A method comprising: prior to commissioning of a processing equipment into service, cleaning and/or passivating a contact surface of the processing equipment with a vapor comprising a chemistry and a carrier, wherein cleaning comprises removing one or more contaminants from the contact surface and wherein passivating comprises creating a passive film on the contact surface. A method of vapor phase descaling is also provided.
Methods and systems herein may be configured to utilize a downhole tool comprising: a transmitter configured to transmit an acoustic signal into at least part of a conduit string, wherein the transmitter is a first downhole element. In addition, receiver configured to measure an incoming signal from at least part of the conduit string, wherein the receiver is the first downhole element or a second downhole element. Further, disposing a downhole tool into a wellbore, wherein the downhole tool and transmitting an acoustic signal into at least part of a conduit string with the transmitter; and receiving the incoming signal from at least part of a conduit string with the receiver.
A method for acoustic noise source detection. The method may include disposing an acoustic logging tool into a wellbore, taking a first measurement at a first depth with the acoustic logging tool as the acoustic logging tool traverses down the wellbore, taking a second measurement at a second depth with the acoustic logging tool as the acoustic logging tool traverses down the wellbore, and forming a first noise source localization map based at least in part on the first measurement. The method may further include forming a second noise source localization map based at least in part on the second measurement and combining the first noise source localization map and the second noise source localization map to form a final enhanced noise source localization map.
Methods and systems herein may be configured to utilize a downhole tool comprising: a transmitter configured to transmit an acoustic signal into at least part of a conduit string, wherein the transmitter is a first downhole element. In addition, receiver configured to measure an incoming signal from at least part of the conduit string, wherein the receiver is the first downhole element or a second downhole element. Further, disposing a downhole tool into a wellbore, wherein the downhole tool and transmitting an acoustic signal into at least part of a conduit string with the transmitter; and receiving the incoming signal from at least part of a conduit string with the receiver.
G01V 1/18 - Receiving elements, e.g. seismometer, geophone
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
5.
CRYOGENIC COOLANT FLOW MANAGEMENT FOR DOWNHOLE SUPERCONDUCTING CABLE
Systems and methods disclosed herein may comprise a bottom hole assembly; and a cable disposed in the wellbore. In examples, the cable may comprise a superconducting material configured to provide at least power to the bottom hole assembly; one or more liquid supply channels configured to supply a fluid to reduce temperature of the superconducting material; and one or more liquid return channels. Further, cryogenic liquid may be pumped through the liquid supply channels.
E21B 47/125 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling using earth as an electrical conductor
A method of improving heat recovery from a geothermal well includes receiving temperature distribution data from a distributed temperature sensing (DTS) system comprising a fiber optic cable disposed in a wellbore, which extends through a formation; analyzing the temperature distribution data to determine a fluid flow profile along the wellbore; determining, based on the fluid flow profile, a location of dominant flow rate; and injecting a sealing agent into the formation at the location. When the sealing agent cures, fractures within a fracture system are sealed in the formation at the location. The cured sealing agent prevents or mitigates fluid flow through the formation at the location.
Aspects of the subject technology relate to systems, methods, and computer-readable media for building electrically submersible pump (ESP) systems. ESP systems include parts that must be compatible with a wellbore environment for them to operate as desired. Parts that operate well when pumping oil may not operate well when pumping geothermal water. Parts of an ESP system must be able to fit into the wellbore and operate according to the expectations of a wellbore operator. This means that parts used to build an ESP system must be selected such that the ESP system may be operated according to an operational plan. Once an ESP system is designed and built, it may be operated in a manner that is consistent with an operational plan. Techniques of the present disclosure include machine learning processes that identify how best to design, build, and operate an ESP system based on a set of characteristics.
Waves from cement bond logging with a sonic logging-while-drilling tool (LWD-CBL) are often contaminated with tool waves and may yield biased CBL amplitudes. The disclosed LWD-CBL wave processing corrects the first echo amplitudes of LWD-CBL before calculating the BI. The LWD-CBL wave processing calculates a tool wave amplitude and a phase angle difference as the difference of the phases between the tool waves and casing waves. The tool waves are then used to correct the LWD-CBL casing wave amplitude and remove errors introduced from tool waves. In conjunction with the sets of operations described, the LWD-CBL wave processing also includes array preprocessing operations. Array preprocessing may employ variation of bandpass filtering and frequency-wavenumber (F-K) filtering operations to suppress tool waves.
E21B 47/005 - Monitoring or checking of cementation quality or level
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 1/36 - Effecting static or dynamic corrections on records, e.g. correcting spreadCorrelating seismic signalsEliminating effects of unwanted energy
A method of improving heat recovery from a geothermal well includes receiving temperature distribution data from a distributed temperature sensing (DTS) system comprising a fiber optic cable disposed in a wellbore, which extends through a formation; analyzing the temperature distribution data to determine a fluid flow profile along the wellbore; determining, based on the fluid flow profile, a location of dominant flow rate; and injecting a sealing agent into the formation at the location. When the sealing agent cures, fractures within a fracture system are sealed in the formation at the location. The cured sealing agent prevents or mitigates fluid flow through the formation at the location.
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.
Aspects of the subject technology relate to systems, methods, and computer-readable media for building electrically submersible pump (ESP) systems. ESP systems include parts that must be compatible with a wellbore environment for them to operate as desired. Parts that operate well when pumping oil may not operate well when pumping geothermal water. Parts of an ESP system must be able to fit into the wellbore and operate according to the expectations of a wellbore operator. This means that parts used to build an ESP system must be selected such that the ESP system may be operated according to an operational plan. Once an ESP system is designed and built, it may be operated in a manner that is consistent with an operational plan. Techniques of the present disclosure include machine learning processes that identify how best to design, build, and operate an ESP system based on a set of characteristics.
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
E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
F04D 13/10 - Units comprising pumps and their driving means the pump being electrically driven for submerged use adapted for use in mining bore holes
12.
CRYOGENIC COOLANT FLOW MANAGEMENT FOR DOWNHOLE SUPERCONDUCTING CABLE
Systems and methods disclosed herein may comprise a bottom hole assembly; and a cable disposed in the wellbore. In examples, the cable may comprise a superconducting material configured to provide at least power to the bottom hole assembly; one or more liquid supply channels configured to supply a fluid to reduce temperature of the superconducting material; and one or more liquid return channels. Further, cryogenic liquid may be pumped through the liquid supply channels.
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.
C09K 8/467 - Compositions for cementing, e.g. for cementing casings into boreholesCompositions for plugging, e.g. for killing wells containing inorganic binders, e.g. Portland cement containing additives for specific purposes
C04B 24/28 - Macromolecular compounds obtained otherwise than by reactions only involving carbon-to-carbon unsaturated bonds
C04B 28/02 - Compositions of mortars, concrete or artificial stone, containing inorganic binders or the reaction product of an inorganic and an organic binder, e.g. polycarboxylate cements containing hydraulic cements other than calcium sulfates
C04B 103/00 - Function or property of the active ingredients
A method comprising: prior to commissioning of a processing equipment into service, cleaning and/or passivating a contact surface of the processing equipment with a vapor comprising a chemistry and a carrier, wherein cleaning comprises removing one or more contaminants from the contact surface and wherein passivating comprises creating a passive film on the contact surface. A method of vapor phase descaling is also provided.
A method for acoustic noise source detection. The method may include disposing an acoustic logging tool into a wellbore, taking a first measurement at a first depth with the acoustic logging tool as the acoustic logging tool traverses down the wellbore, taking a second measurement at a second depth with the acoustic logging tool as the acoustic logging tool traverses down the wellbore, and forming a first noise source localization map based at least in part on the first measurement. The method may further include forming a second noise source localization map based at least in part on the second measurement and combining the first noise source localization map and the second noise source localization map to form a final enhanced noise source localization map.
G01V 1/40 - SeismologySeismic or acoustic prospecting or detecting specially adapted for well-logging
G01V 1/18 - Receiving elements, e.g. seismometer, geophone
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
Improved rotor module balancing approaches are disclosed. For example, a rotor module may be configured to be concentrically disposed on a drive shaft of an ESP motor, and may include an active length, as well as a plurality of pockets which each can extend axially into the active length and be configured to retain one of a plurality of balance masses. Such exemplary rotor modules may be balanced by determining a direction and a mass amount representing unbalance of the rotor module; based on that determination, determining specific pockets for receiving the balance masses and the amount of each corresponding balance mass; and inserting the balance masses into the corresponding pockets. Such an approach may allow for quick and efficient rotor balancing, while minimizing length of the rotor module and/or maximizing the ratio of active length versus total length of the rotor module.
A variety of methods and systems for detecting top of cement in well operations are disclosed, including, in one embodiment, a method for detecting top of cement, including: emitting input energy signals into a cement displacement fluid positioned in a casing, wherein the input energy signals travel in the cement displacement fluid down the casing and are reflected in the casing to form reflected energy signals that return to a surface, and wherein the input energy signals are emitted while a cement composition is setting to harden and form compressive strength in a borehole annulus; measuring one or more properties of the reflected energy signals; and determining the top of cement of the cement composition in the borehole annulus based on at least the one or more properties and temperature data of the borehole.
E21B 47/095 - Locating or determining the position of objects in boreholes or wellsIdentifying the free or blocked portions of pipes by detecting acoustic anomalies, e.g. using mud-pressure pulses
18.
Interactive and smart workflow to measure noise free formation pressure and characterize supercharge in formation testing
Disclosed herein are systems and methods to obtain representative formation pore pressure and formation mobility from pressure measurements with a formation testing tool. In some embodiments, the method includes performing a first pre-test in which a pressure sensor measures a drawdown pressure and a buildup pressure, calculating a statistical value for the measured buildup pressure, determining if the statistical value is above or below a threshold, shutting down a mud pulser if the statistical value is above or below the threshold, and performing a second pre-test in which the pressure sensor measures a second drawdown pressure and a second buildup pressure. In embodiments, the second pre-test includes a formation fluid drawdown flow rate that is different than a formation fluid drawdown flow rate in the first pre-test.
E21B 47/18 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling using acoustic waves through the well fluid
E21B 49/00 - Testing the nature of borehole wallsFormation testingMethods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
A system may include a centralizer configured to be disposed in a radial gap formed between a downhole tubular and a sonde housing. The centralizer may include at least one support feature having a first circumferential end feature, a second circumferential end feature, and an elongated body portion extending axially along a centralizer axis and extending circumferentially about the centralizer axis from the first circumferential end feature to the second circumferential end feature. The elongated body portion may be corrugated with radially inward extending portions and radially outward extending portions alternating along the elongated body portion. Additionally, the radially inward extending portions may be configured to contact the sonde housing and the radially outward extending portions may be configured to contact the downhole tubular to hold the sonde housing in a centralized position with respect to the downhole tubular.
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
20.
BLEND OF PHOSPHONATE ACIDS FOR SCALE PREVENTION IN HIGH ALKALINITY AND HIGH CO2 ENVIRONMENTS
Treatment fluids and methods for preventing the formation of scale. A treatment fluid is provided to the wellbore. The treatment fluid is composed of polyamino polyether methylene phosphonate (PAPEMP), aminoethylethanolamine tri(methylene phosphonate) (AEEA), an organic acid, and an aqueous base fluid. The treatment fluid is introduced into a wellbore penetrating a subterranean formation. A mineral in the wellbore is contacted with the treatment fluid thereby preventing further mineral formation and deposition.
A debris separation and storage ("SAS") apparatus for removing debris from a wellbore, the SAS apparatus including a chamber that includes a housing and an inlet tube located within the housing. The inlet tube includes a plurality of exit apertures positioned along the length of the inlet tube and configured to allow flow of a debris slurry, within the wellbore, from the inlet tube into an SAS area outside of the inlet tube. The chamber also includes a plurality of filter tubes located within the SAS area and oriented parallel to and radially outward from the inlet tube. The filter tubes are configured to block debris larger than a predetermined size of debris from flowing into the filter tubes while allowing the remaining fluid from the debris slurry to pass through the plurality of filter tubes and then out of the chamber, thereby producing a processed debris slurry.
E21B 27/00 - Containers for collecting or depositing substances in boreholes or wells, e.g. bailers for collecting mud or sandDrill bits with means for collecting substances, e.g. valve drill bits
A system may include a centralizer configured to be disposed in a radial gap formed between a downhole tubular and a sonde housing. The centralizer may include at least one support feature having a first circumferential end feature, a second circumferential end feature, and an elongated body portion extending axially along a centralizer axis and extending circumferentially about the centralizer axis from the first circumferential end feature to the second circumferential end feature. The elongated body portion may be corrugated with radially inward extending portions and radially outward extending portions alternating along the elongated body portion. Additionally, the radially inward extending portions may be configured to contact the sonde housing and the radially outward extending portions may be configured to contact the downhole tubular to hold the sonde housing in a centralized position with respect to the downhole tubular.
Treatment fluids and methods for preventing the formation of scale. A treatment fluid is provided to the wellbore. The treatment fluid is composed of polyamino polyether methylene phosphonate (PAPEMP), aminoethylethanolamine tri(methylene phosphonate) (AEEA), an organic acid, and an aqueous base fluid. The treatment fluid is introduced into a wellbore penetrating a subterranean formation. A mineral in the wellbore is contacted with the treatment fluid thereby preventing further mineral formation and deposition.
C09K 8/12 - Clay-free compositions containing synthetic organic macromolecular compounds or their precursors
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
09 - Scientific and electric apparatus and instruments
42 - Scientific, technological and industrial services, research and design
Goods & Services
(1) Active magnetic ranging system comprised of electromagnetic apparatus used to generate or measure magnetic fields (1) Active magnetic ranging services, namely, conducting magnetic resonance imaging interpretation and analysis for the petroleum industry
25.
ENERGY DELIVERY SYSTEM FOR SUPPLYING HYDRAULIC PRESSURE FOR SEVERING AN INTERVENTON MEDIUM
An energy delivery system for supplying hydraulic pressure for severing an intervention medium includes a tubular and a housing. Isolation pistons, actuation pistons, and a compression piston are disposed between the tubular and the housing. A first chamber is formed between the tubular and the housing. One or more second chambers are formed between one or more first pairs of the isolation pistons and the actuation pistons. One or more third chambers are formed between one or more second pairs of the isolation pistons and the actuation pistons. The actuation pistons are configured to transmit force to the compression piston to reduce a volume of the first chamber to pressurize a control fluid to actuate a ball valve to sever an intervention medium.
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.
G16C 20/30 - Prediction of properties of chemical compounds, compositions or mixtures
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
Improved rotor module balancing approaches are disclosed. For example, a rotor module may be configured to be concentrically disposed on a drive shaft of an ESP motor, and may include an active length, as well as a plurality of pockets which each can extend axially into the active length and be configured to retain one of a plurality of balance masses. Such exemplary rotor modules may be balanced by determining a direction and a mass amount representing unbalance of the rotor module; based on that determination, determining specific pockets for receiving the balance masses and the amount of each corresponding balance mass; and inserting the balance masses into the corresponding pockets. Such an approach may allow for quick and efficient rotor balancing, while minimizing length of the rotor module and/or maximizing the ratio of active length versus total length of the rotor module.
The present disclosure relates to borehole sonic logging and, more particularly to, improved reflection imaging of formation structures away from the wellbore. A method for borehole sonic reflection imaging may comprise: disposing a borehole sonic logging tool in a wellbore, wherein the borehole sonic logging tool comprises one or more transmitters and one or more receivers; emitting sound waves from the one or more transmitters; receiving sound waves at the one or more receivers to obtain borehole sonic data; separating up-going arrivals in the borehole sonic data from down-going arrivals in the borehole sonic data; generating a first reflection image based at least on the borehole sonic data; estimating a relative dip angle of a formation bed from the first reflection image; generating an updated velocity model based at least on the relative dip angle; and generating an updated reflection image based at least on the updated velocity model.
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
A downhole signal generation system may include a main housing, a spring, and a valve plug configured to move along a central bore of the main housing between an open position and a closed position to selectively block fluid flow through the main housing. The downhole signal generation system may further include a ball housing insert with a ball slot and a ball release collar disposed about the ball housing insert. The downhole signal generation system may also include a latching feature configured to secure the valve plug to the ball housing insert with the ball release collar in a holding position, and to release the valve plug in response to the ball release collar moving to the release position. Moreover, the spring may be configured to drive the valve plug from the open position to the closed position in response to the latching feature releasing the valve plug.
E21B 47/18 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling using acoustic waves through the well fluid
E21B 34/14 - Valve arrangements for boreholes or wells in wells operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools
31.
Electromagnetic Waves Resistivity Computation Using Accelerated Segmented Lookup Table
A method for well logging may comprise: inserting a downhole tool into a wellbore penetrating a subterranean formation wherein the downhole tool comprises: a transmitter; a receiver; a memory configured to store at least one look up table with polynomial coefficients; and a processor coupled to the memory; obtaining a measurement using the resistivity tool; and generating a resistivity output using the measurement as an input to a polynomial with polynomial coefficients sourced from the look up table.
G01V 3/38 - Processing data, e.g. for analysis, for interpretation or for correction
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 47/18 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling using acoustic waves through the well fluid
E21B 49/00 - 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 3/30 - 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
32.
METHODS AND APPARATUS TO DECOUPLE DOWNHOLE TOOL SPEED FROM CONVEYANCE TOOLS
Wellbore logging apparatus include a positioning mechanism that couples one or more well logging devices included in a well logging tool to a downhole tractor. The positioning tool allows the logging tools to be moved at a different rate of travel through a wellbore compared to the rate of travel of the downhole tractor through the wellbore.
E21B 23/00 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells
E21B 47/12 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
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 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
E21B 41/00 - Equipment or details not covered by groups
33.
WELL SYSTEM ELECTRICAL SUBMERSIBLE PUMP EQUIPMENT FAILURE ANALYSIS
Techniques for electrical submersible pump equipment fault analysis include training, using first training data, one or more machine learning models to categorize previously unseen images of electrical submersible pump equipment into one or more categories of a plurality of categories. The techniques further include training, using second training data, the one or more machine learning models to generate captions for the previously unseen images of electrical submersible pump equipment.
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.
Provided is a test gravel pack assembly. The test gravel pack assembly, in one instance, includes a housing having first and second opposing surfaces, the first and second opposing surfaces defining a thickness that simulates a desired downhole gravel pack thickness. In this instance, the test gravel pack assembly includes an opening extending entirely through the housing from the first surface to the second surface, the opening having a diameter that simulates a desired downhole wellbore casing perforation diameter, and a proppant screen coupled proximate the first opposing surface and over the opening.
Techniques for electrical submersible pump equipment fault analysis include training, using first training data, one or more machine learning models to categorize previously unseen images of electrical submersible pump equipment into one or more categories of a plurality of categories. The techniques further include training, using second training data, the one or more machine learning models to generate captions for the previously unseen images of electrical submersible pump equipment.
01 - Chemical and biological materials for industrial, scientific and agricultural use
Goods & Services
Chemical compositions for use in oil and gas wells; thixotropic polymer sealant compositions for conformance control, water and gas shut‑off, zonal isolation, and fluid‑loss control.
38.
Systems and methods for separating and storing downhole debris
A debris separation and storage (“SAS”) apparatus for removing debris from a wellbore, the SAS apparatus including a chamber that includes a housing and an inlet tube located within the housing. The inlet tube includes a plurality of exit apertures positioned along the length of the inlet tube and configured to allow flow of a debris slurry, within the wellbore, from the inlet tube into an SAS area outside of the inlet tube. The chamber also includes a plurality of filter tubes located within the SAS area and oriented parallel to and radially outward from the inlet tube. The filter tubes are configured to block debris larger than a predetermined size of debris from flowing into the filter tubes while allowing the remaining fluid from the debris slurry to pass through the plurality of filter tubes and then out of the chamber, thereby producing a processed debris slurry.
E21B 37/00 - Methods or apparatus for cleaning boreholes or wells
B01D 29/11 - Filters with filtering elements stationary during filtration, e.g. pressure or suction filters, not covered by groups Filtering elements therefor with bag, cage, hose, tube, sleeve or like filtering elements
B01D 29/52 - Filters with filtering elements stationary during filtration, e.g. pressure or suction filters, not covered by groups Filtering elements therefor with multiple filtering elements, characterised by their mutual disposition in parallel connection
B01D 29/58 - Filters with filtering elements stationary during filtration, e.g. pressure or suction filters, not covered by groups Filtering elements therefor with multiple filtering elements, characterised by their mutual disposition in series connection arranged concentrically or coaxially
B01D 29/90 - Filters with filtering elements stationary during filtration, e.g. pressure or suction filters, not covered by groups Filtering elements therefor having feed or discharge devices for feeding
E21B 21/00 - Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
E21B 27/00 - Containers for collecting or depositing substances in boreholes or wells, e.g. bailers for collecting mud or sandDrill bits with means for collecting substances, e.g. valve drill bits
E21B 27/04 - Containers for collecting or depositing substances in boreholes or wells, e.g. bailers for collecting mud or sandDrill bits with means for collecting substances, e.g. valve drill bits where the collecting or depositing means include helical conveying means
E21B 43/38 - Arrangements for separating materials produced by the well in the well
A variety of methods, compositions, apparatuses, and systems are disclosed, including, in one embodiment, a technique of hydraulic fracturing involving providing a fracturing fluid having capsules containing a demulsifier through a wellbore into a subterranean formation and hydraulically fracturing the subterranean formation with the fracturing fluid, wherein the fracturing fluid forms an emulsion in the subterranean formation. The technique includes releasing the demulsifier from the capsules in the subterranean formation, breaking the emulsion in the subterranean formation with the demulsifier released by the capsules, and flowing the fracturing fluid as flowback from the subterranean formation through the wellbore to surface after and/or during the breaking of the emulsion.
A method or system comprising: disposing an acoustic logging tool into a borehole, wherein the acoustic logging tool is configured to: transmit one or more acoustic waves into the borehole with one or more transmitters; and receive one or more waveforms from the borehole or surrounding casing with an array of receivers. In addition, the method ay also comprise an information handling system configured to predict one or more waveforms at a shifted position with two waveforms recorded at an in-line position to form one or more predicted waveforms at a shifted position; and compare the one or more predicted waveforms at a shifted position with at least one or more waveforms recorded at a shifted position to yield a borehole mud attenuation and/or velocity.
Systems, methods, and apparatus, including computer programs encoded on computer-readable media, for determining subsurface formation boundary information for a wellbore using a well drilling system. Primary boundary information for a formation bed boundary of a subsurface formation may be determined based on primary measurement data. Secondary measurement data may be obtained from one or more sensors of the well drilling system. The primary boundary information may be corrected using the secondary measurement data to determine corrected boundary information for the formation bed boundary of the subsurface formation. An uncertainty may be determined for the corrected boundary information. A drilling operation or a drilling attribute in the wellbore may be modified based on the corrected boundary information and the uncertainty.
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, methods, and apparatus, including computer programs encoded on computer-readable media, for determining subsurface formation boundary information for a wellbore using a well drilling system. Primary boundary information for a formation bed boundary of a subsurface formation may be determined based on primary measurement data. Secondary measurement data may be obtained from one or more sensors of the well drilling system. The primary boundary information may be corrected using the secondary measurement data to determine corrected boundary information for the formation bed boundary of the subsurface formation. An uncertainty may be determined for the corrected boundary information. A drilling operation or a drilling attribute in the wellbore may be modified based on the corrected boundary information and the uncertainty.
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 method or system comprising: disposing an acoustic logging tool into a borehole, wherein the acoustic logging tool is configured to: transmit one or more acoustic waves into the borehole with one or more transmitters; and receive one or more waveforms from the borehole or surrounding casing with an array of receivers. In addition, the method ay also comprise an information handling system configured to predict one or more waveforms at a shifted position with two waveforms recorded at an in-line position to form one or more predicted waveforms at a shifted position; and compare the one or more predicted waveforms at a shifted position with at least one or more waveforms recorded at a shifted position to yield a borehole mud attenuation and/or velocity.
E21B 47/005 - Monitoring or checking of cementation quality or level
E21B 47/20 - 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 modulation of mud waves, e.g. by continuous modulation
A variety of methods, systems, and apparatus are disclosed, including, in one embodiment, a valve system comprising: a valve; and a valve actuation assembly comprising: a linear motion actuator configured to move linearly; a cable coupled to the linear motion actuator; and a shaft coupled to the cable, wherein the cable extends from the linear motion actuator to the shaft, wherein the shaft is configured to rotate and actuate the valve in response to linear movement of the linear motion actuator.
F16K 5/06 - Taps or cocks comprising only cut-off apparatus having at least one of the sealing faces shaped as a more or less complete surface of a solid of revolution, the opening and closing movement being predominantly rotary with plugs having spherical surfacesPackings therefor
A method comprises obtaining, via one or more sensors positioned in a wellbore formed in a subsurface formation, a full spectrum of the subsurface formation at a first depth, wherein the full spectrum is decomposed into peak components and continuum background components. The method comprises identifying one or more elements based on the peak components. The method comprises modifying a generalized set of elemental standards to generate a constrained set of elemental standards based on the one or more elements. The method comprises performing a fitting of the full spectrum to the constrained set of elemental standards to determine an elemental composition at the first depth of the subsurface formation.
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
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 variety of methods, compositions, apparatuses, and systems are disclosed, including, in one embodiment, a technique of hydraulic fracturing involving providing a fracturing fluid having capsules containing a demulsifier through a wellbore into a subterranean formation and hydraulically fracturing the subterranean formation with the fracturing fluid, wherein the fracturing fluid forms an emulsion in the subterranean formation. The technique includes releasing the demulsifier from the capsules in the subterranean formation, breaking the emulsion in the subterranean formation with the demulsifier released by the capsules, and flowing the fracturing fluid as flowback from the subterranean formation through the wellbore to surface after and/or during the breaking of the emulsion.
A reservoir fluid can be produced from a subterranean formation. The reservoir fluid can include water and hydrocarbons such as oil. It is oftentimes desirable to limit the amount of water that is produced, so a higher ratio of hydrocarbons can be produced. Portions of the subterranean formation can have an initial permeability to water. A relative permeability modifier (RPM) package including a surfactant and a polymer can be used in these portions to restrict or prevent water from being produced. The relative permeability modifier package can increase the hydrophobicity of the portion that allows the hydrocarbons to flow through while substantially limiting the amount of water. The relative permeability modifier can coat the surfaces of substances in the formation whereby the permeability to an aqueous fluid is reduced from the initial permeability. The formation can be a high-temperature formation of 230° F. (110.0° C.) or greater.
Daily reports from borehole or reservoir operations can be in various languages, use various sets of activity codes, be missing activity codes, or specify incorrect activity codes. By training a natural language model on a human language and then training the model on borehole and reservoir specific operations, activities, events, and occurrences, the original daily report can be transformed into a standardized daily report. The standardized daily report can use a standard set of activity codes from the client, operator, reference, industry standards, or a combination thereof. This can reduce the time to process a received daily report from days or weeks to a few minutes of processing time. Decision makers can then use the standardized daily report to make faster and more accurate decisions regarding the operations at the borehole or reservoir, such ordering replacement parts sooner or modifying a borehole operation plan.
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 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 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
50.
METHOD FOR UNBIASED ESTIMATION OF INDIVIDUAL METAL THICKNESS OF A PLURALITY OF CASING STRINGS
A method for estimating metal thickness on a plurality of casing strings in a cased hole may comprise obtaining a multi-channel induction measurement using a casing inspection tool, constructing a forward numerical model of the multi-channel induction measurement, using the forward numerical model in an initial guess estimation algorithm to estimate a first set of metal thicknesses of the plurality of casing strings, wherein the initial guess estimation algorithm places bounds on the metal thicknesses, using the forward numerical model in an inversion scheme to estimate a final set of metal thicknesses, wherein the first set of metal thicknesses are one or more initial guesses for the inversion scheme and the inversion scheme places no bounds on the metal thicknesses. A system may comprise an electromagnetic logging tool and a conveyance. The EM logging tool may further comprise a transmitter and a receiver.
G05B 13/04 - Adaptive control systems, i.e. systems automatically adjusting themselves to have a performance which is optimum according to some preassigned criterion electric involving the use of models or simulators
E21B 47/08 - Measuring diameters or related dimensions at the borehole
G01B 7/06 - Measuring arrangements characterised by the use of electric or magnetic techniques for measuring length, width, or thickness for measuring thickness
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
G01V 3/38 - Processing data, e.g. for analysis, for interpretation or for correction
51.
STABILIZER INCLUDING MODIFIED HELICAL WELLBORE STABILIZING ELEMENTS
Provided is a stabilizer for use in a wellbore. The stabilizer, in one example, includes a downhole tubular coupleable to a downhole conveyance in a wellbore. In accordance with this example, the stabilizer additionally includes two or more helical wellbore stabilizing elements extending radially outward from the downhole component, the two or more helical wellbore stabilizing elements shaped such that an annular flow area between leading edges of adjacent helical wellbore stabilizing elements and between trailing edges of adjacent helical wellbore stabilizing elements is variable along at least a portion of a length (L) of the two or more helical wellbore stabilizing elements, and such that an unobstructed axial flow path exists between the adjacent helical wellbore stabilizing elements along the length (L).
The system, in one aspect, includes a first bulk storage container for holding a first bulk dry flowable material having a first dispensing assembly coupled with a first outlet, and a second bulk storage container for holding a second bulk dry flowable material having a second dispensing assembly coupled with the second outlet. The system, in one aspect, may further include a mixed storage vessel, as well as a controller in communication with the first dispensing assembly and the second dispensing assembly, the controller programmed to cause the first dispensing assembly to discharge the first amount of the first dry flowable material to the mixed storage vessel and cause the second dispensing assembly to discharge the second amount of the second dry flowable material to the mixed storage vessel over a comparable time period based upon weight based readings the controller receives from first and second load cells.
Provided is a latch coupling, a well system, and a method for forming a well system. The latch coupling, in one aspect, includes a housing having an outside diameter (OD) and an inside diameter (ID). The latch coupling, according to this aspect, further includes a plurality of axial alignment slots located along the inside diameter (ID) of the housing, wherein a width (WAS) of each of the plurality of axial alignment slots is within 10% of each other.
E21B 23/02 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for locking the tools or the like in landing nipples or in recesses between adjacent sections of tubing
E21B 17/046 - CouplingsJoints between rod and bit, or between rod and rod with ribs, pins, or jaws, and complementary grooves or the like, e.g. bayonet catches
E21B 23/01 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for anchoring the tools or the like
E21B 23/03 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for setting the tools into, or removing the tools from, laterally offset landing nipples or pockets
E21B 23/06 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for setting packers
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
Daily reports from borehole or reservoir operations can be in various languages, use various sets of activity codes, be missing activity codes, or specify incorrect activity codes. By training a natural language model on a human language and then training the model on borehole and reservoir specific operations, activities, events, and occurrences, the original daily report can be transformed into a standardized daily report. The standardized daily report can use a standard set of activity codes from the client, operator, reference, industry standards, or a combination thereof. This can reduce the time to process a received daily report from days or weeks to a few minutes of processing time. Decision makers can then use the standardized daily report to make faster and more accurate decisions regarding the operations at the borehole or reservoir, such ordering replacement parts sooner or modifying a borehole operation plan.
Disclosed herein are methods and systems for treating geothermal wells. The methods include introducing a treatment fluid into a wellbore of a geothermal well having geothermal scale, contacting the geothermal scale with the treatment fluid, and removing at least a portion of the geothermal scale from the geothermal well using the treatment fluid. The treatment fluid comprises an ester, a fluoride-containing source, and a base fluid, wherein a molar ratio of fluoride-containing source to ester is about 1:1 to about 5:1. The methods may also be applied to matrix acidizing.
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
C02F 5/10 - Treatment of water with complexing chemicals or other solubilising agents for softening, scale prevention or scale removal, e.g. adding sequestering agents using organic substances
E21B 43/28 - Dissolving minerals other than hydrocarbons, e.g. by an alkaline or acid leaching agent
57.
PROFILE IDENTIFICATION FOR DOWNHOLE POSITIONING USING NON-CONTACTING ULTRASONIC WAVES
Described herein are systems and techniques for improving deployment accuracies of wellbore tools. Systems and techniques of the present disclosure may transmit acoustic waves and sense reflections of those acoustic waves as a tool is deployed in a wellbore. Data associated with the sensed acoustic waves may be analyzed to identify features of the wellbore that correspond to specific locations of the wellbore. The location and/or velocity of the tool may be monitored when the tool is deployed. Deployment of the tool may be controlled until the tool reaches a target wellbore location. Once the tool is located at the target wellbore location, data from the tool or commands sent via the tool may be used to control one or more pieces of wellbore equipment such that the wellbore can be managed according to wellbore management requirements.
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
An electric submersible pump includes a heat exchanger, a shaft comprising an axial bore, and a motor, which includes a rotor rotationally coupled to the shaft, a stator concentrically disposed with respect to the rotor, and a journal bearing disposed between the stator and the shaft. There is a gap between the rotor and the stator. The electric submersible pump further includes a first pump mechanically coupled to the shaft and configured to pump production fluid through a tubular, and a second pump mechanically coupled to the shaft and configured to pump coolant through the axial bore, the gap, and the heat exchanger. The heat exchanger transfers heat from the coolant to the production fluid to cool the motor.
An acidizing fluid, such as for matrix acidizing or fracture-acidizing a subterranean zone, the acidizing treatment fluid comprising: an acid; an aqueous base fluid; a gelling agent; and a foaming stabilizing agent, wherein the foaming stabilizing agent comprises an antimony-containing compound. The acidizing fluid can further include a foaming agent. Methods of making and utilizing the acidizing fluid are also provided.
An ultrasonic transducer for use in a downhole wellbore environment is disclosed. The ultrasonic transducer can utilize a piezoelectric element located in a housing comprising an inner housing and an outer housing separated by an air gap. The air gap functions to block undesirable ultrasonic waves from exiting or being received by the ultrasonic receiver and resulting in signal noise. For example, the air gap can prevent ultrasonic waves generated by the piezoelectric element from exiting the housing through a side or rear thereof, and can prevent reflected ultrasonic waves from being received by the ultrasonic transducer through a side or rear of the housing. The air gap may contain a gas or a fluid, or the air gap may be evacuated. The ultrasonic transducer may be a component of a downhole tool, such as a logging-while-drilling tool, or a post-drilling operation tool, such as a wireline tool.
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
B06B 1/06 - Processes or apparatus for generating mechanical vibrations of infrasonic, sonic or ultrasonic frequency making use of electrical energy operating with piezoelectric effect or with electrostriction
E21B 47/005 - Monitoring or checking of cementation quality or level
61.
METHOD OF USING DEGRADABLE GLASS FIBERS FOR DOWNHOLE TOOLS
A method for removing a downhole tool may include: contacting a downhole tool with a fluid having a pH of greater than 7, wherein the downhole tool comprises a composite of a polymer matrix reinforced with degradable glass fibers; and degrading the degradable glass fibers using the fluid having a pH of greater than 7.
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
Provided in one example is a coupling member, a downhole tool, and a well system. The coupling member, in one aspect, includes an axial tension member portion, and a first shear member portion, the first shear member portion having a first shear member shoulder extending from a first end of the axial tension member portion, the first shear member shoulder configured to engage with an opposing head member shoulder to axially fix the axial tension member portion relative to the head member. The coupling member, according to one aspect, includes a second shear member portion, the second shear member portion have a second shear member shoulder extending from a second opposing end of the axial tension member portion, the second shear member shoulder configured to engage with an opposing base member shoulder to axially fix the axial tension member portion relative to the base member.
An apparatus comprises one or more high temperature superconducting cables configured to supply power from surface to a bottom hole assembly positioned in a wellbore while drilling the wellbore in a subsurface formation. The apparatus comprises one or more cryogenic liquid supply channels positioned within the one or more high temperature superconducting cables, wherein fluid is pumped, via one or more cryogenic pumps, into the one or more cryogenic liquid supply channels to keep a temperature of the one or more high temperature superconducting cables below a critical temperature.
H01B 12/02 - Superconductive or hyperconductive conductors, cables or transmission lines characterised by their form
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 method and/or system comprising disposing a logging tool into a borehole, wherein the logging tool comprises: a transmitter configured to transmit a sonic pulse into a borehole; and one or more receivers configured to detect reflected sonic pulses as measured sonic data. Further, the method and/or system may be further comprise forming a correlation between the measured sonic data and one measurement from the sonic data and the one or more drilling parameters; and predicting sonic data at a bit with the correlation and one or more drilling parameters. In addition to acoustics the method and/or system maya downhole transmitter configured to transmit a particle and/or wave into the borehole and observe a response from the particle and/or wave, wherein the response is a reflection of or an effect of the particle and/or wave within the borehole or within a formation surrounding the borehole.
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 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.
LOW-NOISE ULTRASONIC TRANSDUCER FOR USE IN WELLBORE OPERATIONS
An ultrasonic transducer for use in a downhole wellbore environment is disclosed. The ultrasonic transducer can utilize a piezoelectric element located in a housing comprising an inner housing and an outer housing separated by an air gap. The air gap functions to block undesirable ultrasonic waves from exiting or being received by the ultrasonic receiver and resulting in signal noise. For example, the air gap can prevent ultrasonic waves generated by the piezoelectric element from exiting the housing through a side or rear thereof, and can prevent reflected ultrasonic waves from being received by the ultrasonic transducer through a side or rear of the housing. The air gap may contain a gas or a fluid, or the air gap may be evacuated. The ultrasonic transducer may be a component of a downhole tool, such as a logging-while-drilling tool, or a post-drilling operation tool, such as a wireline tool.
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 1/16 - Receiving elements for seismic signalsArrangements or adaptations of receiving elements
Described herein are systems and techniques for improving deployment accuracies of wellbore tools. Systems and techniques of the present disclosure may transmit acoustic waves and sense reflections of those acoustic waves as a tool is deployed in a wellbore. Data associated with the sensed acoustic waves may be analyzed to identify features of the wellbore that correspond to specific locations of the wellbore. The location and/or velocity of the tool may be monitored when the tool is deployed. Deployment of the tool may be controlled until the tool reaches a target wellbore location. Once the tool is located at the target wellbore location, data from the tool or commands sent via the tool may be used to control one or more pieces of wellbore equipment such that the wellbore can be managed according to wellbore management requirements.
An apparatus comprises one or more high temperature superconducting cables configured to supply power from surface to a bottom hole assembly positioned in a wellbore while drilling the wellbore in a subsurface formation. The apparatus comprises one or more cryogenic liquid supply channels positioned within the one or more high temperature superconducting cables, wherein fluid is pumped, via one or more cryogenic pumps, into the one or more cryogenic liquid supply channels to keep a temperature of the one or more high temperature superconducting cables below a critical temperature.
E21B 7/15 - Drilling by use of heat, e.g. flame drilling of electrically generated heat
F04B 37/08 - Pumps specially adapted for elastic fluids and having pertinent characteristics not provided for in, or of interest apart from, groups for evacuating by thermal means by condensing or freezing, e.g. cryogenic pumps
H01B 12/16 - Superconductive or hyperconductive conductors, cables or transmission lines characterised by cooling
A method and/or system comprising disposing a logging tool into a borehole, wherein the logging tool comprises: a transmitter configured to transmit a sonic pulse into a borehole; and one or more receivers configured to detect reflected sonic pulses as measured sonic data. Further, the method and/or system may be further comprise forming a correlation between the measured sonic data and one measurement from the sonic data and the one or more drilling parameters; and predicting sonic data at a bit with the correlation and one or more drilling parameters. In addition to acoustics the method and/or system maya downhole transmitter configured to transmit a particle and/or wave into the borehole and observe a response from the particle and/or wave, wherein the response is a reflection of or an effect of the particle and/or wave within the borehole or within a formation surrounding the borehole.
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
E21B 47/085 - Measuring diameters or related dimensions at the borehole using radiant means, e.g. acoustic, radioactive or electromagnetic
69.
DETERMINATION OF MINERALOGY AND LITHOLOGY FROM ELEMENTAL DATA
Disclosed herein are methods and systems for determining downhole formation lithology after calculating the mineralogy of the formation based on acquired elemental data in a specific order. More specifically, the elemental data may be acquired using a downhole geological tool. The elemental data are then used to calculate the formation minerals, which, in combination, are then used to determine the formation lithology classifications.
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
G01V 11/00 - Prospecting or detecting by methods combining techniques covered by two or more of main groups
70.
METHOD OF USING DEGRADABLE GLASS FIBERS FOR DOWNHOLE TOOLS
A method for removing a downhole tool may include: contacting a downhole tool with a fluid having a pH of greater than 7, wherein the downhole tool comprises a composite of a polymer matrix reinforced with degradable glass fibers; and degrading the degradable glass fibers using the fluid having a pH of greater than 7.
E21B 29/02 - Cutting or destroying pipes, packers, plugs or wire lines, located in boreholes or wells, e.g. cutting of damaged pipes, of windowsDeforming of pipes in boreholes or wellsReconditioning of well casings while in the ground by explosives or by thermal or chemical means
C08J 5/24 - Impregnating materials with prepolymers which can be polymerised in situ, e.g. manufacture of prepregs
71.
Downhole wet mate connection system for wellbore tools
A wet mate connection system can be provided for suppling power to a wellbore tool. For example, the wet mate connection system can be positioned downhole in the wellbore. The wet mate connection system can further be electrically coupled with a valve. The wet mate connection system can include a first wet mate connector and a second wet mate connector. The second wet mate connector can be coupled with the first wet mate connector and with the valve. Additionally, the wet mate connection system can include one or more electrical contacts between the first wet mate connector and the second wet mate connector.
Various seals for wellbore systems include a partially bonded seal configured to be actuatable to provide a fluid seal between a first conduit and a second conduit positioned within a wellbore. The partially bonded seal may comprise a hanger body and a sealing element, the sealing element positioned in contact with and arranged to encircle an outer surface of the hanger body for some longitudinal distance along the hanger body. A first portion of the sealing element adjacent to the outer surface of the hanger is bonded to the outer surface of the hanger body, and a second portion of the sealing element adjacent to the outer surface of the hanger body is not bonded to the outer surface of the hanger body.
Aspects of the subject technology relate to systems, methods, and computer readable media for estimating acoustic spectra. Acoustic data can be received at a hydrophone array from a first acoustic source and a second acoustic source in a downhole environment. An initial noise spatial correlation matrix estimation can be generated based on the acoustic data. The initial noise spatial correlation matrix estimation can be applied to a beamformer to generate a first source spectra estimation for the first acoustic source and the second acoustic source. A revised noise spatial correlation matrix estimation can be generated based on the first source spectra estimation. The revised noise spatial correlation matrix estimation can be applied to the beamformer to generate a second source spectra estimation for the first acoustic source and the second acoustic source in the downhole environment based on the first source spectra estimation.
A system and a method for a pulsed neutron logging tool. The pulsed neutron logging tool may include a pulsed neutron generator for generating one or more neutrons, one or more gamma ray scintillator detectors disposed in a detection area, a shielding block that separates the pulsed neutron generator from the one or more gamma ray scintillator detectors, and a shielding layer. The pulsed neutron logging tool may further comprise an information handling system communicatively connected at least in part to the pulsed neutron logging tool. The information handling system is configured to create a gamma ray spectrum from the one or more gamma rays detected by the one or more gamma ray scintillator detectors, remove a background from the gamma ray spectrum to form a peaks-only spectrum, and compare one or more peaks-only elemental standards to the peaks-only spectrum to determine an elemental weight and yield.
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
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
A swellable packer includes a base conduit, a reinforcement element disposed annularly about the base conduit, that includes an annular section, a stabilizing foot to stabilize the annular section relative to the base conduit, and a swellable material annularly disposed outside the base conduit and in contact with the reinforcement element.
Aspects of the subject technology relate to systems, methods, and computer readable media for determining or identifying one or more vibrational modes and corresponding severities experienced by a drilling system operating within a wellbore. Vibrational data comprising vibrational measurements of a vibrational mode is obtained from a component of a drilling assembly while the component is in a wellbore and performing one or more drilling operations. Cumulative vibrational information of the vibrational mode is determined based on the vibrational measurements, the cumulative vibrational information identifying and characterizing, for each of a plurality of instances during a time interval an accumulated severity of the vibrational mode. One or more drilling parameters of the drilling assembly is adjusted based on the cumulative vibrational information.
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
G01V 1/40 - SeismologySeismic or acoustic prospecting or detecting specially adapted for well-logging
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
77.
APPARATUS TO CONNECT CABLES INSIDE COILED TUBING AND CONNECT COILED TUBING
A coiled tubing system includes sections of coiled tubing that include an electrical cable and at least one electrical male wet stab connector. Each male connector includes a male fluid pathway and secures a section of electrical cable such that the electrical cable is isolated from the male fluid pathway. The system also includes a female tubing crossover configured to connect two sections of coiled tubing and including a female fluid pathway and electrical female wet stab connectors. The female connectors are each configured to receive a respective male connector to establish an electrical connection with the electrical cables that is isolated from the female fluid pathway. Each respective male fluid pathway and the female fluid pathway are in fluid communication when the female tubing crossover is connecting two sections of the coiled tubing to provide fluid communication between the sections of coiled tubing.
An electric submersible pump includes a shaft, a motor mechanically coupled to the shaft, and an impeller rotationally coupled to the shaft. The impeller includes a first hub and a first shroud. The first shroud is concentrically disposed about the first hub and has a first axial end and a second axial end. The second axial end is disposed radially outward with respect to the first axial end. A slope of an interior surface of the first shroud proximate the second axial end is within 20 degrees of being parallel to a longitudinal axis of the shaft. The impeller further includes first vanes extending from the first hub to the first shroud. The electric submersible pump further includes a diffuser fluidly coupled to the impeller. The diffuser includes a second hub, a second shroud concentrically disposed about the second hub, and second vanes extending from the second hub to the second shroud.
Treatment fluids and methods for performing a consolidation operation. An example treatment fluid includes an aqueous base fluid, a furfuryl alcohol monomer, a delayed-release acid activator, an oil-wetting surfactant, and a silane coupling agent. A particulate and/or a target area of a subterranean formation is contacted with the treatment fluid to consolidate the particulate and/or target area of the formation.
Aspects of the subject technology relate to systems, methods, and computer readable media for estimating acoustic spectra. Acoustic data can be received at a hydrophone array from a first acoustic source and a second acoustic source in a downhole environment. An initial noise spatial correlation matrix estimation can be generated based on the acoustic data. The initial noise spatial correlation matrix estimation can be applied to a beamformer to generate a first source spectra estimation for the first acoustic source and the second acoustic source. A revised noise spatial correlation matrix estimation can be generated based on the first source spectra estimation. The revised noise spatial correlation matrix estimation can be applied to the beamformer to generate a second source spectra estimation for the first acoustic source and the second acoustic source in the downhole environment based on the first source spectra estimation.
Treatment fluids and methods for performing a consolidation operation. An example treatment fluid includes an aqueous base fluid, a furfuryl alcohol monomer, a delayed-release acid activator, an oil-wetting surfactant, and a silane coupling agent. A particulate and/or a target area of a subterranean formation is contacted with the treatment fluid to consolidate the particulate and/or target area of the formation.
An electric submersible pump includes a heat exchanger, a shaft comprising an axial bore, and a motor, which includes a rotor rotationally coupled to the shaft, a stator concentrically disposed with respect to the rotor, and a journal bearing disposed between the stator and the shaft. There is a gap between the rotor and the stator. The electric submersible pump further includes a first pump mechanically coupled to the shaft and configured to pump production fluid through a tubular, and a second pump mechanically coupled to the shaft and configured to pump coolant through the axial bore, the gap, and the heat exchanger. The heat exchanger transfers heat from the coolant to the production fluid to cool the motor.
E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
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 36/00 - Heating, cooling or insulating arrangements for boreholes or wells, e.g. for use in permafrost zones
H02K 9/19 - Arrangements for cooling or ventilating for machines with closed casing and closed-circuit cooling using a liquid cooling medium, e.g. oil
83.
Acidizing Fluid with Foam Stabilizing Agent Comprising Antimony Compound
An acidizing fluid, such as for matrix acidizing or fracture-acidizing a subterranean zone, the acidizing treatment fluid comprising: an acid; an aqueous base fluid; a gelling agent; and a foaming stabilizing agent, wherein the foaming stabilizing agent comprises an antimony-containing compound. The acidizing fluid can further include a foaming agent. Methods of making and utilizing the acidizing fluid are also provided.
Systems and methods of the present disclosure relate to creating seals that expand during temperature drops. The seals may include a negative CTE material that is either internal or external to the sealing element; shape memory alloys (SMA) which exhibit negative CTE during a phase change; and/or external lattice structures with positive CTE components but negative overall CTE.
A coiled tubing system includes sections of coiled tubing that include an electrical cable and at least one electrical male wet stab connector. Each male connector includes a male fluid pathway and secures a section of electrical cable such that the electrical cable is isolated from the male fluid pathway. The system also includes a female tubing crossover configured to connect two sections of coiled tubing and including a female fluid pathway and electrical female wet stab connectors. The female connectors are each configured to receive a respective male connector to establish an electrical connection with the electrical cables that is isolated from the female fluid pathway. Each respective male fluid pathway and the female fluid pathway are in fluid communication when the female tubing crossover is connecting two sections of the coiled tubing to provide fluid communication between the sections of coiled tubing.
A hydraulic fracturing system and method identifies, for each of two or more segments of a hydraulic fracturing treatment applied downhole in a wellbore, at least one contributing factor that leads to a fracturing event during each respective segment, applies pattern recognition to fracturing data associated with one or more monitoring wells to identify at least one precursor for each of the contributing factors of a selected fracturing event, determines, based on the identified at least one precursor for each of the contributing factors of the selected fracturing event, whether the selected fracturing event is likely to occur in the wellbore.
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
E21B 43/26 - Methods for stimulating production by forming crevices or fractures
Provided in one example is a coupling member, a downhole tool, and a well system. The coupling member, in one aspect, includes an axial tension member portion, and a first shear member portion, the first shear member portion having a first shear member shoulder extending from a first end of the axial tension member portion, the first shear member shoulder configured to engage with an opposing head member shoulder to axially fix the axial tension member portion relative to the head member. The coupling member, according to one aspect, includes a second shear member portion, the second shear member portion have a second shear member shoulder extending from a second opposing end of the axial tension member portion, the second shear member shoulder configured to engage with an opposing base member shoulder to axially fix the axial tension member portion relative to the base member.
E21B 17/046 - CouplingsJoints between rod and bit, or between rod and rod with ribs, pins, or jaws, and complementary grooves or the like, e.g. bayonet catches
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 23/06 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for setting packers
E21B 33/128 - PackersPlugs with a member expanded radially by axial pressure
E21B 34/10 - Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole
89.
Intervention-less method of setting open hole packers
A hydraulic ratcheting device that includes an activation chamber, a valve chamber disposed adjacent to the activation chamber, and an activation piston that includes a first piston area exposed to a fluid source, and a second piston area exposed to the valve chamber, where the activation piston is configured to translate forward, in response to a pressure increase on the first piston area, and push a liquid from the valve chamber into the activation chamber using the second piston area.
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 23/06 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for setting packers
A filtercake breaker fluid can include a delayed acid and a viscosifier. The delayed acid can generate an acid downhole that breaks the filtercake. The viscosifier delays the breaking of the filtercake by the acid due to an increase in viscosity of the breaker fluid. The viscosifier can be a hydrophobically modified polymer or a viscoelastic surfactant.
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
C09K 8/52 - Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning
91.
FILTER CAKE REMOVAL COMPOSITIONS AND RELATED WELLBORE METHODS
Compositions and methods for removing a filter cake from a wellbore may use a breaker that comprises an ester-based acid precursor and a lactone. A treatment fluid may contain an aqueous fluid and the breaker. A method may include introducing the treatment fluid into the wellbore, contacting the filter cake in the wellbore with the treatment fluid, and removing at least a portion of the filter cake.
C09K 8/528 - Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning inorganic depositions, e.g. sulfates or carbonates
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
Methods and compositions for using lubricants in subterranean formations, and specifically lubricants that comprise certain solvents, surfactants and alcohols or alcohol ethoxylates, and methods for their use, are provided. In one embodiment, the methods include introducing a treatment fluid that includes a base fluid and a lubricant including a glycol component, an alcohol or alcohol ethoxylate component, and at least one nonionic surfactant into at least a portion of a subterranean formation.
C10M 105/14 - Lubricating compositions characterised by the base-material being a non-macromolecular organic compound containing oxygen having hydroxy groups bound to acyclic or cycloaliphatic carbon atoms polyhydroxy
C10M 129/40 - Carboxylic acidsSalts thereof having carboxyl groups bound to acyclic or cycloaliphatic carbon atoms having 8 or more carbon atoms monocarboxylic
C10M 129/46 - Carboxylic acidsSalts thereof having carboxyl groups bound to acyclic or cycloaliphatic carbon atoms cycloaliphatic
A method of servicing a wellbore penetrating a subterranean formation, the method comprising: preparing a wellbore servicing composition comprising: (a) core-shell particles comprising a core and a shell, wherein the shell wholly or partially surrounds the core, and wherein: (i) the core of each of the core-shell particles comprises a particle selected from an inorganic particle or an organic particle; and (ii) the shell comprises a polymer that is a polymerization product of one or more monomers and optionally one or more cross-linkers, wherein the one or more monomers include a thermally stable monomer, the one or more cross-linkers include a thermally stable cross-linker, or wherein the one or more monomers include the thermally stable monomer and the one or more cross-linkers include the thermally stable cross-linker; and (b) a carrier fluid; and placing the wellbore servicing composition into the wellbore, the subterranean formation or both.
Aspects of the subject technology relate to systems, methods, and computer readable media for determining or identifying one or more vibrational modes and corresponding severities experienced by a drilling system operating within a wellbore. Vibrational data comprising vibrational measurements of a vibrational mode is obtained from a component of a drilling assembly while the component is in a wellbore and performing one or more drilling operations. Cumulative vibrational information of the vibrational mode is determined based on the vibrational measurements, the cumulative vibrational information identifying and characterizing, for each of a plurality of instances during a time interval an accumulated severity of the vibrational mode. One or more drilling parameters of the drilling assembly is adjusted based on the cumulative vibrational information.
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 method of sealing a lost circulation zone may include: circulating a lost circulation treatment composition to a subterranean formation comprising a lost circulation zone, wherein the lost circulation treatment composition comprises: a carrier fluid; a polymeric additive; a fine particulate component; and a composite particulate component containing size and shape selected materials; wherein the cost circulation treatment composition has the property of allowing full volume passage through a 15,000 micron fracture width; flowing the lost circulation treatment composition into the lost circulation zone; and plugging the lost circulation zone using the lost circulation treatment composition.
E21B 21/00 - Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
E21B 21/08 - Controlling or monitoring pressure or flow of drilling fluid, e.g. automatic filling of boreholes, automatic control of bottom pressure
E21B 33/13 - Methods or devices for cementing, for plugging holes, crevices or the like
C09K 8/42 - Compositions for cementing, e.g. for cementing casings into boreholesCompositions for plugging, e.g. for killing wells
C09K 8/467 - Compositions for cementing, e.g. for cementing casings into boreholesCompositions for plugging, e.g. for killing wells containing inorganic binders, e.g. Portland cement containing additives for specific purposes
96.
FILTER CAKE REMOVAL COMPOSITIONS AND RELATED WELLBORE METHODS
Compositions and methods for removing a filter cake from a wellbore may use a breaker that comprises an ester-based acid precursor and a lactone. A treatment fluid may contain an aqueous fluid and the breaker. A method may include introducing the treatment fluid into the wellbore, contacting the filter cake in the wellbore with the treatment fluid, and removing at least a portion of the filter cake.
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 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
C09K 8/52 - Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning
C09K 8/86 - Compositions based on water or polar solvents containing organic compounds
Provided is a coiled tubing deployment/retrieval apparatus, a coiled tubing surface equipment spread, and a method. The coiled tubing deployment/retrieval apparatus, in one aspect, includes a frame, a coiled tubing guide coupled to the frame, and a coiled tubing injector coupled to the frame, the coiled tubing injector configured to insert or retrieve a coiled tubing string guided by the coiled tubing guide into or out of a wellbore. The coiled tubing deployment/retrieval apparatus, in one aspect, further includes a power cable injector coupled to the frame, the power cable injector configured to insert or retrieve a power cable into or out of the wellbore alongside the coiled tubing string.
Disclosed are systems, apparatuses, methods, and computer readable medium for estimating metal loss of a casing wall including: acquiring at least two electromagnetic measurement data sets that are taken at two or more different times; aligning one or more depths across the at least two electromagnetic measurement data sets; computing a thickness of a plurality of downhole pipes, which at least partially overlap, based upon an applied inversion algorithm to each of the at least two electromagnetic measurement data sets; determine a location of one or more metal loss locations based upon a change in thickness for a given one of the plurality of downhole pipes; estimating one or more parameters of metal loss based upon the applied inversion algorithm.
A method of sealing a lost circulation zone may include: circulating a lost circulation treatment composition to a subterranean formation comprising a lost circulation zone, wherein the lost circulation treatment composition comprises: a carrier fluid; a polymeric additive; a fine particulate component; and a composite particulate component containing size and shape selected materials; wherein the cost circulation treatment composition has the property of allowing full volume passage through a 15,000 micron fracture width; flowing the lost circulation treatment composition into the lost circulation zone; and plugging the lost circulation zone using the lost circulation treatment composition.
C04B 28/02 - Compositions of mortars, concrete or artificial stone, containing inorganic binders or the reaction product of an inorganic and an organic binder, e.g. polycarboxylate cements containing hydraulic cements other than calcium sulfates
C09K 8/42 - Compositions for cementing, e.g. for cementing casings into boreholesCompositions for plugging, e.g. for killing wells
E21B 21/00 - Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
E21B 33/138 - Plastering the borehole wallInjecting into the formation
100.
Integrated Pulsed Neutron Logging Tool for Spectroscopy and Porosity Measurements
A system and a method for a pulsed neutron logging tool. The pulsed neutron logging tool may include a pulsed neutron generator for generating one or more neutrons, one or more gamma ray scintillator detectors disposed in a detection area, a shielding block that separates the pulsed neutron generator from the one or more gamma ray scintillator detectors, and a shielding layer. The pulsed neutron logging tool may further comprise an information handling system communicatively connected at least in part to the pulsed neutron logging tool. The information handling system is configured to create a gamma ray spectrum from the one or more gamma rays detected by the one or more gamma ray scintillator detectors, remove a background from the gamma ray spectrum to form a peaks-only spectrum, and compare one or more peaks-only elemental standards to the peaks-only spectrum to determine an elemental weight and yield.
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 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
