A method includes initiating a managed pressure drilling (MPD) operation in an MPD system including a rotating control device (RCD) including at least one sealing element and a plurality of pressures sensors placed relative to the at least one sealing element. The RCD is positioned in the MPD system so as to receive fluid exiting an annulus of a wellbore. Further, the method includes creating a pressure spike in the annulus of the wellbore during the MPD operation, and monitoring a pressure differential between the plurality of pressure sensors to determine whether there is a leakage within the RCD.
A fluid displacement pump can include a rotor; and a stator, where the stator includes two materials bonded by a tie layer. A method can include providing materials; bonding two of the materials using another one of the materials as a tie layer to form a stator material; forming a stator of a pump using the stator material.
A technique facilitates application of increased force in various well applications while limiting the overall time period of the operation by automatically utilizing two modes of operation. In some well applications, the technique automatically applies increased force to facilitate shearing of a tubular product in a timely manner. By way of example, the system may be utilized to rapidly advance rams to the point of contact with the tubular product extending through well equipment, e.g. through a blowout preventer (BOP), and then to automatically shift to a slower advance but higher force mode. The higher force mode facilitates shearing of a variety of tubular products in a variety of well applications.
A method for correcting elemental yields obtained from gamma ray spectra includes acquiring a plurality of elemental yields corresponding to a plurality of time intervals; summing one of the plurality of elemental yields with an accumulated negative yield to compute a corrected yield; setting the accumulated negative yield to a minimum of zero and the computed corrected yield; resetting the corrected yield to a maximum of zero and the computed corrected yield; and repeating the summing, the setting, and the resetting, for each of the acquired plurality of elemental yields to compute a corresponding plurality of corrected elemental yields.
H04B 13/02 - Transmission systems in which the medium consists of the earth or a large mass of water thereon, e.g. earth telegraphy
E21B 47/13 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling by electromagnetic energy, e.g. of radio frequency range
G01S 11/06 - Systems for determining distance or velocity not using reflection or reradiation using radio waves using intensity measurements
G01V 5/10 - Prospecting or detecting by the use of nuclear radiation, e.g. of natural or induced radioactivity specially adapted for well-logging using primary nuclear radiation sources or X-rays using neutron sources
5.
DOWNHOLE INSTRUMENT ACQUISITION AND TELEMETRY SYSTEM
A method may include acquiring NMR data using a NMR unit disposed in a borehole in a formation, where the NMR data represent characteristics of the formation. The method may also include compressing the NMR data using projection followed by adaptive quantization to generate multiple, quantized data structures, where the adaptive quantization selects a gain value from a plurality of gain values. The method may further include transmitting the multiple, quantized data structures using borehole telemetry, where the multiple, quantized data structures include an indicator for the selected gain value.
G01V 3/32 - Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for well-logging operating with electron or nuclear magnetic resonance
G01V 3/28 - Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for well-logging operating with magnetic or electric fields produced or modified either by the surrounding earth formation or by the detecting device using induction coils
An apparatus and method of creating a window in a composite casing section. The composite casing section has a metallic casing, an indexing locator and a composite joint. The composite joint is positioned between the metallic casing and indexing locator. The indexing locator is configured to locate a departure device within the wellbore. The departure device directs the milling device to mill the window through the composite joint. A lateral wellbore is created after the window is milled through the composite joint.
E21B 29/00 - Cutting or destroying pipes, packers, plugs, or wire lines, located in boreholes or wells, e.g. cutting of damaged pipes, of windows; Deforming of pipes in boreholes or wells; Reconditioning of well casings while in the ground
E21B 17/04 - Couplings; Joints between rod and bit, or between rod and rod
E21B 33/14 - Methods or devices for cementing, for plugging holes, crevices, or the like for cementing casings into boreholes
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
A bridge racker includes a bridge crane, a vertical column connected to the bridge crane, an extender connected to the vertical column, and a tool connected to the extender. The tool is configured to hold a tubular and the extender is configured to adjust a horizontal offset between the vertical column and the tool.
A method for gain correcting a gamma ray spectrum includes acquiring a gamma ray spectrum including gamma ray counts distributed into a plurality of energy channels, evaluating the acquired gamma ray spectrum to determine an energy of a calibration feature therein, comparing the energy of the calibration feature in the acquired spectrum to a standard spectral energy to determine a deviation between the energy of the calibration feature and the standard spectral energy, and adjusting the acquired spectrum so that the energy of the calibration feature is equal to the standard spectral energy to obtain a gain calibrated spectrum.
G16C 20/10 - Analysis or design of chemical reactions, syntheses or processes
G01N 23/22 - Investigating or analysing materials by the use of wave or particle radiation, e.g. X-rays or neutrons, not covered by groups , or by measuring secondary emission from the material
9.
METHOD FOR ESTIMATING NET INELASTIC GAMMA RAY COUNTS
A method for estimating net inelastic gamma ray counts includes acquiring a burst gamma ray count measured during a neutron burst time interval, acquiring a capture gamma ray count measured during at least one neutron capture time interval, acquiring a neutron count during at least the neutron burst time interval, and subtracting a portion of the capture gamma ray count and a portion of the neutron count from the burst gamma ray count to estimate the net inelastic gamma ray count.
G16C 20/10 - Analysis or design of chemical reactions, syntheses or processes
G01N 23/22 - Investigating or analysing materials by the use of wave or particle radiation, e.g. X-rays or neutrons, not covered by groups , or by measuring secondary emission from the material
10.
DEVICES, SYSTEMS, AND METHODS FOR DOWNHOLE SURVEYING
A drilling system may include a steering tool configured to engage a wellbore wall to direct an orientation of a toolface, the steering tool being rotatable about a rotational axis. A drilling system may include an azimuth sensor package, the azimuth sensor package including at least one of a multi-axis gyroscopic azimuth sensor rotatable about the rotational axis of the steering tool, a multi-axis magnetic azimuth sensor rotatable about the rotational axis of the steering tool, or an accelerometer azimuth sensor rotatable about the rotational axis of the steering tool.
E21B 47/022 - Determining slope or direction of the borehole, e.g. using geomagnetism
G01V 3/18 - Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for well-logging
E21B 44/00 - Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systems; Systems specially adapted for monitoring a plurality of drilling variables or conditions
Techniques for controlling tortuosity of fluid flow through a subterranean formation include introducing a diversion fluid into a wellbore, introducing a first fluid into the wellbore, collecting a second fluid from the wellbore or a second wellbore, and recovering heat from the second fluid. Techniques for increasing the likelihood that a fluid will absorb heat as it flows through rock fractures include introducing a first fluid into a first wellbore, introducing a particulate fluid into the first wellbore, collecting a second fluid from a second wellbore, and recovering heat from the second fluid. Techniques for recovering heat from a subterranean formation include observing a first parameter of a first fluid introduced into a first wellbore, observing a second parameter of a second fluid collected from a second wellbore, recovering heat from the second fluid, and introducing a diversion fluid into the first wellbore.
A bridge racker includes a bridge crane, a vertical lifting assembly connected to the bridge crane and with access to a limited vertical range at the bridge crane, and a winch assembly connected to the bridge crane and with access to an entire vertical range between a drill floor and the bridge crane.
E21B 19/15 - Racking of rods in horizontal position; Handling between horizontal and vertical position
E21B 19/00 - Handling rods, casings, tubes or the like outside the borehole, e.g. in the derrick; Apparatus for feeding the rods or cables
E21B 19/20 - Combined feeding from rack and connecting, e.g. automatically
B66C 23/26 - Cranes comprising essentially a beam, boom or triangular structure acting as a cantilever and mounted for translatory or swinging movements in vertical or horizontal planes or a combination of such movements, e.g. jib cranes, derricks or tower cranes specially adapted for use in particular locations or for particular purposes constructed, e.g. with separable parts, to facilitate rapid assembly or dismantling, for operation at successively higher levels, for transport by road or rail
B66C 1/42 - Gripping members engaging only the external or internal surface of the articles
B66C 7/02 - Runways, tracks, or trackways for trolleys or cranes for underhung trolleys or cranes
B66C 11/16 - Rope, cable, or chain drives for trolleys; Combinations of such drives with hoisting gear
A method can include operating a field system using a first partition as an active partition and a second partition as a passive partition; responsive to receipt of a system update, changing a bootloader configuration from the first partition to the second partition; performing root of trust measurements for the update where the measurements account at least for the change in the bootloader configuration; responsive to establishing trust via the measurements, accessing an encryption key; decrypting, using the encryption key, at least the second partition for use by the system; and rebooting the field system using the second partition as an active partition and the first partition as a passive partition for a system rollback responsive to detection of a system update issue.
G06F 21/53 - Monitoring users, programs or devices to maintain the integrity of platforms, e.g. of processors, firmware or operating systems during program execution, e.g. stack integrity, buffer overflow or preventing unwanted data erasure by executing in a restricted environment, e.g. sandbox or secure virtual machine
G06F 21/57 - Certifying or maintaining trusted computer platforms, e.g. secure boots or power-downs, version controls, system software checks, secure updates or assessing vulnerabilities
G06F 21/71 - Protecting specific internal or peripheral components, in which the protection of a component leads to protection of the entire computer to assure secure computing or processing of information
G06F 21/00 - Security arrangements for protecting computers, components thereof, programs or data against unauthorised activity
14.
ELECTRIC ANNULAR BLOWOUT PREVENTER WITH RADIAL COMPRESSION OF PACKER
An annular blowout preventer includes an annular body including a central bore extending therethrough, a plurality of electric motors disposed circumferentially around the annular body, a packer assembly disposed within the annular body about the central bore, and a plurality of pusher plates disposed in the annular body, each pusher plate configured to radially engage the packer assembly. The packer assembly includes a packer element and a donut that circumferentially surrounds the packer element. The plurality of pusher plates is correspondingly connected to the plurality of electric motors via a connecting rod.
A shckline stuffing box includes one or more packer elements that are configured to compress axially and expand radially to seal around a slickline to contain a. pressure within a wellbore therebelow during a slickline wellbore intervention. The slickline stuffing box also includes a valve configured to be positioned below the one or more packer elements in a first configuration of the slickline stuffing box and above the one or more packer elements in a second configuration of the slickline stuffing box. The valve is configured to contain the pressure within the wellbore in response to the slickline breaking and falling down and out of the slickline stuffing box.
E21B 33/072 - Well heads; Setting-up thereof having provision for introducing objects or fluids into, or removing objects from, wells for cable-operated tools
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 34/14 - Valve arrangements for boreholes or wells in wells operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools
A slickline stuffing box includes a piston configured to move in response to a force exerted thereon by a pressurized fluid. The slickline stuffing box also includes a packer element positioned above the piston. The packer element is configured to compress axially and expand radially, in response to movement of the piston, to seal around a slickline to contain a pressure within a wellbore during a slickline wellbore intervention. The slickline stuffing box also includes a valve configured to be positioned below the packer element in a first configuration of the slickline stuffing box and above the packer element in a second configuration of the slickline stuffing box. The valve is configured to contain the pressure within the wellbore in response to the slickline breaking and falling down and out of the slickline stuffing box.
E21B 33/072 - Well heads; Setting-up thereof having provision for introducing objects or fluids into, or removing objects from, wells for cable-operated tools
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 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
An actuation assembly. The actuation assembly may include a housing, a mandrel disposed within the housing and shiftable within the housing to open and close an isolation valve, and a piston assembly disposed between the housing and the mandrel. The piston assembly may include a first hydraulic chamber fluidly couplable to a first trigger, a second hydraulic chamber fluidly couplable to the first trigger and a second trigger, a third hydraulic chamber fluidly couplable to the second trigger, a close collet piston positioned between the first hydraulic chamber and the second hydraulic chamber and close collet piston operable to shift the mandrel to close the isolation valve when the first trigger is activated, and an open collet piston positioned between the second hydraulic chamber and the third hydraulic chamber and open collet piston operable to shift the mandrel to open the isolation valve when the second trigger is activated.
E21B 34/14 - Valve arrangements for boreholes or wells in wells operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools
E21B 23/04 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells operated by fluid means, e.g. actuated by explosion
18.
CARBONATES CHARACTERIZATION VIA DIFFUSE REFLECTION INFRARED MEASUREMENT
A method can include irradiating a rock sample with infrared radiation from at least one radiation source; detecting infrared radiation reflected from the rock sample for two different wavelength bands using a photodetector; and, based on a comparison of the infrared radiation for the two different wavelength bands, using a processor, determining whether the rock sample includes carbonate.
G01N 21/31 - Investigating relative effect of material at wavelengths characteristic of specific elements or molecules, e.g. atomic absorption spectrometry
G01N 21/3563 - Investigating relative effect of material at wavelengths characteristic of specific elements or molecules, e.g. atomic absorption spectrometry using infrared light for analysing solids; Preparation of samples therefor
A method for estimating a formation gas concentration while drilling includes making first gas concentration measurements in drilling fluid as the drilling fluid exits a wellbore or second gas concentration measurements in drilling fluid before the drilling fluid is pumped into the wellbore while drilling the wellbore. The first gas concentration measurements or the second gas concentration measurements may be evaluated with a model to estimate the formation gas concentration.
A method for estimating surface concentrations of gas in a drilling fluid in use in a drilling rig includes measuring gas-out or gas-in concentrations while drilling a wellbore and processing the gas-out measurements or the gas-in measurements with a calibrated model to estimate corresponding gas-in concentrations or gas-out concentrations.
Embodiments presented provide for a method of monitoring emissions. A calibration of a metal oxide sensor is accomplished in order to monitor fugitive methane gas emissions on a consistent and constant basis.
A downhole valve assembly includes a safety valve and an actuator that opens and/or closes the valve. The actuator can be an electro-hydraulic actuator (EHA), an electro mechanical actuator (EMA), or an electro hydraulic pump (EHP). The downhole safety valve can also include an electric magnet. The electric magnet can act as or control a magnetic decoupling mechanism to control closure of the safety valve.
A method of forward modeling reservoir fluid geodynamics that accounts for both slow processes and fast processes. The method provides a model that accounts for the fluid geodynamics from charge to current time.
E21B 49/08 - Obtaining fluid samples or testing fluids, in boreholes or wells
E21B 49/02 - Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells by mechanically taking samples of the soil
A system for detecting hydrocarbons in a subterranean formation includes an outlet sensor configured to measure an outlet drilling fluid parameter of a drilling fluid. The system also includes an inlet sensor configured to measure an inlet drilling fluid parameter of the drilling fluid. The system also includes a gas extractor positioned downstream from the outlet of the wellbore and upstream from the inlet sensor. The gas extractor is configured to extract a gas from the drilling fluid. The system also includes a computing system configured to determine a first time when the outlet drilling fluid parameter increases by more than a first threshold, determine a second time when the inlet drilling fluid parameter becomes substantially constant or increases by more than a second threshold, and determine a surface transit time of the drilling fluid based at least partially upon the first time and the second time.
A method can include receiving real-time data during a controlled drilling operation performed by a controller, an instrumented rig and a drillstring that includes one or more downhole sensors, where the data include surface data from the instrumented rig and downhole data from the one or more downhole sensors; detecting a drilling behavior during the drilling operation; and generating a control recommendation to mitigate the drilling behavior.
E21B 21/08 - Controlling or monitoring pressure or flow of drilling fluid, e.g. automatic filling of boreholes, automatic control of bottom pressure
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 44/00 - Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systems; Systems specially adapted for monitoring a plurality of drilling variables or conditions
E21B 7/02 - Drilling rigs characterised by means for land transport, e.g. skid mounting or wheel mounting
A method, sensor, and non-transitory computer-readable storage medium are provided for estimating actual amplitudes of a waveform. A machine learning model may be trained for an embedded system of a first three-axes sensor having a limited range to estimate the actual amplitudes of a waveform that saturates the first three-axes sensor in a direction of one of the three axes. The embedded system acquires a second waveform during use of a tool including the first three-axes sensor. The second waveform that occurs after a second waveform producing event is isolated. The embedded system extracts a multi-dimensional feature from the isolated second waveform and estimates, using the machine learning model, the actual amplitudes of the second waveform based on the extracted multi-dimensional feature.
G01V 1/40 - Seismology; Seismic or acoustic prospecting or detecting specially adapted for well-logging
E21B 47/12 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
Systems and methods presented herein facilitate ensuring the integrity of oil and gas well intervention operations using blockchain technologies. In particular, the systems and methods described herein utilize blockchain technologies to ensure that all data relating to oil and gas well intervention operations are captured and stored in substantially real time during the operations in a secure and immutable manner.
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
G05B 13/02 - Adaptive control systems, i.e. systems automatically adjusting themselves to have a performance which is optimum according to some preassigned criterion electric
H04L 9/00 - Arrangements for secret or secure communications; Network security protocols
28.
MEASURING INFLATABLE PACKER EXPANSION AND WELLBORE DEFORMATION
An inflatable packer assembly that includes opposing end fittings by which the inflatable packer assembly is installable within a downhole tool string. An inflatable body coupled between the end fittings has an external groove. An elongation sensor is fixed in the external groove. The elongation sensor includes a capacitive element that whose capacitance varies based on elongation of the elongation sensor in response to inflation of the inflatable body.
Devices, systems, and methods are provided for a through-rotary centralizer for downhole operations. The through-rotary centralizer assists with centralizing a tool operating downhole, such as a bit. The through-rotary centralizer has a mandrel, a sleeve rotatably mounted around the mandrel, a floating hub slidably mounted around the sleeve, and centralizing arms mounted to the sleeve and floating hub. The centralizing arms extend to exert force against the inner wall of a tubular, such as wellbore casing, thereby providing stability to the downhole tool. Because the sleeve is rotatably mounted to the mandrel, the mandrel rotates within the sleeve and is able to transmit power or torque to the downhole tool, such as a bit. The centralizing arms are not required to rotate with the mandrel due to the rotatably mounted sleeve. A surface system may be used to control the position of the through-rotary centralizer.
A system and method for providing improved control of fluid flow between an interior and an exterior of a tubing string with a multicycle valve system. The multicycle valve having a run-in position, a fracturing position, and a production position. The multicycle valve comprising an outer housing having fracturing ports and production ports. The multicycle valve has a fracturing sleeve which is shifted via pressure applied to a first drop dissolvable ball to open fracturing ports of the multicycle valve. Pressure applied to a second dropped ball shifts an intermediate sleeve to close the fracturing ports and shifts a production sleeve to open production ports. The multicycle valve also has a bypass port allows sufficient fluid to exit the multicycle valve such that an additional ball pump-down operations can still take place uphole of the multicycle valve.
E21B 34/14 - Valve arrangements for boreholes or wells in wells operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools
E21B 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 43/267 - Methods for stimulating production by forming crevices or fractures reinforcing fractures by propping
E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
31.
A METHOD TO ESTABLISH A DETECTABLE LEAK SOURCE LOCATION
Embodiments presented provide for a method for detecting emissions. The method establishes a map that is used with prevailing wind conditions to establish a point source location for methane gas emissions.
An ammonia production system includes a steam generation device configured to produce steam and an electrolyzer cell configured to produce hydrogen feedstock gas from the steam. A hydrogen combustor receives the hydrogen feedstock gas from the electrolyzer cell and combusts the hydrogen feedstock gas and produce heat and electricity. A combustion thermal conduit provides heat transfer between the hydrogen combustor and the steam generation device. An electrical generator is connected to the hydrogen combustor and configured to generate electricity.
The disclosure relates to an electrolysis system and method. The electrolysis system comprises a heating device for heating water above its boiling point (such as steam generator or flash desalinator) to produce a processed water product (such as steam or desalinated water). It also includes an electrolyzer that receives the processed water product to produce hydrogen gas and oxygen based on the processed water product. The system also includes a compressor that receives hydrogen gas and compresses the hydrogen gas, the compressor heating the hydrogen gas to a heated gas temperature; and a cooling system that cools the hydrogen gas from the heated gas temperature to a cooled temperature. The system also includes a heat transfer system that transfers absorbed heat from the cooling system to the heating device, the heating device producing the processed water product at least in part using the absorbed heat
Systems and method presented herein enable the estimation of porosity using neutron-induced gamma ray spectroscopy. For example, the systems and methods presented herein include receiving, via a control and data acquisition system, data relating to energy spectra of gamma rays captured by one or more gamma ray detectors of a neutron-induced gamma ray spectroscopy logging tool. The method also includes deriving, via the control and data acquisition system, one or more spectral yields relating to one or more elemental components from the data relating to the energy spectra of the gamma rays. The method further includes estimating, via the control and data acquisition system, a measurement of porosity based on the one or more spectral yields relating to the one or more elemental components.
G01V 5/12 - Prospecting or detecting by the use of nuclear radiation, e.g. of natural or induced radioactivity specially adapted for well-logging using primary nuclear radiation sources or X-rays using gamma- or X-ray sources
G01V 5/10 - Prospecting or detecting by the use of nuclear radiation, e.g. of natural or induced radioactivity specially adapted for well-logging using primary nuclear radiation sources or X-rays 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
Systems and methods presented herein include sidewall coring tools used to return core samples of rock from a sidewall of a wellbore as part of a data collection exercise for exploration and production of hydrocarbons. In particular, the systems and methods presented herein perform sidewall coring of a subterranean formation using a combination of rotary and percussive coring. More specifically, the systems and methods presented herein rotate a coring cylinder of a sidewall coring tool back and forth less than a full rotation while pushing the coring cylinder of the sidewall coring tool against a bore wall of a wellbore, and push the coring cylinder of the sidewall coring tool into the subterranean formation to enable extraction of a core sample of the subterranean formation.
E21B 49/06 - Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells by mechanically taking samples of the soil using side-wall drilling tools or scrapers
G01N 1/04 - Devices for withdrawing samples in the solid state, e.g. by cutting
An electromagnetic telemetry system to support communications at an oilfield. The system may include unique modes of encoding and decoding acquired signal data between a downhole tool and a surface unit for attenuation of noise from the data. In one embodiment, a mode of speech separation may be utilized to further enhance reliability of the acquired signal data.
G01V 3/30 - Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for well-logging operating with electromagnetic waves
E21B 47/13 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling by electromagnetic energy, e.g. of radio frequency range
37.
QUALITY ASSESSMENT OF DOWNHOLE RESERVOIR FLUID SAMPLING BY PREDICTED INTERFACIAL TENSION
Methods and systems that configure a downhole tool disposed within a wellbore adjacent a reservoir to perform fluid sampling operations that draw live reservoir fluid from the reservoir into the downhole tool are described. The live reservoir fluid is at elevated pressure and temperature conditions of the reservoir. The live reservoir fluid is analyzed within the downhole tool to determine fluid properties of the live reservoir fluid. Interfacial tension of the live reservoir fluid can be determined or predicted from the fluid properties of the live reservoir fluid. The interfacial tension of the live reservoir fluid can be used to characterize and assess quality of the live reservoir fluid in substantially real-time. The characterization and assessment of the quality of the live reservoir fluid can be used to control the sampling operations or initiate downhole fluid analysis or sample collection for analysis of "clean" reservoir fluid of acceptable quality.
A method can include acquiring electromagnetic conductivity measurements for in-phase conductivity and quadrature conductivity using an electromagnetic conductivity tool disposed in a borehole of a formation that includes particles, where energy emissions of the electromagnetic conductivity tool polarize the particles; inverting a model, using the electromagnetic conductivity measurements, for at least two of salinity, water saturation, cation exchange capacity of the particles, Archie cementation exponent and Archie saturation exponent to characterize the formation, where the model includes (i) an in-phase conductivity relationship that depends on formation porosity and water saturation and (ii) a quadrature conductivity petrophysical relationship that depends on salinity, formation grain density, water saturation and cation exchange capacity of the particles; and transmitting the at least two to a computing framework for generation of at least one operational parameter for a borehole field operation for the borehole.
G01V 3/30 - Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for well-logging operating with electromagnetic waves
E21B 44/00 - Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systems; Systems specially adapted for monitoring a plurality of drilling variables or conditions
A fluid electrical probe includes a body portion housing a cleaner, a head portion forming a gap, an electrode disposed in the gap, and a temperature sensor disposed in the gap. The cleaner is extendable into the gap to clean the electrode and the temperature sensor. The body portion comprises a handle configured to be gripped by an operator.
Monitoring and real-time adjustments of proppant concentrations during a hydraulic fracturing treatment may be advantageous, particularly when the goal is to create a heterogeneous proppant pack in the fracture. The proppant concentration may be measured by analyzing noise spectra as the fracturing fluid passes through a tubular body at the surface or downhole in the subterranean well.
Systems and methods presented herein facilitate coiled tubing cleanout operations, and generally relate to estimating reservoir pressure prior to the coiled tubing cleanout operations (e.g., while the wellbore is shut-in). For example, a method includes acquiring, via one or more downhole sensors of a coiled tubing system at least partially disposed within a wellbore, downhole data of the coiled tubing system; identifying, via a processing and control system, a density profile of fluids disposed within the wellbore based at least in part on the acquired downhole data; interpreting, via the processing and control system, the density profile of the fluids disposed within the wellbore; and estimating, via the processing and control system, a reservoir pressure of a reservoir through which the wellbore extends based at least in part on the interpreted density profile of the fluids disposed within the wellbore.
A system includes a drill pipe and a rotating control device including a housing defining a bore through which the drill pipe extends during a managed pressure drilling operation, a sealing element disposed in the housing that is configured to seal against the drill pipe to block fluid flow through an annular space surrounding the drill pipe, a bearing assembly disposed in the housing that enables the sealing element to rotate relative to the housing, and means for detecting eccentricity or misalignment of the drill pipe within the rotating control device during the managed pressure drilling operation.
E21B 44/00 - Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systems; Systems specially adapted for monitoring a plurality of drilling variables or conditions
G01V 1/40 - Seismology; Seismic or acoustic prospecting or detecting specially adapted for well-logging
E21B 47/013 - Devices specially adapted for supporting measuring instruments on drill bits
A method can include acquiring data from a borehole imaging tool disposed in a borehole in a formation where the borehole includes electrically insulating oil-based fluid introduced into the borehole as a drilling lubricant; determining, based on the data, electrically insulating oil-based fluid impeditivity and a reference formation impeditivity via a circuit model that includes series and parallel terms; and detecting a location of a fracture in the formation based on a change in current flow from the tool through the electrically insulating oil-based fluid and into the formation by determining an effective formation impeditivity based on at least a portion of the data for the location and by comparing the effective formation impeditivity to the reference formation impeditivity.
G01V 3/20 - Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for well-logging operating with propagation of electric current
G01V 3/02 - Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination or deviation operating with propagation of electric current
E21B 47/002 - Survey of boreholes or wells by visual inspection
G01V 1/40 - Seismology; Seismic or acoustic prospecting or detecting specially adapted for well-logging
44.
INDUCED CIRCUITRY WITHIN A HARD DIAMOND-LIKE AND CARBON-RICH LAYER HAVING SENSING ABILITIES
A system may include a substrate and a coating deposited onto a surface of the substrate. The coating includes a carbon rich layer deposited on the substrate. The carbon rich layer is also characterized by a first carbon content including sp2carbon and sp3carbon. Further, the carbon rich layer includes one or more treated carbon regions. The one or more treated carbon regions possess an electrically conductive carbon material having a second carbon content including sp2carbon and sp3carbon. The second carbon content includes more sp2 carbon than the first carbon content, and may be pre-arranged and interconnected to produce an electrical circuitry with a pluralities of sensing abilities. The formed smart coating may be preferentially produced on a hard diamond-like carbon coating, such as a low friction and anti-scaling coating.
C23C 16/50 - Chemical coating by decomposition of gaseous compounds, without leaving reaction products of surface material in the coating, i.e. chemical vapour deposition (CVD) processes characterised by the method of coating using electric discharges
C23C 16/52 - Controlling or regulating the coating process
C23C 14/06 - Coating by vacuum evaporation, by sputtering or by ion implantation of the coating forming material characterised by the coating material
A method for evaluating an unknown gas sample includes acquiring a chromatogram of the unknown gas sample and processing the chromatogram to identify a peak. The peak is evaluated to determine if it is representative of a single gas species in the unknown gas sample. The peak is fit with at least first and second curves when the peak is not representative of a single gas species. First and second areas under the corresponding first and second curves are computed and processed to compute a composition of the unknown gas sample or a ratio of concentrations of individual gases in the unknown gas sample.
Embodiments presented provide for a method of evaluation for data that is inconsistent or that changes over time. These embodiments involve the processing of pollutants in a stream such that accuracy is maintained during the processing for high quality evaluation. The method includes collecting atmospheric data for an area, collecting concentration data for pollutant emissions, processing the atmospheric data to determine a quality of the atmospheric data, processing the concentration data for pollutant emissions to determine a concentration data quality, producing a combined quality metric from the processed atmospheric data and the processed concentration data, and determining if the combined quality metric is of a high or low level.
G01N 33/00 - Investigating or analysing materials by specific methods not covered by groups
G01W 1/06 - Instruments for indicating weather conditions by measuring two or more variables, e.g. humidity, pressure, temperature, cloud cover or wind speed giving a combined indication of weather conditions
47.
A METHOD TO PERFORM SELECTION OF OPTICAL GAUGE LENGTH OF FIBERS USED IN HYDROCARBON RECOVERY OPERATIONS, CARBON CAPTURE AND SEQUESTRATION, AND GEOTHERMAL APPLICATIONS
Embodiments presented provide for use of fiber optics within the wellbore environment. Embodiments further provide selection of optimal gauge length of fiber optics in hydrocarbon recovery operations, carbon capture and sequestration operations, or geothermal applications. The method includes obtaining data from optical fibers, processing the data using a fixed gauge length, estimating an apparent velocity using the fixed gauge length through an autonomous computing arrangement, estimating a source bandwidth from the apparent velocity through the autonomous computing arrangement to produce a result, establishing a variable gauge length and reference profile for the result, and processing the obtained data with the established variable gauge length to yield a processed optical data set.
E21B 47/125 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling using earth as an electrical conductor
E21B 41/00 - Equipment or details not covered by groups
E21B 43/267 - Methods for stimulating production by forming crevices or fractures reinforcing fractures by propping
A method for estimating an apparent conductivity of a subterranean formation includes acquiring at least first and second electromagnetic propagation measurements made using an electromagnetic propagation tool having at least one transmitting antenna spaced apart from at least one receiving antenna. A ratio is computed using the measurements and further evaluated to estimate the apparent conductivity.
G01V 3/30 - Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for well-logging operating with electromagnetic waves
G01V 3/12 - Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination or deviation operating with electromagnetic waves
G01V 3/38 - Processing data, e.g. for analysis, for interpretation or for correction
A seal for a rotating control device includes a ring having an inner diameter sized to permit a joint of a tubular to pass therethrough, a sealing element coupled to the ring, and configured to seal with the tubular both at the joint and the body, and an insert coupled to the sealing element and at least partially made of a material that is rigid in comparison to the sealing element. The insert includes a plurality of segments that are configured to slide at least radially in response to the sealing element expanding and contracting by engagement with the tubular.
Geopolymer slurry compositions and methods are described herein that can be used for repair operations in previously cemented wells. The compositions and methods comprise geopolymer slurry compositions having a first component comprising an aqueous-based fluid; a second component comprising an aluminosilicate material; and a third component that activates a polymerization reaction in the slurry composition upon contact with a set cementitious material. The third component can include a set cementitious material.
C09K 8/467 - Compositions for cementing, e.g. for cementing casings into boreholes; Compositions for plugging, e.g. for killing wells containing inorganic binders, e.g. Portland cement containing additives for specific purposes
C04B 28/00 - 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
E21B 33/13 - Methods or devices for cementing, for plugging holes, crevices, or the like
C04B 111/00 - Function, property or use of the mortars, concrete or artificial stone
51.
A METHOD AND APPARATUS TO PERFORM DOWNHOLE COMPUTING FOR AUTONOMOUS DOWNHOLE MEASUREMENT AND NAVIGATION
Embodiments presented provide for an apparatus used for wellbore intervention, evaluation and stimulation. The apparatus provides a tractor mechanism, a power supply, tools and sensors used in evaluation and stimulation activities with hydrocarbon recovery operations.
E21B 23/00 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells
E21B 44/00 - Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systems; Systems specially adapted for monitoring a plurality of drilling variables or conditions
E21B 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
52.
A LINEAR CUT GENERATION METHOD FOR SENSOR INVERSION CONSTRAINT IMPOSITION
Embodiments presented provide for a method of analysis for methane leaks. The method of analysis includes performing a record generation event, performing a quality assessment of the record generation event, performing a linear cut generation procedure to create a linear cut generation data set, and performing a source term inversion using the linear cut generation data set.
E21B 47/10 - Locating fluid leaks, intrusions or movements
E21B 49/00 - Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
G01W 1/02 - Instruments for indicating weather conditions by measuring two or more variables, e.g. humidity, pressure, temperature, cloud cover or wind speed
53.
LEVERAGING FIBER OPTIC-BASED PIPELINE MONITORING FOR MICROSEISMIC MONITORING
Embodiments presented provide for a fiber-optic based pipeline monitoring system and method that senses, records and evaluates micro-seismic events near the monitored pipeline. The method includes locating at least one fiber optic line within an ecosystem of a pipeline, operating the pipeline to carry a fluid through the ecosystem, and monitoring the at least one fiber optic line during the carrying of the fluid through the pipeline. The monitoring the at least one fiber optic line includes obtaining at least one signal from both the pipeline and the ecosystem.
A detonation module for a perforation tool is described herein. The detonation module includes a detonator, a switch circuit disposed in a fluid-sealed housing and electrically coupled to the detonator, a shielding circuit coupled to the switch circuit, an annular electrical contact electrically coupled to the switch circuit, and an annular, electrically conductive, compressive member to form a compressive electrical connection with an end of a perforation unit.
Compositions, methods, and workflows for treating a siliceous geologic formation including flowing a treatment composition into the formation, wherein the treatment composition has a pH of about -1.0 to about 6.0 and includes an acid having molecular weight less than about 200 or an ammonium or sodium salt thereof, an HF source, and a precipitation prevention agent, and a transient modifier, and allowing the transient modifier to modify the permeability of the siliceous formation. The precipitation prevention agent may comprise a chelant or a scale inhibitor. The transient modifier may comprise surfactant, viscoelastic surfactant, a solid, hydrophobic material, an emulsion, a gas, or an energized fluid.
Properties of reservoir rock, hydraulic fracturing materials and a wellbore to be stimulated are determined. One or more preliminary designs for hydraulic fracturing and well production is selected. The data and designs are entered into one or more computer models for calculating well productivity after the hydraulic fracturing treatment. A treatment and well startup design is selected that will provide maximum well productivity, and work proceeds accordingly.
E21B 43/26 - Methods for stimulating production by forming crevices or fractures
G06F 30/28 - Design optimisation, verification or simulation using fluid dynamics, e.g. using Navier-Stokes equations or computational fluid dynamics [CFD]
A drill bit includes a bit insert. A bit body of the bit includes an insert cavity. The bit insert is inserted into the insert cavity. The bit insert is secured to the insert cavity, such as by braze or with a connection mechanism. The bit insert may be replaceable, thereby allowing a drilling operator to adjust the configuration of the bit based on which bit insert is used.
E21B 10/43 - Rotary drag type drill bits with teeth, blades or like cutting elements, e.g. fork-type bits, fish tail bits characterised by the arrangement of teeth or other cutting elements
E21B 10/60 - Drill bits characterised by conduits or nozzles for drilling fluids
A method for estimating a porosity of a rock sample includes acquiring a calibrated digital image of the rock sample, extracting color and texture features from the digital image of the rock sample, and estimating the porosity of the rock sample using a model to evaluate the extracted color features and texture features. The model is configured to correlate digital image color and texture features with porosity.
G01V 5/10 - Prospecting or detecting by the use of nuclear radiation, e.g. of natural or induced radioactivity specially adapted for well-logging using primary nuclear radiation sources or X-rays using neutron sources
E21B 49/02 - Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells by mechanically taking samples of the soil
Geopolymer precursors are presented that are useful for subterranean wells. The precursors contain an aluminosilicate source, an alkali activator, and a carrier fluid. Additives are incorporated into the precursors to induce expansion, self-healing, flexibility, and to improve tensile and shear-bond strength.
C09K 8/46 - Compositions for cementing, e.g. for cementing casings into boreholes; Compositions for plugging, e.g. for killing wells containing inorganic binders, e.g. Portland cement
C09K 8/467 - Compositions for cementing, e.g. for cementing casings into boreholes; Compositions for plugging, e.g. for killing wells containing inorganic binders, e.g. Portland cement containing additives for specific purposes
C09K 8/42 - Compositions for cementing, e.g. for cementing casings into boreholes; Compositions for plugging, e.g. for killing wells
C04B 28/00 - 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
Geopolymer precursors are presented that are useful for subterranean wells. The precursors contain an aluminosilicate source, an alkali activator, and a carrier fluid. Additives are incorporated into the precursors to induce expansion, self-healing, flexibility, and to improve tensile and shear-bond strength.
C09K 8/46 - Compositions for cementing, e.g. for cementing casings into boreholes; Compositions for plugging, e.g. for killing wells containing inorganic binders, e.g. Portland cement
C09K 8/467 - Compositions for cementing, e.g. for cementing casings into boreholes; Compositions for plugging, e.g. for killing wells containing inorganic binders, e.g. Portland cement containing additives for specific purposes
C09K 8/42 - Compositions for cementing, e.g. for cementing casings into boreholes; Compositions for plugging, e.g. for killing wells
C04B 28/00 - 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
A method may include introducing a breaker fluid into a wellbore having a filter-cake on the walls therein, wherein the breaker fluid comprises an organic peroxide; an aqueous solution; an enzyme; and a chelating agent; wherein the breaker fluid degrades a filter-cake along the wellbore wall in the subterranean formation.
Geopolymer precursors are presented that are useful for subterranean wells. The precursors contain an aluminosilicate source, an alkali activator, and a carrier fluid. Additives are incorporated into the precursors to induce expansion, self-healing, flexibility, and to improve tensile and shear-bond strength.
C09K 8/46 - Compositions for cementing, e.g. for cementing casings into boreholes; Compositions for plugging, e.g. for killing wells containing inorganic binders, e.g. Portland cement
C09K 8/467 - Compositions for cementing, e.g. for cementing casings into boreholes; Compositions for plugging, e.g. for killing wells containing inorganic binders, e.g. Portland cement containing additives for specific purposes
C09K 8/42 - Compositions for cementing, e.g. for cementing casings into boreholes; Compositions for plugging, e.g. for killing wells
C04B 28/00 - 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
Geopolymer precursors are presented that are useful for subterranean wells. The precursors contain an aluminosilicate source, an alkali activator, and a carrier fluid. Additives are incorporated into the precursors to induce expansion, self-healing, flexibility, and to improve tensile and shear-bond strength.
C09K 8/467 - Compositions for cementing, e.g. for cementing casings into boreholes; Compositions for plugging, e.g. for killing wells containing inorganic binders, e.g. Portland cement containing additives for specific purposes
C04B 28/00 - 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
C04B 24/26 - Macromolecular compounds obtained by reactions only involving carbon-to-carbon unsaturated bonds
E21B 33/13 - Methods or devices for cementing, for plugging holes, crevices, or the like
Systems and methods are disclosed herein for improved debris collection within a wellbore. An example method can include inserting a tool into a wellbore, where the tool includes an input shaft, an auger shaft, and a collection chamber. The input shaft can be rotated in a first direction, causing rotation of the auger shaft. The rotation of the auger shaft conveys debris into the collection chamber. The input shaft can also be rotated in a second direction, which causes the auger shaft to retract within the collection chamber. The retraction of the auger shaft within the collection chamber prevents the debris from escaping the collection chamber. The tool can then be removed from the wellbore while preventing the collected debris from escaping the collection chamber.
E21B 27/04 - Containers for collecting or depositing substances in boreholes or wells, e.g. bailers for collecting mud or sand; Drill bits with means for collecting substances, e.g. valve drill bits where the collecting or depositing means include helical conveying means
65.
REAL-TIME CABLE SPEED AND DEPTH MEASUREMENTS BASED ON OPTICAL MEASUREMENTS
Systems and methods are disclosed herein for optically measuring the speed of a cable, such as a cable being fed down a wellbore from a cable spool in an oil and gas operation. An example system can include a reference device having a known length that is statically mounted to a frame of the cable spool. The system can include at least two cameras statically mounted to the frame of the cable spool, with the cameras oriented such that their respective fields of view include both the reference device and a portion of the cable, such as a portion not on the spool but not yet downhole. The cameras can send images to a controller that can use triangulation to determine a distance the cable travels in a duration of time between images and calculate an estimated cable speed based on the determined distance and duration of time.
G01P 3/68 - Devices characterised by the determination of the time taken to traverse a fixed distance using optical means, i.e. using infrared, visible, or ultraviolet light
G01P 3/38 - Devices characterised by the use of optical means, e.g. using infrared, visible, or ultraviolet light using photographic means
G01B 11/22 - Measuring arrangements characterised by the use of optical techniques for measuring depth
Systems and methods are disclosed herein for identifying cable damage using machine vision, such as on a cable being fed down a wellbore from a cable spool in an oil and gas operation. An example method can include providing a camera directed toward a cable that is winding upon, or unwinding from, a cable spool. The method can also include capturing a plurality of frames of images of the cable by the camera, such as by capturing video. The captured frames can be cropped to remove portions of the frames that do not include the cable. The method can further include processing the cropped frames using a machine-learning model. The machine-learning model can be trained using images of known cable damage as inputs so it can identify new instances of damage. The machine-learning model can further classify each cropped frame as including damage or not including damage.
G01N 21/88 - Investigating the presence of flaws, defects or contamination
G01N 21/892 - Investigating the presence of flaws, defects or contamination in moving material, e.g. paper, textiles characterised by the flaw, defect or object feature examined
Electromechanical actuators are provided. Such electromechanical actuators can be used in full-bore flow control valves. The flow control valves comprise a generally cylindrical housing, a choke sleeve disposed within the housing, and an electro-mechanical actuator (EMA) assembly housed by the housing. The EMA assembly comprises an actuator and an electronics cartridge. The actuator and electronics cartridge disposed parallel to and at least partially circumferentially aligned with each other.
E21B 34/06 - Valve arrangements for boreholes or wells in wells
E21B 47/01 - Devices for supporting measuring instruments on drill bits, pipes, rods or wirelines; Protecting measuring instruments in boreholes against heat, shock, pressure or the like
68.
METHOD AND DOWNHOLE APPARATUS FOR MATRIX ACIDIZING OF A SUBTERRANEAN ROCK FORMATION
The present disclosure relates to downhole tools and related methods that provide for controlled radial movement of one or more nozzles to provide an adjustable and variable standoff between the exit of the nozzle(s) and the wellbore surface in the treatment zone of a wellbore during matrix acidizing.
An automated workflow for processing dual arrival events consisting of: (1) an automated time pick that located and characterized dual compressional and shear arrival events present in acoustic waveform measurements; and (2) a ray tracing inversion procedure that inverted these time picks and constructed a locally layered formation model of slowness along the well trajectory. The disclosed workflow embodiments provide the following benefits: (1) an automated time pick which estimates the variation of the arrival event with measured depth and determines whether the shoulder bed is above or below the well track; and (2) a ray tracing inversion that determines the raypath type of the dual arrival event. The disclosed workflow embodiments provide a log display of tool layer and shoulder bed compressional and shear slowness which is useful for making correct porosity, VP/VS, and Poisson ratio estimates as well as other geomechanics answers.
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
70.
DOWNHOLE MILLING DISPLACEMENT MEASUREMENT AND CONTROL
Systems and methods are disclosed herein for performing a milling operation within a wellbore in an oil-and-gas setting. An example system can include a milling tool, which can include a cutting head, a linear actuator configured to advance the cutting head, and a linear displacement measurement sensor associated with the linear actuator. The sensor can be configured to measure linear displacement of the linear actuator. The system can also include a cable to lower the milling tool, a control unit that receives data from the sensor, and a display device that displays a visualization of the data from the sensor. The control unit can analyze the data to determine a location of a milling target, a status of the milling operation, and undesirable milling conditions down hole. The control unit can perform a remedial action, such as by turning on a pump to remove debris from the wellbore.
E21B 29/00 - Cutting or destroying pipes, packers, plugs, or wire lines, located in boreholes or wells, e.g. cutting of damaged pipes, of windows; Deforming of pipes in boreholes or wells; Reconditioning of well casings while in the ground
E21B 47/12 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
Systems and methods for monitoring and control in downhole well applications are provided. The system and methodology may be combined with a variety of completions or other types of well equipment deployed downhole to enable electrical, fiber optic, hydraulic, and/or control lines communication with downhole components. For example, the completion may be in the form of a two-stage completion having a lower completion and an upper completion which enable the desired communication when joined.
A method for estimating vertical and horizontal resistivity values and vertical and horizontal dielectric constant values of a multi-layer, anisotropic subterranean formation includes acquiring electromagnetic propagation measurements of the subterranean formation and inverting the measurements using a one-dimensional formation model to compute the anisotropic resistivity and anisotropic dielectric constant values. The model includes a plurality of formation layers in which each of the formation layers has corresponding vertical and horizontal real conductivity and vertical and horizontal imaginary conductivity values.
G01V 3/30 - Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for well-logging operating with electromagnetic waves
E21B 47/12 - 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 for drilling a subterranean wellbore includes rotating a bottom hole assembly (BHA) in the subterranean wellbore to drill the wellbore, the BHA including a drill collar, a drill bit, and a triaxial accelerometer set and a triaxial magnetometer set in or coupled to the drill collar. The triaxial accelerometer set and the triaxial magnetometer set make a plurality of sets of synchronized accelerometer measurements and magnetometer measurements while drilling. These synchronized measurements are processed to compute an interference magnetic field which is in turn processed to compute at least one of a distance or a direction to a magnetic target located external to the wellbore.
G01V 3/30 - Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for well-logging operating with electromagnetic waves
E21B 47/13 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling by electromagnetic energy, e.g. of radio frequency range
An apparatus and method of setting a packer assembly within a wellbore in a steam injection system. The packer assembly isolates portions of the wellbore. The packer assembly comprising a body. The body comprising a ramp and a sealing element positioned adjacent the ramp. A setting collet operable to force the sealing element along the ramp to expand the sealing element. A shear assembly shearable to unset the packer assembly.
A method includes determining where to place one or more devices at a site. Each device includes a first sensor configured to measure a concentration of a greenhouse gas (GHG). The method also includes measuring the concentration of the GHG with the first sensors. The method also includes quantifying a rate that the GHG is emitted based at least partially upon the measured concentration of the GHG. The method also includes determining a location of a GHG-emitting source at the site that is emitting the GHG that is measured by the first sensors. The location is determined based at least partially upon the measured concentration, the quantified rate, or both. The method also includes identifying the GHG-emitting source at the determined location by comparing the determined location with a list of a plurality of GHG-emitting sources at the site and locations thereof.
Systems and methods presented herein are configured to optimize a hydraulic fracturing job design through the use of an advanced wellbore proppant transport model and coupled hydraulic fracture simulator. For example, a data processing system is configured to simulate, via a wellbore flow simulator being executed by the data processing system, a distribution of proppant between a plurality of perforation clusters of a wellbore during a hydraulic fracturing job design; to simulate, via a hydraulic fracture simulator being executed by the data processing system, one or more hydraulic fractures propagating through a subterranean formation through which the wellbore extends; and to automatically adjust, via fracturing design software executed by the data processing system, the hydraulic fracturing job design by dynamically exchanging data relating to the distribution of the proppant and the one or more hydraulic fractures between the wellbore flow simulator and the hydraulic fracture simulator.
Geopolymeric compositions are presented that are useful as geopolymer slurries for cementing subterranean wells. The slurries may contain an aluminosilicate source,, an alkaline source and a carrier fluid. The slurries generate an alkali metal or alkaline earth hydroxide activator in situ, thereby avoiding or reducing handling of alkali materials at a wellsite.
C09K 8/467 - Compositions for cementing, e.g. for cementing casings into boreholes; Compositions for plugging, e.g. for killing wells containing inorganic binders, e.g. Portland cement containing additives for specific purposes
E21B 33/13 - Methods or devices for cementing, for plugging holes, crevices, or the like
Geopolymer precursor compositions are presented that are useful for cementing a subterranean well, among other uses. The precursor compositions are dry mixtures that have an aluminosilicate source and an activator. The activator is an alkalinity source that is safe to store, transport, and blend with an aluminosilicate source. The activator may be a hydroxide-free activator. A geopolymer slurry is formed by adding water to the dry geopolymer precursor compositions. Such slurries have suitable characteristics for use in cementing applications that use pumpable mixtures.
C09K 8/46 - Compositions for cementing, e.g. for cementing casings into boreholes; Compositions for plugging, e.g. for killing wells containing inorganic binders, e.g. Portland cement
C09K 8/467 - Compositions for cementing, e.g. for cementing casings into boreholes; Compositions for plugging, e.g. for killing wells containing inorganic binders, e.g. Portland cement containing additives for specific purposes
C04B 28/00 - 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
E21B 33/13 - Methods or devices for cementing, for plugging holes, crevices, or the like
79.
TUNABLE LASER SPECTROSCOPY MEASUREMENT OF C13 ETHANE
An apparatus for making isotopic ethane measurements of a gas sample includes a tunable infrared laser configured to emit an infrared laser beam; an infrared sensor configured to receive the infrared laser beam; a gas cell deployed in a path between the tunable infrared laser and the infrared sensor such that the infrared laser beam passes through the gas cell, the gas cell configured to receive the gas sample; and a controller configured to evaluate the received infrared laser beam to estimate a ratio of C13 ethane to C12 ethane in the gas sample.
G01N 21/3504 - Investigating relative effect of material at wavelengths characteristic of specific elements or molecules, e.g. atomic absorption spectrometry using infrared light for analysing gases, e.g. multi-gas analysis
G01N 21/39 - Investigating relative effect of material at wavelengths characteristic of specific elements or molecules, e.g. atomic absorption spectrometry using tunable lasers
G01N 21/31 - Investigating relative effect of material at wavelengths characteristic of specific elements or molecules, e.g. atomic absorption spectrometry
A method and apparatus for landing and orienting a production selective landing tool (PSLT) within a well casing. The well casing is provided with one or more indexing casing coupling (ICC). The PSLT is included in a completion string. The PSLT has several landing keys and an orientation key. The PSLT is conveyed through the casing and lands in the ICC. The PSLT has integrated control lines for intelligent completion. The PSLT has lugs coupled to a mandrel and control lines. The lugs, the mandrel and the control lines are shifted relative to the body of the PSLT. The control lines are in a slot of the body. The PSLT is locked in the ICC when the mandrel is shifted. The PSLT can be removed from the ICC via pulling the completion string uphole.
E21B 34/14 - Valve arrangements for boreholes or wells in wells operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools
E21B 23/03 - 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 34/10 - Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole
81.
FABRICATING RUBBER LINING FOR COMPOSITE PCP STATOR
Techniques for forming a helical rubber hose are provided. Such techniques include modified crosshead extrusion techniques in which an elastomer is melted, fed into a crosshead assembly, and extruded on a helical mandrel fed through the crosshead assembly to form a hose. In techniques described herein, relative axial and rotational motion of the mandrel and a die plate at or on the outlet or output of the crosshead assembly are kinematically matched such that the distance of relative axial movement of the mandrel per one revolution equals one pitch of the mandrel.
Systems and methods presented herein generally relate to a formation testing tool configured to determine whether a formation fluid being tested is a bubble point fluid or a dew point fluid. For example, in certain embodiments, a method includes depressurizing a flowline of a formation testing tool. The flowline contains a formation fluid having a gas-to-oil ratio (GOR) within a predetermined GOR range. The method also includes determining, using a fluid analysis module of the formation testing tool, whether the formation fluid is a bubble point fluid or a dew point fluid by analyzing distribution of bubbles in the formation fluid that are caused by the depressurization of the flowline.
E21B 49/02 - Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells by mechanically taking samples of the soil
E21B 49/08 - Obtaining fluid samples or testing fluids, in boreholes or wells
E21B 49/10 - Obtaining fluid samples or testing fluids, in boreholes or wells using side-wall fluid samplers or testers
83.
NANODIAMOND WITH VACANCY DEFECT AND QUANTUM DOT LUMINESCENCE
Luminescent diamond is made by subjecting a volume of diamond grains to high-pressure/high-temperature conditions with or without a catalyst or pressure transfer media to cause the grains to undergo plastic deformation to produce internal vacancy defects, increasing the luminescent activity/intensity of the resulting diamond material. The luminescent material is then subjected to further treatment to create quantum dots on the surface of the diamond particles. Quantum dot formation can include placing the diamond particles in liquid and subjecting the particles to laser pulses. The consolidated diamond material may be treated to further increase luminescent activity/intensity including reducing the consolidated diamond material to diamond particles, heat treatment in vacuum, and/or air heat treatment. The resulting luminescent diamond particles display a level of luminescence intensity greater than that of conventional luminescent nanodiamond, and may be functionalized for use in biological applications.
Luminescent diamond is made by creating vacancies in diamond grains and heat treating the diamond grains by controlling a thickness of the diamond grains on a substrate. The heat treatment may occur in a temperature range that does not burn the diamond grains, and the controlled thickness produces an even color change and/or promotes oxygen terminations on the diamond particle surfaces.
An automated image acquisition device includes a housing including an image acquisition chamber. A tray is deployed in the image acquisition chamber and is configured to receive a drill cuttings sample. At least one light is also deployed in the image acquisition chamber and is disposed to illuminate the tray. A digital camera is deployed in the image acquisition chamber and is configured to acquire a digital image (e.g., a digital color image) of the cuttings sample. The device further includes an electronic controller configured to instruct the digital camera to record a digital image of the drill cuttings and save the image to digital memory or transfer the image to an external computing device.
E21B 49/00 - Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
E21B 49/02 - Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells by mechanically taking samples of the soil
G01N 21/85 - Investigating moving fluids or granular solids
86.
AUTOMATED IMAGE-BASED ROCK TYPE IDENTIFICATION WITH NEURAL-NETWORK SEGMENTATION AND CONTINUOUS LEARNING
A method for evaluating drill cuttings includes acquiring a first digital image and processing the first digital image with a trained neural network (NN) to generate a first segmented image including a plurality of labeled segments in which at least one label includes a lithology type. The segmented image and the acquired first digital image are processed to retrain the NN. A second digital image is then be processed with the retrained NN to generate a second segmented image including a plurality of labeled segments in which at least one label includes a lithology type.
E21B 49/00 - Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
E21B 21/06 - Arrangements for treating drilling fluids outside the borehole
A method for correcting an LWD image to remove stick slip features includes obtaining an LWD image in a wellbore. Surface depth measurements may be interpolated to obtain interpolated surface depths at selected ones of the depths in the LWD image and evaluated to obtain a first tool status log. The LWD image may be evaluated to obtain a second tool status log. The two status logs may be synchronized to obtain a synchronized log. A stick slip feature may be identified in the LWD image and the image resampled to remove the stick slip feature from the LWD image.
E21B 49/00 - Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
E21B 47/12 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
E21B 44/00 - Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systems; Systems specially adapted for monitoring a plurality of drilling variables or conditions
Described herein are methods of recovering a target ion, such as lithium, from earth materials. The methods include leaching the target ion from an earth material such as a clay to form a target solution and extracting the target ion from the dilute lithium solution using a extraction process selective for the target ion to yield a concentrate which can be converted to a product.
C22B 3/04 - Extraction of metal compounds from ores or concentrates by wet processes by leaching
B01D 61/00 - Processes of separation using semi-permeable membranes, e.g. dialysis, osmosis or ultrafiltration; Apparatus, accessories or auxiliary operations specially adapted therefor
C02F 1/44 - Treatment of water, waste water, or sewage by dialysis, osmosis or reverse osmosis
C02F 1/46 - Treatment of water, waste water, or sewage by electrochemical methods
C22B 3/20 - Treatment or purification of solutions, e.g. obtained by leaching
C22B 3/26 - Treatment or purification of solutions, e.g. obtained by leaching by liquid-liquid extraction using organic compounds
C22B 3/42 - Treatment or purification of solutions, e.g. obtained by leaching by ion-exchange extraction
Systems and methods presented herein provide for the generation of acoustic waves for acoustic stimulation, as well as for analysis of subterranean formations, using downhole tools and associated equipment that are not conventionally designed to do so. For example, in certain embodiments, formation testing tools, formation, measurement tools, inflatable packers, and so forth, may be controlled by control systems to, for example, create pressure pulses that generate the acoustic waves. In addition, in certain embodiments, a tool conveyance system that conveys a formation testing or measurement tool into a wellbore may include acoustic receivers that may detect the acoustic waves after they reflect from subterranean features of the formation.
G01V 1/40 - Seismology; Seismic or acoustic prospecting or detecting specially adapted for well-logging
E21B 49/02 - Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells by mechanically taking samples of the soil
E21B 23/06 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for setting packers
E21B 33/129 - Packers; Plugs with mechanical slips for hooking into the casing
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
90.
COLLABORATIVE GENERATION OF CUTTINGS LOGS VIA ARTIFICIAL INTELLIGENCE
A method for generating a depth log of cuttings obtained during a subterranean drilling operation includes acquiring images of the cuttings and labeling the images with a lagged depth at a rig site; generating a clustering of lithology types in the acquired images at a rig the site; transferring the images and the clustering of lithology types from the rig site to an offsite location; evaluating the images and the clustering of lithology types to label each of the lithology types at the offsite location; and generating a description and/or depth log of the labeled lithology types at the offsite location.
E21B 49/00 - Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
E21B 49/08 - Obtaining fluid samples or testing fluids, in boreholes or wells
A method for processing geophysical data may include retrieving geophysical data from a wellsite, where the data comprises seismic data related to the wellsite. Further, the method may include converting the geophysical data to at least one visual image. Furthermore, the method may include obtaining a common shot visual image of the wellsite. Moreover, the method may include comparing the geophysical data for the at least one visual image to the common shot visual image of the wellsite. Additionally, the method may include determining and/or enhancing a difference between the converted geophysical data of the image and the common shot to produce results.
G01V 1/36 - Effecting static or dynamic corrections on records, e.g. correcting spread; Correlating seismic signals; Eliminating effects of unwanted energy
An improved downhole locking mechanism which may include a housing releasably connected to a downhole tool. The housing includes a first housing connected to a second housing. A sleeve disposed within the second housing. A coupling connecting the sleeve and a completion or another assembly. A piston disposed within the sleeve and retained in a locked position via a shear assembly. The piston maintains a retainer in the locked position, where the retainer engages both the sleeve and the lower housing. Hydraulic pressure within the bore of the locking mechanism causes the piston to shear the shear assembly and axially shift the piston towards the upper housing. Shifting the piston causes the retainer to move radially inward to an unlocked position and disengaging the sleeve from the lower housing and unlocking the locking mechanism.
E21B 23/02 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for locking the tools or the like in landing nipples or in recesses between adjacent sections of tubing
E21B 34/10 - Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole
E21B 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
93.
HIGH-CONTRAST ULTRAVIOLET FLUORESCENCE IMAGING SYSTEMS AND METHODS FOR PIXEL-LEVEL DETECTION OF CRUDE OIL IN DRILL CUTTINGS
Systems and methods are provided for imaging drill cuttings, which employ a UV source including a UV LED, which is configured to illuminate a sample volume with UV radiation that interacts with oil-bearing cuttings to cause fluorescence emission. A camera system is configured to capture at least one image of the cuttings based on fluorescence emission. In another aspect, methods are provided for characterizing oil content in drill cuttings that involve capturing at least one WE image of the cuttings illuminated by white light, capturing at least one UV image of the cuttings based on fluorescence emission from UV radiation, processing the at least one WE image to determine a first pixel count for all cuttings, processing the at least one UV image to determine a second pixel count for oil-bearing cuttings, and determining a parameter representing oil content of the cuttings based on the first and second pixel counts.
E21B 49/00 - Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
E21B 34/16 - Control means therefor being outside 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 systems; Systems specially adapted for monitoring a plurality of drilling variables or conditions
A system and method for producing hydrocarbons from a well with a dual sleeve valve assembly. The dual sleeve valve assembly has a toe valve assembly and a production assembly. The toe valve assembly has a valve sleeve positioned in a valve housing comprising at least one fracturing port. The valve sleeve is shiftable to allow fluid through the least one fracturing port. The production assembly comprises a production sleeve positioned within a production outer housing comprising at least one screen port and at least one production port. A sand screen assembly disposed around the production outer housing. The production sleeve shiftable by a ball to allow fluid through the at least one screen port and the at least one production port.
E21B 34/14 - Valve arrangements for boreholes or wells in wells operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools
E21B 23/04 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells operated by fluid means, e.g. actuated by explosion
Luminescent materials have red luminescent behavior after sintering using an HPHT process. Red luminescence is achieved with a temperature of 1475 °C to 1800 °C, and potentially 1600 °C to 1750 °C, with coarse sintered diamond powder having an average size greater than or equal to 100 nm, or more fine grain average grain sizes of at least 25 nm or at least 50 nm. The luminescent material has red luminescence as a result of NV-centers created through the HPHT process which dominates over NV0 centers produced at lower temperatures, and over NVN centers produced at higher temperatures.
A method of deploying a pump in a well production tubing using an electrical cable includes attaching a downhole barrier valve (DBV) to a spoolable conveyance. The DBV is closed to flow in both directions until a differential pressure across the DBV exceeds a first threshold. The DBV is closed to flow when the differential pressure falls below the first threshold. The DBV is moved to a selected depth in the well by extending the conveyance through a lubricator attached to a wellhead at an upper end of the production tubing. The spoolable conveyance is withdrawn from the well. The pump is attached to the electrical cable and is moved through the wellhead and the production tubing by extending the cable until the pump reaches a selected setting depth in the well.
A technique facilitates regulation of pressure in a well to avoid deleterious effects. The technique involves use of a completion deployed downhole in a borehole. The completion may comprise a variety of equipment assembled to facilitate a desired injection operation. A choke is positioned below, i.e. downhole, of the equipment. When an injection fluid is delivered down through the completion, the choke is able to provide a desired pressure regulation. For example, the choke may be controlled or otherwise utilized so as to control pressure of the injection fluid such that the injection fluid above the choke is maintained at a pressure higher than the liquid to gas transition level of the injection fluid.
A method for evaluating a multiphase drilling fluid includes receiving a sample of the multiphase drilling fluid and modifying the sample to enhance a separation of a first NMR peak corresponding to a first fluid phase component and a second NMR peak corresponding to a second fluid phase component. A nuclear magnetic resonance (NMR) measurement is made of the modified sample and evaluated to compute a property of the drilling fluid.
G01V 3/32 - Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for well-logging operating with electron or nuclear magnetic resonance
G01V 3/14 - Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination or deviation operating with electron or nuclear magnetic resonance
E21B 49/08 - Obtaining fluid samples or testing fluids, in boreholes or wells
E21B 47/002 - Survey of boreholes or wells by visual inspection
Composite cement compositions and pumpable slurries for cementing well or at least one zone of the wells are provided and comprise cementitious material that forms calcium silicate hydrates upon exposure to water, inert filler material, nano-sized calcium carbonate particles, and water, wherein the cementitious material has a mean particle size of at least about 0.5 micron and no more than about 20 microns, the inert filler material has particle sizes of at least about 25 microns and no more than about 2 millimeters (mm), and the compositions and slurries have densities of at least about 9.5 pounds per gallon (ppg) and no more than about 12.5 ppg and solid volume fractions of at least about 50%. Methods of cementing the wells or the at least one zone of the wells are also provided and comprise pumping the compositions and slurries into the well and allowing the compositions and slurries to set or cure to form or produce lightweight composite cements having compressive strengths of greater than 400 pounds per square inch.
C09K 8/467 - Compositions for cementing, e.g. for cementing casings into boreholes; Compositions for plugging, e.g. for killing wells containing inorganic binders, e.g. Portland cement containing additives for specific purposes
C04B 22/10 - Acids or salts thereof containing carbon in the anion, e.g. carbonates
C04B 20/00 - Use of materials as fillers for mortars, concrete or artificial stone according to more than one of groups and characterised by shape or grain distribution; Treatment of materials according to more than one of the groups specially adapted to enhance their filling properties in mortars, concrete or artificial stone; Expanding or defibrillating materials
A snap latch or collet for connecting two components together is provided. In one embodiment a latch for connecting a first wellbore element and a second wellbore element includes multiple tensile fingers and multiple collet fingers. The multiple collet fingers include at least two collet fingers disposed circumferentially between a pair of circumferentially neighboring tensile fingers. Additional systems, devices, and methods are also disclosed.
E21B 17/04 - Couplings; Joints between rod and bit, or between rod and rod
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
patents
