensing system sensor data associated with an ICV of multiple ICVs in the well, the trained machine-learning model can generate a result indicating a predicted flow rate of the pressurized injection fluid through the ICV. The result may be output and used to control the flow rate of pressurized injection fluid through the ICVs.
A tubing to be positioned in a wellbore, the tubing comprising: a channel having multiple pairs of slots created on each side of the channel, wherein each of the multiple pairs of slots is positioned at different depths of the wellbore, wherein at least one cable is to be positioned in the channel and comprises at least one of a sensor or a splice; and a clamp configured to be positioned in each of the multiple pairs of slots and configurable to clamp down on the at least one cable positioned in the channel, wherein the clamp is to be positioned in a first pair of slots of the multiple pairs of the slots such that clamp is not positioned over the at least one sensor or the splice of the least one cable.
The disclosure presents processes that utilize collected resistivity data, for example, from an ultra-deep resistivity tool located downhole a borehole. In some aspects, each slice of resistivity data can generate multiple distribution curves that can be overlaid offset resistivity logs. In some aspects, an analysis can be performed to identify trends in the distribution curves that can be used to identify approximate locations of subterranean formation surfaces, shoulder beds, obstacles, proximate boreholes, and other borehole and geological characteristics. As the number of distribution curves generated increase, the confidence in the analysis also increases. In some aspects, the number of distribution curves can be twenty, one hundred, one hundred and one, or other counts of distribution curves. In some aspects, the resistivity data can be used to generate two or more synchronized view perspectives of a specific location along the borehole, where each view perspective uses the same focus area.
G01V 3/02 - Electric or magnetic prospecting or detectingMeasuring magnetic field characteristics of the earth, e.g. declination or deviation operating with propagation of electric current
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 47/026 - Determining slope or direction of penetrated ground layers
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
G01V 3/38 - Processing data, e.g. for analysis, for interpretation or for correction
88.
DOWNHOLE TOOL INCLUDING RELATED LUG SLOTS AND LUGS FOR COUPLING A MILLING TOOL AND WHIPSTOCK ASSEMBLY
Provided is a milling tool, a whipstock assembly, a well system, and a method. The milling tool, in at least one aspect, includes a plurality of blades extending radially outward from a mill body, each of the plurality of blades having a primary surface and first and second side surfaces coupled to opposing sides of the primary surface, adjacent blades of the plurality of blades separated by a spacing. The milling tool may further includes a lug slot extending partially into one of the plurality of blades from the first side surface exposed by the spacing, the lug slot configured to engage with a lug of a related tool to couple the milling tool with the related tool when rotating in a first direction and to disengage from the lug of the related tool to release the milling tool from the related tool when rotating in a second opposite direction.
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 29/06 - Cutting windows, e.g. directional window cutters for whipstock operations
89.
DOWNHOLE TOOL INCLUDING RELATED LUG SLOTS AND LUGS FOR COUPLING A MILLING TOOL AND WHIPSTOCK ASSEMBLY
Provided is a milling tool, a whipstock assembly, a well system, and a method. The milling tool, in at least one aspect, includes a plurality of blades extending radially outward from a mill body, each of the plurality of blades having a primary surface and first and second side surfaces coupled to opposing sides of the primary surface, adjacent blades of the plurality of blades separated by a spacing. The milling tool may further includes a lug slot extending partially into one of the plurality of blades from the first side surface exposed by the spacing, the lug slot configured to engage with a lug of a related tool to couple the milling tool with the related tool when rotating in a first direction and to disengage from the lug of the related tool to release the milling tool from the related tool when rotating in a second opposite direction.
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 29/06 - Cutting windows, e.g. directional window cutters for whipstock operations
90.
DATA-DRIVEN METHODS TO DETERMINE POSITION OF A MOVING OBJECT IN A WELLBORE
A computer-implemented method for determining the position of a downhole component with a neural network model is provided. The computer-implemented method can include acquiring real-time or characteristic data including values for one or more input variables associated with one or more time steps in a cementing operation, training the neural network to minimize a loss function and estimate a value for the position of the downhole component and an uncertainty at one or more time steps, estimating the value at the one or more time steps, estimating an uncertainty in the value at the one or more time steps, determining an operation position of the downhole component when an operation is to be performed, and determining the time step when the operation is to be performed.
E21B 47/09 - Locating or determining the position of objects in boreholes or wellsIdentifying the free or blocked portions of pipes
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
91.
OPERATING INTELLIGENT COMPLETION VALVES IN A HYDROCARBON WELL USING MACHINE LEARNING
A system for operating intelligent completion valves (ICVs) used in a hydrocarbon well operation is disclosed. The ICVs can be positionable downhole in a wellbore. A trained machine-learning model can be generated by training a machine-learning model on training data comprising acoustic signal data generated by a pressurized injection fluid flowing through the ICVs at various flow rates and different ICV positions. When new acoustic sensing system sensor data associated with an ICV of multiple ICVs in the wellbore is applied to the trained machine-learning model, the trained machine-learning model can generate a result determining that the amplitude spike is attributable to a change in the position of the intelligent completion valve. The system may also determine a magnitude of the change in the position of the intelligent completion valve. The result may be output and used to control the ICV.
A method of performing a nuclear magnetic resonance (NMR) measurement of a subterranean formation includes calibrating an NMR tool at a calibration formation operational frequency (ωgƒ@RT) and a calibration borehole operational frequency (ωgbh@RT) to determine calibration parameters for both the borehole and the formation sensitive volumes. The NMR tool is then operated in the borehole to determine, in the borehole sensitive volume, a downhole borehole operational frequency (ωgbh@T) at which the downhole borehole sensitive volume is substantially unchanged from the calibration borehole sensitive volume. A processor determines a downhole formation operational frequency (ωgƒ@T) at which the downhole formation sensitive volume is substantially unchanged from the calibration formation sensitive volume relative to the NMR tool based on ωgbh@T, ωgbh@RT, and ωgƒ@RT. The processor also determines an optimal amplitude modulation (AMopt) for ωgƒ@T. The NMR tool measures a property of the formation at ωgƒ@T and AMopt.
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
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 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
G01V 13/00 - Manufacturing, calibrating, cleaning, or repairing instruments or devices covered by groups
Some implementations include a system comprising an electrical line positioned proximate to one or more subsurface formations; and a permanent downhole sensor array coupled to the electrical line, the permanent downhole sensor array including one or more downhole sensors, each downhole sensor including: a first sensing device configured to detect at least a first component of a downhole fluid.
E21B 47/005 - Monitoring or checking of cementation quality or level
E21B 34/06 - Valve arrangements for boreholes or wells in wells
E21B 47/10 - Locating fluid leaks, intrusions or movements
E21B 49/08 - Obtaining fluid samples or testing fluids, in boreholes or wells
G01N 21/31 - Investigating relative effect of material at wavelengths characteristic of specific elements or molecules, e.g. atomic absorption spectrometry
A system can be used to control a wellbore tool using a piezoelectric pump. The system can include a piston, the piezoelectric pump, and a solenoid valve. The piston can be positioned in a wellbore to control the wellbore tool. The piezoelectric pump can be coupled with the piston to generate differential pressure. The piston can be actuated in at least a first direction or a second direction in response to receiving the differential pressure. The solenoid valve can be coupled with the piezoelectric pump to selectively cause the piezoelectric pump to apply the differential pressure in the first direction or in the second direction.
Provided are methods and systems to generate power from hydrogen in a hybrid hydrogen power generation system including two or more different hydrogen power generation systems. In some examples, electricity may be generated to power oilfield equipment by hydrogen fuel cells and/or by solid oxide fuel cells. Electricity may also be generated to recharge an energy storage for future electricity use. Hydrogen may also be injected directly into an internal combustion engine powering oilfield equipment such as a turbine and/or a reciprocating engine to lower hydrocarbon-based fuel consumption.
E21B 41/00 - Equipment or details not covered by groups
C01B 3/24 - Production of hydrogen or of gaseous mixtures containing hydrogen by decomposition of gaseous or liquid organic compounds of hydrocarbons
H01M 8/0612 - Combination of fuel cells with means for production of reactants or for treatment of residues with means for production of gaseous reactants from carbon-containing material
H01M 8/12 - Fuel cells with solid electrolytes operating at high temperature, e.g. with stabilised ZrO2 electrolyte
96.
CEMENT HEAD FLOW DIVERTER FOR TETHERED CEMENT PLUG DEPLOYMENT
Systems and methods are provided for tethered plug deployment using a cement head flow diverter. In some aspects, the present technology may include a cement head comprising: an elongated housing having a top opening, a bottom opening, and an interior housing space; a cap coupled to the top opening of the elongated housing, wherein the cap includes an aperture for receiving a communication line; an inner canister disposed within the interior housing space of the elongated housing, wherein the inner canister has a top open end, a bottom open end, and an interior canister space; and a cement plug disposed within the interior canister space of the inner canister, wherein a top portion of the cement plug is configured to couple to the communication line through the top open end of the inner canister.
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 chargePlugs therefor
E21B 47/005 - Monitoring or checking of cementation quality or level
97.
DOWNHOLE TOOL WITH CRACK COMPLIANT SEAL AND MECHANICAL STRENGTHENING FEATURE AT A JOINT THEREOF
Provided is a downhole tool, a well system and a method. The downhole tool, in one aspect, includes a first member, the first member having a first member hardness value (HV1), and a second member, the second member having a second member hardness value (HV2), the first and second members positioned proximate one another forming an overlapping space therebetween. The downhole tool according to this aspect, further includes a mechanical strengthening feature located between the first member and the second member, the mechanical strengthening feature configured to increase an engineering rating of the overlapping space, and a crack compliant seal positioned at the overlapping space, the crack compliant seal having a compliant seal hardness value (HVcs) less than or equal to one or more of the (HV1) or the (HV2).
Provided is a well system, and a method. The well system, in one aspect, includes a wellbore positioned within a subterranean formation, as well as a downhole tool positioned within the wellbore. The downhole tool, according to one aspect, includes a housing, as well as an expandable metal member positioned about the housing, the expandable metal member comprising a metal configured to expand in response to hydrolysis. The well system, in one further aspect, includes a reactive colloidal dispersion of colloid particles surrounding a surface of the expandable metal member.
Provided is a downhole tool, a well system and a method. The downhole tool, in one aspect, includes a first member, the first member having a first member inside diameter (ID1), a first member outside diameter (OD1), and a first member hardness value (HV1), and a second member, the second member having a second member inside diameter (ID2), a second member outside diameter (OD2), and a second member hardness value (HV2), the first and second members positioned proximate one another forming an overlapping space therebetween. The downhole tool according to this aspect, further includes a crack compliant seal positioned at the overlapping space and having a compliant seal hardness value (HVcs) less than or equal to one or more of the (HV1) or (HV2) and a high yield strength weld positioned at the overlapping space, the high yield strength weld having a yield strength of at least 50 ksi.
Provided are a downhole tool, a well system, and a method. The downhole tool, in one aspect, includes a housing, as well as an expandable metal member positioned about the housing, the expandable metal member comprising a metal configured to expand in response to hydrolysis. The downhole tool, according to one aspect, further includes colloid particles surrounding a surface of the expandable metal member.
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 chargePlugs therefor
C09K 8/32 - Non-aqueous well-drilling compositions, e.g. oil-based
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