A method for extracting thermal energy from a geothermal reservoir having one or more features extending through the geothermal reservoir includes analyzing subsurface data to determine a measured depth of a feature of the one or more that intersects a production well, running a downhole tool along the production well to a location corresponding to the measured depth of the feature, and performing an intervention at the location using the downhole tool, wherein the intervention includes injecting a reactive solution into the feature, wherein the reactive solution is configured to penetrate the feature to a desired depth and according to a desired pattern based on an injection rate of the reactive solution into the feature and a reaction rate of the reactive solution with the feature.
A method for modeling a subsurface region using Artificial Intelligence (AI), including: drilling of at least one reference well into a subsurface region, initializing a first stratigraphic model of the subsurface region, initializing a first gramma ray model, receiving first gamma ray measurements from a gamma ray sensor coupled to a first tool of a first drill string traversing the subsurface region during the drilling of an additional well, determining that a first difference between the first gamma ray model and the received first gamma ray measurements exceeds an error threshold, updating the first stratigraphic model based on the first difference, updating the first gamma ray model, and outputting the updated first stratigraphic model and the updated first gamma ray model.
G01V 5/12 - Prospecting or detecting by the use of ionising radiation, e.g. of natural or induced radioactivity specially adapted for well-logging using primary nuclear radiation sources or X-rays using gamma- or X-ray sources
3.
WELLBORE BALANCED PRESSURE COMPENSATION FOR ROTATING CONTROL DEVICE (RCD) ROTARY SEALS
A seal assembly of a rotating control device (RCD) includes an interior chamber isolated from an external portion of the RCD and configured to store compensation fluid. The seal assembly also includes a path coupled to the interior chamber. The seal assembly further includes a seal chamber coupled to the path. The seal assembly additionally includes a seal element disposed in the seal chamber and configured to form an annular seal about a tubular as the tubular rotates, moves axially, or both.
A system for managing and tracking digital images of drill cuttings includes at least one networked database configured to store the digital images. A supplier portal is configured to enable a supplier to upload the digital images into the database and a customer portal is configured to provide customer access to selected ones of the digital images in the database. A networked blockchain ledger is in communication with the database, the supplier portal, and the customer portal. The blockchain ledger is configured to initiate a smart chain contract for each of the digital images, record customer access events within each smart chain contract for each of the digital images, and create a micro invoice including charges related to the recorded customer access events.
G06F 16/535 - Filtering based on additional data, e.g. user or group profiles
G06F 16/27 - Replication, distribution or synchronisation of data between databases or within a distributed database systemDistributed database system architectures therefor
Apparatuses, systems, and methods can include a processing resource and a memory device storing instructions executable by the processing resource. The instructions can include hosting a plurality of domains and registering a plurality of components and/or microservices from the plurality of domains. In addition, the instructions can include locating a plurality of components and/or microservices from the plurality of domains, access one or more components and/or microservices from one or more domains, combining the one or more components and/or microservices on a page to create a personalized page, and deploy the personalized page. In some examples, a user deploys and operates the personalized page.
A method for extracting thermal energy from a geothermal reservoir having at least two features includes analyzing subsurface data to determine a first location of a first feature of the at least two features and a second location of a second features of the at least two features. The method further includes analyzing the subsurface data to identify first characteristics of the first feature and second characteristics of the second feature, performing a first intervention at the first location, wherein the first intervention is configured to limit fluid flow into and out of the first feature, and performing a second intervention at the second location, wherein the second intervention is configured to increase a flow rate of geothermal fluid from the second feature into a production well.
A choke system for oilfield operations including an actuator; a choke including: a housing defining an interior flow path; a choke plunger coupled to and movable by the actuator; and a choking member coupled to and movable by the choke plunger within the interior flow path to adjust a pressure of a fluid in the interior flow path; a sensor external to the choke, the sensor configured to measure an actuator parameter; and a control system configured to control the pressure of the fluid by: determining the pressure of the fluid based on the actuator parameter measured by the sensor, and wherein the actuator parameter is proportional to the pressure of the fluid; and actuating the actuator to cause the choking member to move within the interior flow path until the pressure of the fluid reaches a desired pressure.
A method including deploying a formation testing tool in a borehole, actuating first and second packers of the formation testing tool in the borehole, obtaining measurements in response to actuation of the first and second packers of the formation testing tool in the borehole, and analyzing the measurements to estimate at least a shear modulus (G) of a geological formation surrounding the borehole.
E21B 49/10 - Obtaining fluid samples or testing fluids, in boreholes or wells using side-wall fluid samplers or testers
E21B 49/02 - Testing the nature of borehole wallsFormation testingMethods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells by mechanically taking samples of the soil
E21B 33/124 - Units with longitudinally-spaced plugs for isolating the intermediate space
The present disclosure relates to a shaped charge liner. The shaped charge liner includes a first liner portion formed a first material. The first liner portion has an apex and a skirt section that define an interior volume of the first liner portion. The shaped charge liner also includes a second liner portion formed of a second material. The second liner portion is coupled to the first liner portion such that the second liner portion is an edge of the interior volume.
A method of storing carbon dioxide in an earth formation includes drilling a borehole extending into the earth formation including a subterranean formation with a drilling fluid including one or more additives that aid carbon storage. The method includes forming a filtercake on surfaces of the earth formation, the filtercake including the fluid loss material and the one or more additives, after drilling the borehole, pumping an injection fluid into the earth formation, releasing the one or more additives from the filtercake with the injection fluid, and introducing the one or more additives and the injection fluid into the subterranean reservoir. Related methods of storing carbon dioxide in an earth formation, and related wellbore fluids are also disclosed.
A method can include generating a pill blend recommendation based at least in part on formation characteristics to mitigate formation loss of drilling fluid during drilling of a borehole, where the pill blend recommendation specifies a particle size distribution determined by a framework that relates historical pill blends and mitigation success; and, responsive to an indication of formation loss of drilling fluid during the drilling of the borehole, issuing an instruction to pump a pill blend formulated according to the pill blend recommendation.
The invention relates to a method for manufacturing at least one interconnector (1) for solid oxide electrochemical devices, referred to as ISO (1), referred to as the method. The method includes: compressing (7) a stack (2) comprising at least two machined metal sheets (3) in contact with one another; and, at the same time as the pressure is applied, heating the stack to a temperature of between 700°C and 1200°C. The compressing includes applying a pressure greater than or equal to 4 bar. The at least two metal sheets are machined and arranged such that, after manufacture, the ISO is formed. The pressure is applied perpendicularly to the at least two sheets.
B32B 15/01 - Layered products essentially comprising metal all layers being exclusively metallic
B23K 20/02 - Non-electric welding by applying impact or other pressure, with or without the application of heat, e.g. cladding or plating by means of a press
A system includes a first tool including first control circuitry, wherein the first tool is configured to perform a first operation within a borehole, and a second tool including second control circuitry, wherein the second tool is configured to perform a second operation within the borehole, and wherein the first control circuitry is configured to communicate with the second control circuitry via Ethernet.
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 rotating control device includes a drive guide element, a bearing housing, a rotary seal housing including a plurality of rotary seals surrounding the drive guide element and limiting ingress of a working fluid flowing into the bearing housing, a seal sleeve positioned between the plurality of rotary seals and the drive guide element, a plurality of feed lines containing a pressure compensation fluid, and a plurality of features that cooperates with the plurality of rotary seals. As the drive guide element and the seal sleeve rotate about a tubular, the plurality of features pushes the pressure compensation fluid across a face of a corresponding rotary seal, provides a backpressure against the corresponding rotary seal to reduce a differential pressure across the corresponding rotary seal, or both.
A seal including a seal body, an inner arm protruding from the seal body and configured to engage an inner surface, and an outer arm protruding from the seal body and configured to engage an outer surface. The inner arm includes an inner seal protrusion proximate to a distal end of the inner arm and an inner support protrusion. The outer arm includes an outer seal protrusion proximate to a distal end of the outer arm and an outer support protrusion. The inner seal protrusion and the outer seal protrusion define a seal width, and the inner support protrusion and the outer support protrusion define a support width less than the seal width while the seal is in an uncompressed state.
A wellbore fluid includes an oleaginous base fluid, and an emulsifier composition. The emulsifier composition includes an emulsifier including an amide comprising a reaction product of a polyamine and one or more fatty acids. The emulsifier composition further includes one or more organic acids. The one or more organic acids may be present in the emulsifier composition a concentration of at least about 1.0 mole for every about 1.0 mole of the amide. Related methods of operating a wellbore and wellbore are also disclosed.
A progressive cavity pump system including a pump string disposed in a wellbore. The pump string includes a progressive cavity pump and a rod string, wherein the rod string is rotatable about a rod string axis to rotate a rotor of the progressive cavity pump. The progressive cavity pump system includes a permanent magnetic motor ("PMM") configured to drive the rotation of the rod string. The PMM is oriented such that a drive shaft of the PMM rotates about a drive shaft axis that is not coaxial with the rod string axis.
F04C 2/107 - Rotary-piston machines or pumps of intermeshing-engagement type, i.e. with engagement of co-operating members similar to that of toothed gearing of internal-axis type with the outer member having more teeth or tooth-equivalents, e.g. rollers, than the inner member with helical teeth
F04C 11/00 - Combinations of two or more machines or pumps, each being of rotary-piston or oscillating-piston typePumping installations
F04C 13/00 - Adaptations of machines or pumps for special use, e.g. for extremely high pressures
F04C 15/00 - Component parts, details or accessories of machines, pumps or pumping installations, not provided for in groups
E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
18.
COMMUNICATION METHOD FOR UNTETHERED DOWNHOLE SYSTEMS
The disclosure provides methods of communication for untethered systems. The method includes defining a window for sampling a torque-related current and a modulator rotor relative position-related parameter; using the defined window, recording local maximum and local minimum values of the torque-related current versus a modulator rotor relative position-related parameter of a rotor of a rotary pulser system in the untethered system; identifying at least one of consecutive torque-related current minimum values and consecutive torque-related current maximum values based on a periodicity; computing an absolute modulator rotor position based on the periodic maxima and minima of the torque-related current; and controlling the modulator rotor using the absolute modulator rotor position to modulate uplink signals to a surface environment.
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 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
A system includes an electric submersible progressive cavity pump (ESPCP). The ESPCP includes a stator having an internal bore, and a hollow rotor disposed in the internal bore of the stator, where the hollow rotor is configured to rotate within the internal bore to pump a fluid via a plurality of progressive cavities.
F04C 2/107 - Rotary-piston machines or pumps of intermeshing-engagement type, i.e. with engagement of co-operating members similar to that of toothed gearing of internal-axis type with the outer member having more teeth or tooth-equivalents, e.g. rollers, than the inner member with helical teeth
F04C 11/00 - Combinations of two or more machines or pumps, each being of rotary-piston or oscillating-piston typePumping installations
F04C 13/00 - Adaptations of machines or pumps for special use, e.g. for extremely high pressures
F04C 15/00 - Component parts, details or accessories of machines, pumps or pumping installations, not provided for in groups
E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
20.
WELLBORE FLUIDS INCLUDING HYDROPHOBIC MODIFIED STARCH, AND RELATED METHODS
A wellbore fluid includes a base fluid and a fluid loss material comprising hydrophobic modified starch. The hydrophobic modified starch comprises at least one of crosslinked starch, hydroxyalkylated starch, or carboxymethylated starch, and at least one hydrophobic group bonded to the at least one of the crosslinked starch, hydroxyalkylated starch, or the carboxymethylated starch. The wellbore fluid further comprises a hydrophobic bridging material. Related methods and drilling fluids are disclosed.
Systems and methods are described for developing a model to predict humidity (relative, absolute) values inside a closed housing with an absorbent filter. In an example, a methane sensor that includes an internal atmospheric sensor and an external atmospheric sensor can be placed at a site. A computing device can use measurements from the atmospheric sensors to calculate predicted relative and absolute humidity values inside the methane sensor. The computing device can train a gaussian process regression model to calibrate sensor data based on the external temperature and humidity. When the model predicts the ambient methane within a predetermined degree of allowance, the model can be applied to live readings from methane sensors in the field.
A system for drilling a borehole includes a drilling assembly. An array of sensors is distributed around a circumference of the drilling assembly. Each sensor is configured to measure a temperature of fluid external to the drilling assembly at a different azimuthal position around the circumference of the drilling assembly. A method of drilling a borehole using a drilling assembly includes monitoring a fluid in an annulus between the drilling assembly and a wall of the borehole using an array of sensors distributed around a circumference of the drilling assembly. The method includes detecting a temperature change of the fluid using a sensor of the array of sensors, and determining an azimuthal direction of the temperature change with respect to the circumference of the drilling assembly. The method includes steering the drilling assembly to extend the borehole according to the determined azimuthal direction of the temperature change.
E21B 47/103 - Locating fluid leaks, intrusions or movements using thermal measurements
E21B 47/01 - Devices for supporting measuring instruments on drill bits, pipes, rods or wirelinesProtecting measuring instruments in boreholes against heat, shock, pressure or the like
A method of drilling a borehole includes extending the borehole in a formation using a drilling assembly deployed on coiled tubing. In some aspects, the method includes determining a value of a rate of penetration of the drilling assembly in the formation from drilling data obtained while drilling the borehole, and determining a value of porosity of the formation from the value of rate of penetration. In some aspects, the method includes determining a value of dimensionless torque from the drilling data, and determining a value of porosity of the formation from the value of dimensionless torque. The method further includes, based on the value of porosity, steering a drilling assembly in the borehole to further extend the borehole in the formation.
E21B 49/00 - Testing the nature of borehole wallsFormation testingMethods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
G01V 5/08 - Prospecting or detecting by the use of ionising radiation, e.g. of natural or induced radioactivity specially adapted for well-logging using primary nuclear radiation sources or X-rays
A method of drilling a borehole includes receiving resistivity log data. The log data includes a phase shift and a propagation attenuation of electrical signals emitted by a resistivity logging tool at successive depths in the borehole. The method includes determining an increasing trend of one of the phase shift or the propagation attenuation from a first depth of the successive depths to a second depth of the successive depths, and determining a decreasing trend of a different one of the phase shift or the propagation attenuation from the first depth to the second depth. The method includes determining a resistivity of a formation at the second depth based on the increasing trend and the decreasing trend. The method includes, based on the resistivity of the formation at the second depth, steering a drilling assembly in the borehole to extend the borehole in the formation.
G01V 3/26 - Electric or magnetic prospecting or detectingMeasuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for well-logging operating with magnetic or electric fields produced or modified either by the surrounding earth formation or by the detecting device
E21B 44/00 - Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systemsSystems specially adapted for monitoring a plurality of drilling variables or conditions
A system is provided a composition of produced fluids of production wells extending through an earth formation, the produced fluids having a concentration of lithium. The system may provide a feed material to a lithium extraction process, the feed material comprising flowrates of the produced fluids. The system may utilize a simulation to determine an optimal feed composition to provide to the lithium extraction process to maximize a concentration of lithium in the feed material. The system may adjust flowrates of each of the produced fluids based on the optimal feed composition. Related systems and methods are also disclosed.
The invention relates to a method for producing hydrogen via steam electrolysis, the method comprising the following steps: - producing steam (112) by heating liquid water (204); and - electrolysing, in an electrolysis unit (102), at least a portion of the steam (112) to provide a first output stream (116) rich in hydrogen and a second output stream (118) rich in oxygen; characterised in that the steam is produced by at least one heat pump circuit reusing a portion of the heat from at least one of the output streams (116, 118) in order to vaporise the liquid water. The invention also relates to a system (400) implementing such a method.
The invention relates to the coupling of a hydrogenation or oxidation plant (2) and a dihydrogen production plant (3), for transferring (4) heat generated by the hydrogenation or oxidation plant (2) to an input stream of an electrochemical device of the dihydrogen production plant (3) and/or for feeding (100), to said hydrogenation or oxidation plant (2), one or more fluids formed by the electrochemical device.
Methods and systems are provided that calculate data representing an estimate of formation strength while drilling. The methods and systems employ a drill bit that is instrumented with a first sensor and a second sensor. A processor is configured to i) determine and store first data representing cutting forces acting on a cutting element of the drill bit while drilling based on measurements of the first sensor while drilling, ii) determine and store second data representing depth of cut of the drill bit while drilling based on measurements of the second sensor while drilling, and iii) process the first data and second data to generate and store data representing contact stress against the formation while drilling. This resultant data can be used as an estimate of formation strength. This estimate of formation strength is similar to UCS and can be used in oilfield operations/planning, such as formation characterization while drilling, or drilling efficiency analysis while drilling.
E21B 47/12 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
E21B 47/013 - Devices specially adapted for supporting measuring instruments on drill bits
E21B 44/00 - Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systemsSystems specially adapted for monitoring a plurality of drilling variables or conditions
(1) A multiple segment production assembly for subsurface wells, namely, flow control valves, subsurface safety valves, gas lift valves, packers, monitoring and telemetry equipment for segmenting a downhole well and enhancing control and monitoring of each individual segment while producing the well.
30.
INTERCONNECTOR FOR AN ELECTROCHEMICAL DEVICE COMPRISING SEALING GROOVES
The invention relates to a high temperature electrolyser comprising interconnectors (4) forming grooves for retaining seals (44, 46). The invention also relates to the corresponding production and assembly methods.
Methods and systems for managing operation of a well are disclosed. The method may include obtaining sonic log data for a geological formation in which the well is positioned. An iterative cross-correlation based reflector tracking process may be performed using the sonic log data to obtain a reflector data package. The reflector data package may include a plurality of points on a reflector and a plurality of dip angles of the reflector for the plurality of points. The reflector data package may be used, at least in part, to operate the well.
G01V 1/40 - SeismologySeismic or acoustic prospecting or detecting specially adapted for well-logging
E21B 47/12 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
32.
SYSTEM AND METHODOLOGY FOR EVALUATION OF DISTRIBUTED ACOUSTIC AND TEMPERATURE SIGNALS DURING WELL FLOWS WITH HETEROGENEOUS INFLOW AND OUTFLOW PATTERNS
Methods and systems for managing characterization of wells using data acquisitions tools are disclosed. The data acquisition tools may be positioned in portions of wells. While positioned in the wells, the data acquisition tools may be measured. The measurements may be ingested into models and may provide, as output, inferred conditions in the portions of the wells. The models may be created using simulation systems. The simulation systems may allow for conditions that may be present in wells to be simulated, and data acquisition tools to be exposed to the simulated conditions. While exposed to the simulated conditions, the data acquisition tools may be measured to establish associations that may be used to infer conditions that may be present in wells.
E21B 43/267 - Methods for stimulating production by forming crevices or fractures reinforcing fractures by propping
E21B 47/14 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling using acoustic waves
A system includes a blowout preventer (BOP) having a ram assembly having first and second pistons. The first piston is configured to drive a first ram into a cavity of the BOP and the second piston is configured to drive a second ram into the cavity. The system also includes a motor assembly having first and second motors. The first motor is configured to cause an extension of a first lock to constrain the first piston and the second motor is configured to cause an extension of a second lock to constrain the second piston. The first and second motors are fluidly coupled to each other in a series arrangement via a connector conduit. The connector conduit is configured to flow a motor fluid sequentially through the first and second motors.
A rig power supply system may identify a power profile of a drilling rig. A rig power supply system may, based on the power profile, generate an operating profile for the drilling rig, the operating profile including a combination of rig power supply of a rig power supply system and stored energy capacity of an energy storage system.
A rig power management system may identify a power demand of a drilling rig. A rig power management system may when the power demand is greater than a threshold power setpoint, supplementing a rig power supply system with an energy storage system. A rig power management system may when the power demand is less than the threshold power setpoint, maintaining a power generation at an operating power setpoint to charge the energy storage system.
Methods and systems are disclosed that use a temperature sensor integral to a drill bit during drilling. The temperature sensor is configured to measure temperature associated with a cutting element of the drill bit over time during drilling. The temperature sensor is used to generate temperature data representing temperature of the cutting element of the drill bit over time during drilling. The temperature data is processed to determine and monitor at least one condition of the wellbore and/or the drill bit during drilling, such as i) detection of faults or openings or cracks or other geological rock features of the wellbore being drilled, ii) estimation of one or more drilling parameters of the drill bit (such as rate of penetration (ROP), iii) detection of lost cutting element(s), iv) detection of bit balling, and v) detection of drilling efficiency.
E21B 47/01 - Devices for supporting measuring instruments on drill bits, pipes, rods or wirelinesProtecting measuring instruments in boreholes against heat, shock, pressure or the like
Aspects of the disclosure provide for using anticorrelation in propagation resistivity logs to detect boundary approaching conditions. Geosteering may be performed based on the detected boundary approaching conditions. The boundary detection and geosteering may be for a high angle well. The anticorrelation may be between attenuation resistivity and phase shift resistivity.
G01V 3/30 - Electric or magnetic prospecting or detectingMeasuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for well-logging operating with electromagnetic waves
E21B 41/00 - Equipment or details not covered by groups
E21B 43/16 - Enhanced recovery methods for obtaining hydrocarbons
G01V 3/30 - Electric or magnetic prospecting or detectingMeasuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for well-logging operating with electromagnetic waves
G01V 1/40 - SeismologySeismic or acoustic prospecting or detecting specially adapted for well-logging
39.
CUTTING INSERTS FOR USE IN A DOWNHOLE BIT AND METHODS THEROF
A cutting insert may include a base surface and a cutting element. The base surface is configured to be connected to a base of the cutting element. The cutting element including an upper surface. The upper surface includes a vertical most point and a cutting edge, and where the cutting edge has a vertical most portion, and where the vertical most portion of the cutting edge is closer to the base surface than the vertical most point.
A system includes a tube string configured to deploy within a wellbore, where the tube string includes a passage extending along a length of the tube string, and where the passage is configured to route fluid between a downhole location and an up hole location. The tube string also includes passage isolation device including a ball valve disposed within the passage and configured to transition between an open configuration and a closed configuration, where the ball valve is configured to enable a flow of the fluid through the ball valve in the open configuration. The ball valve is also configured to block the flow of the fluid through the ball valve in the closed configuration. The passage isolation device also includes an electronic actuator coupled to the ball valve, where the electronic actuator is configured to actuate the transition of the ball valve between the open configuration and the closed configuration.
The present application relates to a connector (10) designed to establish a fluid connection between two ducts (5, 6) of a high-temperature electrolyser-type electrochemical system. The connector (10) comprises a pipe element (30) and a connecting member (32), each comprising an electrically insulating material such as a ceramic. The present application also relates to an electrochemical system comprising at least one such connector (10).
C25B 1/042 - Hydrogen or oxygen by electrolysis of water by electrolysis of steam
C25B 9/00 - Cells or assemblies of cellsConstructional parts of cellsAssemblies of constructional parts, e.g. electrode-diaphragm assembliesProcess-related cell features
C25B 15/08 - Supplying or removing reactants or electrolytesRegeneration of electrolytes
F16L 23/028 - Flanged joints the flanges being connected by members tensioned axially characterised by how the flanges are joined to, or form an extension of, the pipes the flanges being held against a shoulder
H01M 50/00 - Constructional details or processes of manufacture of the non-active parts of electrochemical cells other than fuel cells, e.g. hybrid cells
H01M 8/04 - Auxiliary arrangements, e.g. for control of pressure or for circulation of fluids
42.
BREAKTHROUGH DETECTION FOR LITHIUM BEARING RESERVOIRS
Aspects of the present disclosure provide a method for extracting minerals from a reservoir zone. The method includes extracting a fluid from the reservoir zone, the fluid including mineral brine and the mineral brine including the minerals, extracting the minerals from the mineral brine and producing a depleted effluent, injecting one or more tracers into the depleted effluent, injecting the depleted effluent with the one or more tracers into the reservoir zone, and monitoring the fluid for the one or more tracers.
The invention relates to a plant for producing dihydrogen, referred to as plant. The plant comprises an electrolyser, arranged to produce dioxygen and dihydrogen from steam, referred to as hot steam, at a temperature higher than 150°C, or water, referred to as hot water, at a temperature lower than or equal to 90°C. The plant further comprises a clinker manufacturing unit. The plant further comprises a heat recovery unit arranged to produce the hot steam or the hot water from gaseous emissions, referred to as hot gases, at a temperature higher than 150°C, emitted by the clinker manufacturing unit.
An electric submersible pump (ESP). The ESP may comprise a bag frame comprising an upper bag frame and a lower bag frame. The ESP may comprise a bag. The ESP may comprise a housing. The ESP may comprise a shaft tube. The ESP may comprise a clamp. The ESP may comprise a bag support with a lower bag support and an upper bag support. The bag support may support an external surface of the bag that is uncovered by the housing, the bag frame, the shaft tube, and the clamps. The lower bag support may comprise a single, complete ring that supports the bag from the clamp to the housing.
The invention relates to a high-temperature electrolyser comprising corrugated interconnectors (4) equipped with reinforcing rods (30). The invention also relates to the associated production method.
A bacterial carbon dioxide immobilization system may inject carbon dioxide in the underground aquifer. A bacterial carbon dioxide immobilization system may inject a nutrient in the underground aquifer. A bacterial carbon dioxide immobilization system may inject carbonate-forming bacteria configured to form a carbonate from the nutrient and carbon dioxide, the carbonate-forming bacteria encapsulated with an encapsulating layer.
An electric submersible pump (ESP) comprising: a head comprising one or more top bearings and one or more sand filters; a long bearing with axial grooves configured to be used with two short sleeves; raised and intermediate seal bodies with long-bearings; an internal relief valve mounted internally inside a seal body; a body positioned above a thrust bearing chamber comprising dual bushings with axial grooves in different bores; and a base with long-bearings.
The invention relates to a modular assembly for a solid oxide electrolysis system for producing hydrogen. The assembly comprises at least one module (1) comprising at least one stack (2) of solid oxide plates positioned in a heat chamber (3), pipes for supplying fluids into the stack (2), pipes for discharging fluids from the stack (2), and at least one fluid-heating device allowing the fluid to reach a temperature that is compatible with the operation of the stack (2). The module (1) comprises a first removable part (10) provided with first connectors (4) for fluid pipes, which part comprises the stack (2) of solid oxide plates positioned in the heat chamber (3), and a second fixed part (11) provided with second connectors (5) capable of being connected to and disconnected from the first connectors (4). The second fixed part (11) comprises a distribution network (13) comprising the fluid supply pipes (14) and fluid discharge pipes (15).
A method includes: generating a synthetic geological formation model, including: receiving relative dip angles, determining a dielectric assumption, a horizontal relative permittivity, a vertical relative permittivity, and a vertical resistivity, and determining respective apparent dielectric permittivity and resistivity, performing 1D inversion, including: generating random geological layer parameters, generating a reference formation model, forward modeling the synthetic geological formation model, generating attenuation and phase-shift logs, generating a 1D inversion model, and generating inverted resistivity and inverted permittivity (EPSI), training a dielectric enhancement model, including: validating the dielectric enhancement model with the apparent dielectric permittivity and resistivity and an enhanced EPSI, training a convolutional neural network (CNN) with the inverted resistivity and permittivity and the relative dip angle, and updating the enhanced EPSI, generating a model prediction for a target geological formation, including: receiving logged values for the target geological formation, and correcting the logged values with the trained dielectric enhancement model.
G01V 5/10 - Prospecting or detecting by the use of ionising radiation, e.g. of natural or induced radioactivity specially adapted for well-logging using primary nuclear radiation sources or X-rays using neutron sources
G01V 5/12 - Prospecting or detecting by the use of ionising radiation, e.g. of natural or induced radioactivity specially adapted for well-logging using primary nuclear radiation sources or X-rays using gamma- or X-ray sources
E21B 47/12 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
50.
HOT BOX COMPRISING UNIFORMLY POWERED STACKS OF PLATES FOR SOLID OXIDE ELECTROLYZER (SOEC) OR FOR FUEL CELL SYSTEM (SOFC), AND ASSOCIATED INSTALLATION
The invention relates to a hot box (1) of reversible high-temperature SOEC/SOFC electrolysis stacks (2), comprising a tank (10) accommodating at least two stacks, an inlet (14) and an outlet (15) through which first and second fluids (32) can enter and be discharged, said hot box further comprising a first supply pipe (6) for supplying a third fluid to each of said at least two stacks (2), and which extends from outside said tank to a central shaft (60). The hot box comprises sub-pipes (61) for distributing said third fluid, these each extending from the central distribution shaft to an inlet of a stack, said at least two stacks being positioned at equal distances from said central shaft. The hot box also includes discharge channels (62) which extend from the bottom of each of the stacks, to a second discharge pipe that collects a fourth fluid and discharges it out of said tank.
A safety valve piston seal assembly for safety valve pistons to improve the reliable of safety valve operation. The safety valve piston seal assembly is positioned about a safety valve piston and comprises components which divert a load path to the safety valve piston rather than to susceptible components of the seal assembly. The seal assembly may comprise a metal spring energized seal, an MSE backup ring adjacent the MSE seal and a load transfer assembly. The load assembly comprises a load ring, C-rings and a retaining sleeve. The retaining sleeve holds the two load rings and C-ring in place. The retaining sleeve restricts movement of the load ring.
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
52.
AT-BIT DEPTH OF CUT AND RATE OF PENETRATION MEASUREMENTS
A drill bit includes cutting elements and a displacement sensor deployed on a drill bit body. The displacement sensor includes an engagement piston disposed to translate axially in a sensor housing. The engagement piston includes an inner plunger and an opposing outer engagement element configured to engage a subterranean formation and is biased outward from the sensor housing. The displacement sensor further includes a position sensor configured to sense an axial position of the engagement piston in the sensor housing. An electronic controller is configured to determine a measured displacement from the sensed axial position of the engagement piston. The displacement sensor may enable depth of cut and rate of penetration measurements to be made while drilling.
E21B 47/01 - Devices for supporting measuring instruments on drill bits, pipes, rods or wirelinesProtecting measuring instruments in boreholes against heat, shock, pressure or the like
E21B 10/48 - Drill bits characterised by wear resisting parts, e.g. diamond inserts the bit being of core type
53.
SYSTEMS AND METHODS FOR PREDICTING WELLBORE STIMULATION PERFORMANCE OF ACID JETTING THROUGH PRE-PERFORATED LINERS
The present disclosure relates to systems and methods for predicting wellbore stimulation performance of acid jetting through pre-perforated liners. In particular, the methods presented herein include collecting data relating to a wellbore stimulation operation performed subsurface in a wellbore, and utilizing a physics-based model to predict an effect of jetting on efficiency of a reactive fluid during the wellbore stimulation operation based at least in part on the collected data. In addition, experimental and field treatment data, real-time telemetry, production logs, flow quantification logs or distributed sensing (e.g., temperature, acoustic, strain, and so forth) results may be used to calibrate tuning parameters of the physics-based model, which may be adjusted based on data analytics and machine learning methods.
E21B 43/27 - Methods for stimulating production by forming crevices or fractures by use of eroding chemicals, e.g. acids
E21B 43/267 - Methods for stimulating production by forming crevices or fractures reinforcing fractures by propping
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 system includes a valve cartridge, including a body defining a fluid flow path extending from an oil inlet to an oil outlet. The oil inlet is configured to be fluidly coupled to a volume disposed about a piston. The oil inlet is configured to receive oil from the volume disposed about the piston and direct the oil along the flow path. The toe valve cartridge further includes a first membrane disposed along the flow path, downstream of the oil inlet. The first membrane is configured to rupture when exposed to a pressure and a second membrane disposed along the flow path, downstream of the first membrane. The valve cartridge is configured to direct the oil along the flow path, through the ruptured first membrane, through the ruptured second membrane, and out of the valve cartridge via the oil outlet.
E21B 34/10 - Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole
E21B 34/14 - Valve arrangements for boreholes or wells in wells operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools
E21B 43/267 - Methods for stimulating production by forming crevices or fractures reinforcing fractures by propping
Systems and methods are provided to extract features (e.g., colors, textual features) from arbitrary shaped and sized images by implementing global average pooling (GAP) and partial convolution in an autoencoder (AE) for analysis of the images. A global average pooling (GAP) layer may be used at the last layer of the encoder of the AE to make the feature rotation and translation invariant and scale equivariant. In addition, partial convolution may be used in the encoder to logically ignore the invalid pixels (e.g., background, image error, other object) or any pixel (e.g., in any area) in the images.
G01N 15/0227 - Investigating particle size or size distribution by optical means using imagingInvestigating particle size or size distribution by optical means using holography
G01N 21/84 - Systems specially adapted for particular applications
A method can include receiving queries for a well work program; responsive to the queries, retrieving data from a database to populate a well work program template; generating a graphical user interface based on the populated well work program template; and, responsive to interactions with the graphical user interface, generating a well work program file that specifies actions to perform the well work program.
G06Q 10/063 - Operations research, analysis or management
E21B 44/00 - Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systemsSystems specially adapted for monitoring a plurality of drilling variables or conditions
Methods and apparatus are described herein for recovering an element of interest from an aqueous source. Methods described herein include measuring a first conductivity of a first aqueous material using a conductivity sensor; performing an operation on the first aqueous material to change a concentration of an element of interest of the first aqueous material and yield a second aqueous material; measuring a second conductivity of the second aqueous material using a conductivity sensor; comparing the first conductivity, or a first value of a variable derived from the first conductivity, with the second conductivity, or with a second value of the variable derived from the second conductivity; and modifying a parameter of the operation based on the comparison. Methods are also described herein for recovery of elements of interest from aqueous sources using simulated moving beds processes.
A system may include a CO2 capture module, including a capture unit for capturing CO2 from a gas using a capture material and a regeneration unit for unloading the CO2 from a loaded capture material and regenerating said loaded capture material using heat. A system may include an energy module for producing electrical power and heat using solar energy, wherein at least a portion of the heat produced in the energy module is used in the regeneration unit.
B01D 53/96 - Regeneration, reactivation or recycling of reactants
F24S 10/30 - Solar heat collectors using working fluids with means for exchanging heat between two or more working fluids
F24S 60/00 - Arrangements for storing heat collected by solar heat collectors
B01D 53/14 - Separation of gases or vapoursRecovering vapours of volatile solvents from gasesChemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases or aerosols by absorption
A method for estimating a mechanical property of a subterranean formation includes engaging the formation with an engagement assembly deployed on a downhole tool to make engagement measurements while rotating the downhole tool in the wellbore. The mechanical property of the formation may be estimated from the engagement measurements. The mechanical property may include a modulus, a strain profile, or a formation integrity.
E21B 47/01 - Devices for supporting measuring instruments on drill bits, pipes, rods or wirelinesProtecting measuring instruments in boreholes against heat, shock, pressure or the like
A method includes receiving formation model data corresponding to characteristics of a formation, receiving at least one drilling parameter corresponding to an attribute related to a well in the formation, generating a synthetic response based upon the formation model data and the at least one drilling parameter, undertaking channel selection based on the synthetic response as training data, wherein the channel selection comprises a set of data channels of a logging tool of the well that prioritizes a predetermined portion of measurements to transmit from the logging tool, training a machine learning system into a trained machine learning system utilizing the training data comprising the channel selection corresponding to the synthetic response as a matched pair of inputs for the machine learning system, and generating a final model as the trained machine learning system via the training of the machine learning system.
G01V 3/30 - Electric or magnetic prospecting or detectingMeasuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for well-logging operating with electromagnetic waves
E21B 47/12 - 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 exacting elements of interest, such as lithium, from an aqueous material are described herein. The systems generally use multiple vessels with selective media in each vessel to accomplish extraction of the element of interest. The vessels are operated in cyclic, permuted fashion to move between absorption and desorption operations by routing flows of streams for accomplishing such operations among the vessels in programmed ways. Sensors configured to detect total dissolved solids, or a parameter related to total dissolved solids, are used to detect endpoints for mode switching and to ascertain other aspects of system performance.
B01D 15/08 - Selective adsorption, e.g. chromatography
C22B 3/24 - Treatment or purification of solutions, e.g. obtained by leaching by physical processes, e.g. by filtration, by magnetic means by adsorption on solid substances, e.g. by extraction with solid resins
A system and method for predicting formation properties is described. For example, a computing device may receive deep directional resistivity (DDR) measurement data from one or more DDR sensors. The computing device may apply a formation property prediction model to the DDR measurement data, the formation property prediction model pretrained to identify predicted formation parameters based on input DDR data, formation properties of the input DDR data, and tool parameters. The computing device may receive the predicted formation parameters for a subsurface beyond the wellbore in response to applying the formation property prediction model to the DDR measurement data.
G01V 3/30 - Electric or magnetic prospecting or detectingMeasuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for well-logging operating with electromagnetic waves
E21B 47/12 - 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 MSE-UCS correlation model of one or more reference wells is based on drilling parameters and well log data. The MSE-UCS correlation model is then used to generate a proxy mechanical earth model of an additional well being drilled using the drilling parameters of the additional well.
E21B 44/00 - Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systemsSystems specially adapted for monitoring a plurality of drilling variables or conditions
G06F 30/27 - Design optimisation, verification or simulation using machine learning, e.g. artificial intelligence, neural networks, support vector machines [SVM] or training a model
A wellbore production system includes a production tubing positioned within a wellbore and an electrical submersible pump (ESP) assembly positioned within the production tubing. The ESP assembly is a rigless ESP assembly that is conveyable within the production tubing by a conveyance line. The ESP assembly includes a high-speed helicoaxial pump a motor for driving the helicoaxial pump. A power transmission line extends from a surface of the wellbore outside of the production tubing and connects through the production tubing to the motor. The wellbore production system includes a gravity-assisted gas separator connected to the production tubing and connected to an intake of the ESP assembly.
The invention relates to the coupling of a metallurgical plant (2) to a dihydrogen production plant (3), for transferring (4) heat produced by the metallurgical plant (2) to an input stream of an electrochemical device of the dihydrogen production plant (3) and/or for feeding (100) to the metallurgical plant (2) one or more fluids formed by the electrochemical device.
A wellbore fluid includes an aqueous base fluid, and a fluid loss material formulated and configured to form a filtercake on surfaces of an earth formation responsive to exposure to a wellbore pressure. The fluid loss material includes at least one polymer, and a bridging material including a fatty acid salt of at least one of an alkali metal, an alkaline metal, ammonium, quaternary ammonium, a Group IIIA element, a Group IVA element, a Group VA element, a Group IB element, a Group IIB element, or a Group VIIB element of the periodic table, the bridging material comprising an oil-soluble material formulated and configured to dissolve out of the filtercake to form channels in the filtercake. Related methods and wellbore fluids are disclosed.
C09K 8/12 - Clay-free compositions containing synthetic organic macromolecular compounds or their precursors
C09K 8/588 - Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids characterised by the use of specific polymers
C09K 8/68 - Compositions based on water or polar solvents containing organic compounds
C09K 8/90 - Compositions based on water or polar solvents containing organic compounds macromolecular compounds of natural origin, e.g. polysaccharides, cellulose
E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
67.
COILED TUBING STRING MISSION PROFILE, DESIGN, AND OPTIMIZATION TOOL
Systems and methods presented herein are configured to optimize the design and validation of coiled tubing strings. For example, a processing workflow may include generating a mission profile for a coiled tubing (CT) string for deployment in a well based on CT analytics. The processing workflow may also include creating a CT string design for the CT string based at least in part on a plurality of operational parameters of the well. The CT string design of the CT string defines a plurality of physical characteristics of the CT string. The processing workflow may further include adjusting one or more of the plurality of physical characteristics of the CT string design of the CT string based at least in part on the generated mission profile for the CT string and a predicted life cycle of the CT string.
A method for sealing a wellbore is provided. The method includes positioning a tool including a radiation emitting device in a wellbore at a desired depth, emitting electromagnetic radiation at one or more frequencies, emitting the electromagnetic radiation includes emitting the electromagnetic radiation in a radial direction towards geological material disposed in the wellbore, melting the geological material with the electromagnetic radiation, and sealing at least a portion of the wellbore with the melted geological material.
Methods and related systems for drilling a subterranean wellbore includes rotating a bottomhole assembly (BHA) to drill the wellbore. The BHA includes a cutting tool and at least one sensor. The at least one sensor is configured to make measurements while drilling. These measurements are processed to compute a magnetic field profile, which is further processed to identify and characterize a signature or pattern in the magnetic field profile that is representative of a target well proximate to the wellbore being drilled. At least one of a distance or a direction to the target well can be computed based on characteristics of the signature or pattern in the magnetic field profile. The computed distance or direction to the target well can be used to control the direction of drilling of the wellbore.
G01V 3/30 - Electric or magnetic prospecting or detectingMeasuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for well-logging operating with electromagnetic waves
E21B 47/01 - Devices for supporting measuring instruments on drill bits, pipes, rods or wirelinesProtecting measuring instruments in boreholes against heat, shock, pressure or the like
This disclosure relates to systems and methods with multiple sensors located in different zones of a hydrocarbon production system. The multiple sensors are configured to capture parameters about flow through multiple zones of a wellbore. The system also includes a processor that is configured to obtain data about a multiphase flow through the plurality of zones of the wellbore of the hydrocarbon production system from the multiple sensors and to solve an interpretation problem for a first unknown in a bottommost zone. The processor is configured to use a value for the first unknown in the bottommost zone to solve for a second unknown in an upper zone that is above the bottommost zone in the wellbore of the hydrocarbon production system. The processor is configured to change control parameters of the hydrocarbon production system based at least in part on the first unknown and the second unknown.
A roller cone may include a innermost region having roller cone cutting elements arranged thereon such that the cutting elements may be closer to a radial axis of a drill bit. A roller cone may include a central region having roller cone cutting elements arranged thereon. The central region of a roller cone may also include multiple zones where the cutting element density within the central region and/or zones may vary between zones and/or regions. The cutting element density may be no less than 75% greater in one zone /or region than the cutting element density of another zone/or region.
A method of determining eccentricity of a tubular within a wellbore includes transmitting a sonic signal and receiving sonic waveforms based on detecting the sonic signal with sonic receivers positioned azimuthally around a sonic measurement tool. The sonic waveforms each include a tubular interference mode reflected and/or refracted from the tubular, and a casing interference mode reflected and/or refracted from a casing of the wellbore. The method includes generating an eccentricity waveform plot by combining the sonic waveforms and removing a monopole component, and generating an arrival time curve of the sonic waveforms to determine an earliest arrival time of the casing interference mode of one of the sonic waveforms. An eccentricity direction is determined as the azimuthal position of the earliest arrival time, and an eccentricity magnitude is determined with a tubular-eccentricity model based on the earliest arrival time.
An autonomous multiphase boosting (AMB) system (1) comprising an inlet pipe (30), equipped with a phase determination assembly (20), configured to determine a gas volume fraction and a mass rate of at least one phase in a multiphase inlet flow flowing in the inlet pipe; a multiphase pump (40); a fluid separator (50), configured to receive a multiphase boosted flow outputted by the multiphase pump and to separate a gas phase from a liquid phase of the multiphase booster flow, the liquid phase being outputted by a liquid outlet (53) to form a liquid flow; a return pipe (70), connecting the liquid outlet to the inlet pipe, the return pipe being equipped with at least a return valve (71); and a controller (80), configured to control the return valve based on the gas volume fraction determined by the phase determination assembly.
An electrical submersible pump system includes an electrical submersible pump (ESP) and a motor connector assembly (MCA) coupled to the ESP, such that the MCA includes an upper annular body including an outer circumferential annular surface, a lower annular body coupled to the upper annular body via a threaded connection, and a bearing sleeve assembly that includes a bearing sleeve, such that the bearing sleeve assembly is configured to mount on the outer circumferential annular surface.
Aspects of the present disclosure provide a method for insulating a cable. The method including applying a plurality of layers of an insulating material around a portion of a conductor of a cable, at least one layer of the plurality of layers including a first visual indicator, at least another layer of the plurality of layers including a second visual indicator, curing the plurality of layers to form an insulation layer having an outer diameter, removing a portion of the outer diameter of the insulation layer to reduce the outer diameter of the insulation layer to a desired diameter while maintaining a desired insulation layer thickness, and determining the desired diameter has been reached and the desired insulation thickness has been maintained based on an appearance of one of the first visual indicator or the second visual indicator.
A wellbore fluid includes a continuous phase comprising an oleaginous fluid, a discontinuous phase comprising a non-oleaginous fluid, an emulsion of the discontinuous phase in the continuous phase, at least one emulsifier disposed around droplets of the discontinuous phase, at least one gelling material comprising at least one of xanthan gum, scleroglucan gum, gellan gum, carrageenan gum, or curdlan gum, and at least one crosslinker dispersed within the non-oleaginous fluid of the discontinuous phase. Related methods and treatment fluids are also disclosed.
C09K 8/68 - Compositions based on water or polar solvents containing organic compounds
C09K 8/90 - Compositions based on water or polar solvents containing organic compounds macromolecular compounds of natural origin, e.g. polysaccharides, cellulose
C09K 8/588 - Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids characterised by the use of specific polymers
C09K 8/32 - Non-aqueous well-drilling compositions, e.g. oil-based
E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
The present disclosure relates to shaped charge. The shaped charge includes an explosive component having a first density and a first mechanical strength. The shaped charge also includes a liner member having a second density and a second mechanical strength. Further, the shaped charge includes an intervening liner member having a third density and a third mechanical strength. The intervening liner member is disposed between the explosive component and the liner member. The intervening liner member has one or both of: the third density being between the first density and the second density; and the third mechanical strength being between the first mechanical strength and the second mechanical strength.
Methods for geothermal well planning and development are provided. This includes: installing fiber optic cables that extend within a plurality of shallow wells, wherein the fiber optic cables support both DTS measurements and DAS measurements; connecting DTS interrogators to the fiber optic cables and configuring the DTS interrogators to measure temperature profiles in the plurality of shallow wells over time; determining planned location of one or more geothermal wells that access a geothermal reservoir from the measured temperature profiles; selecting at least one shallow well to be used for DAS measurements; at each selected shallow well, disconnecting the DTS interrogator from the fiber optic cable at the shallow well and connecting a DAS interrogator to the fiber optic cable at the shallow well; and configuring the DAS interrogator at each selected shallow well to measure an acoustic profile in the selected shallow well over time.
Methods and systems are provided for automated closed-loop control of drilling trajectory during directional drilling to a geological target, which employ a surface-located predictive controller that interfaces to and cooperates with a downhole trajectory control system to automatically control the drilling direction of a drilling tool during the directional drilling. The predictive controller is configured to receive data representing a new reference trajectory for a given measured depth and generate output data representing a sequence of set-points for the new reference trajectory. The predictive controller is further configured to communicate the output data to the downhole trajectory control system to automatically control the drilling direction of the drilling tool to follow the new reference trajectory.
E21B 44/00 - Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systemsSystems specially adapted for monitoring a plurality of drilling variables or conditions
An assembly for use in an electrical submersible pump includes a thrust runner. A shaft extends through the thrust runner. A plurality of grooves is formed in an exterior surface of the shaft. A ring disposed around the shaft includes an interior surface defining a bore. The interior surface includes a plurality of ribs protruding into the bore. Each rib is engaged with a corresponding groove of the plurality of grooves. A collar is disposed around the shaft and the ring. The collar includes a flange engaged with the thrust runner between the thrust runner and the ring.
E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
81.
METHODS FOR SELECTION OF COMPOSITION AND CONCENTRATION OF A CORROSION INHIBITOR PACKAGE USED IN STIMULATION OF SUBTERRANEAN FORMATIONS INVOLVING ACID-CONTAINING FLUIDS
The present disclosure relates to a method for stimulating a subterranean formation that includes selecting a wellbore for an acid stimulation treatment and initial pumping schedule using a wellbore treatment fluid system; obtaining information on metal used for pipe in the wellbore and a maximum corrosion rate threshold and/or a pitting index threshold to perform the acid stimulation treatment; determining composition and concentration of a corrosion inhibitor package for the wellbore treatment fluid system to obtain a corrosion rate and/or a pitting index of surfaces of the metal; updating the pumping schedule based on the determined composition and concentration of the corrosion inhibitor package; and performing hydraulic acid fracturing or an acidizing treatment using the updated pumping schedule.
A method including obtaining measurements of one or more first parameters of a packer during an actuation of the packer in a borehole, obtaining measurements of one or more second parameters related to a geometrical change in the borehole caused by the actuation of the packer, and analyzing a plurality of first and second parameters, a plurality of derivatives of the first and second parameters, or a combination thereof to estimate at least a static bulk modulus (K) of a geological formation surrounding the borehole.
E21B 49/02 - Testing the nature of borehole wallsFormation testingMethods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells by mechanically taking samples of the soil
E21B 33/1295 - PackersPlugs with mechanical slips for hooking into the casing actuated by fluid pressure
E21B 33/126 - PackersPlugs with fluid-pressure-operated elastic cup or skirt
A wireline cable with zinc-coated steel armor wires exposed at its exterior, is protected from corrosion by fluid, such as drilling fluid, in a wellbore by application of a coating of a viscous liquid composition, which may be a thixotropic grease, onto the exposed armor wires. The viscous liquid composition includes a viscous carrier and at least one substance which is an oxygen scavenger. The cable may also be protected by application of such a coating as it is withdrawn from a wellbore and rewound onto a storage drum.
A method can include receiving dielectric data from a downhole dielectric tool of a drillstring disposed in a borehole in a target material that includes a target material boundary between the target material and one or more other materials; generating a geosteering command, based at least in part on the dielectric data, that calls for orienting a drill bit of the drillstring with respect to the target material boundary; and issuing the geosteering command to a geosteering actuator of the drillstring.
E21B 44/00 - Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systemsSystems specially adapted for monitoring a plurality of drilling variables or conditions
E21B 49/00 - Testing the nature of borehole wallsFormation testingMethods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
Systems and methods of the present disclosure includes a mixer configured to mix air and hydrocarbons and a burner configured to receive the mixed air and hydrocarbons and to generate syngas. The system also includes a cooling system configured to receive the syngas and to cool the syngas to form cooled syngas. The system further includes a collector configured to collect carbon from the cooled syngas as soot. Moreover, the system includes a flare stack configured to receive the cooled syngas and to burn off at least part of the cooled syngas.
The present disclosure relates to a shaped charge. The shaped charge includes an explosive component and a liner member coupled to the explosive component. The explosive component and the liner member emit a perforating jet based on ignition of the explosive component. The liner member has a planar symmetric portion that is planar symmetric along an axial length of the planar symmetric portion relative to planes perpendicular to a direction of the emitted perforating jet.
Embodiments presented provide for a connection between high power sources to downhole equipment. In embodiments, methods and apparatus are presented to allow connection of power sources in hazardous environments, such as gaseous environments containing explosive hydrocarbons.
A method comprising validating a carbon dioxide injection operation plan at a carbon dioxide injection site, which comprises creating a first simulation model to simulate flow from the wellhead to a downhole environment and creating a second simulation model to simulate flow dynamics in a reservoir. The method further comprises conducting a carbon dioxide injection test operation based on the carbon dioxide injection plan at the carbon dioxide injection site and monitoring the carbon dioxide injection operation, which comprises measuring real-time data from the wellhead and the downhole, comparing the real-time data with the first simulation model, identifying risks from the comparison between the collected data in the first simulation model, and adjusting the carbon dioxide injection operation and based on the identified risks.
A technique facilitates drilling of a borehole by simplifying alignment between a running tool and a seal rotating system. According to an embodiment, the running tool is connected into a drill string. The drill string is then used to move the running tool linearly within the seal rotating system until engagement of an alignment mechanism occurs. With continued linear movement, the alignment mechanism automatically causes relative rotation between the running tool and the seal rotating system until a desired alignment position is achieved. The seal rotating system may then be secured to the running tool via threaded fasteners or other suitable fastening mechanism.
A milling bit valve is disclosed for improved debris collection within a wellbore. The check valve can be part of a debris removal tool that includes a motor, pump, gearbox, bailer, milling bit, check valve, and rotational shafts. In an example, on its uphole end, the milling bit can be coupled with the check valve. On its downhole end, the milling bit can be configured for debris removal with cutting edges. The downhole end can also include openings that provide access to an internal cavity of the milling bit. The internal cavity can extend the entire length of the milling bit. This allows the pump to pull drilling fluid into the bailers through the milling bit and check valve. As a result, the debris removal tool can simultaneously remove obstructions in a wellbore and collect debris from the obstruction removal.
E21B 29/00 - Cutting or destroying pipes, packers, plugs or wire lines, located in boreholes or wells, e.g. cutting of damaged pipes, of windowsDeforming of pipes in boreholes or wellsReconditioning of well casings while in the ground
E21B 31/00 - Fishing for or freeing objects in boreholes or wells
E21B 10/60 - Drill bits characterised by conduits or nozzles for drilling fluids
The invention relates to a facility (1) for producing dihydrogen, the facility comprising a water purification device (2), a heating device (3) for converting the purified water into steam, and an electrolyser (4) configured to produce at least one stream of dihydrogen from the steam. The heating device (3) is preferably configured to recover waste heat. The invention also relates to a corresponding method.
A method can include receiving channels of data during a controlled drilling operation performed by a drilling controller and an instrumented rig that includes a drawworks operable to control position of a drillstring that includes a drill bit; responsive to a change in a value in one of the channels of data, computing a maximum rate of penetration (ROP) reference value based at least in part on a portion of the data; generating a drawworks control command based at least in part on the maximum rate of penetration reference value; and issuing the drawworks control command to the drawworks for control of the position of the drillstring with respect to time.
A fluid testing system includes a fluid container with an inner surface that defines a chamber. The fluid testing system also includes a spray bar that extends circumferentially about at least a portion of the chamber, wherein the spray bar includes multiple cleaning fluid outlets to spray a cleaning fluid onto the inner surface that defines the chamber.
E21B 49/08 - Obtaining fluid samples or testing fluids, in boreholes or wells
E21B 49/10 - Obtaining fluid samples or testing fluids, in boreholes or wells using side-wall fluid samplers or testers
E21B 37/00 - Methods or apparatus for cleaning boreholes or wells
94.
NMR-BASED LITHIUM MEASURING AND MONITORING DOWNHOLE TOOLS, METHODS OF USING SAID DOWNHOLE TOOLS, AND METHODS OF MEASURING LITHIUM CONCENTRATIONS BASED ON NMR MEASUREMENTS ACQUIRED BY SAID DOWNHOLE TOOLS
NMR-based lithium measuring and monitoring downhole tools and methods measure at least one lithium concentration of a fluid in a borehole and/or a surrounding formation of the borehole, wherein the downhole tool has an NMR sensor having a magnet-coil geometry with at least one magnet and a RF coil tuned to match a Larmor frequency of a nucleus of lithium. The downhole tools and methods acquire an NMR-based lithium concentration measurement of a fluid at a sensitive region within the wellbore and/or formation that is defined by the magnet-coil geometry of the NMR sensor and determine a lithium concentration of the fluid at the sensitive region based on the acquired NMR-based lithium concentration measurement. The downhole tools and methods may interpret an acquired signal based on relaxation distributions of total acquired signals, wherein the acquired signal is indicative of the acquired NMR-based lithium concentration measurement and separate a lithium signal from confounding signals deriving from other non-lithium nuclei based on the interpretated acquired signal.
G01V 3/32 - Electric or magnetic prospecting or detectingMeasuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for well-logging operating with electron or nuclear magnetic resonance
G01V 3/14 - Electric or magnetic prospecting or detectingMeasuring magnetic field characteristics of the earth, e.g. declination or deviation operating with electron or nuclear magnetic resonance
E21B 47/12 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
E21B 49/08 - Obtaining fluid samples or testing fluids, in boreholes or wells
A fluid pressure compensation system includes a housing, an electric actuator, a power spring, a stem, a stroking bellows, and a plurality of compensation bellows. The electric actuator is disposed in the housing. The power spring is disposed in the housing. The stem is operatively connected to the electric actuator and the power spring and slidably moveable relative to the housing. The stroking bellows is sealably connected to the housing and the stem. The plurality of compensation bellows is sealably connected to and extends laterally outwardly from the housing.
An expandable tool includes a reamer block, a cutting element coupled to the reamer block, and a brake element embedded in the reamer block. The cutting element includes a cutting face extending to a gauge radius of the reamer block. The cutting element has a cutting rake angle formed on a radial plane between the cutting face and a normal line orthogonal to a borehole wall. The brake element includes an engagement face extending less than the cutting diameter. The brake element has a brake rake angle that is different than the cutting rake angle, such as by at least 45°. The brake rake angle is defined between the engagement face and the normal line.
E21B 10/32 - Drill bits with leading portion, i.e. drill bits with a pilot cutterDrill bits for enlarging the borehole, e.g. reamers with expansible cutting tools
E21B 47/01 - Devices for supporting measuring instruments on drill bits, pipes, rods or wirelinesProtecting measuring instruments in boreholes against heat, shock, pressure or the like
A ringout detection system may receive a plurality of surface weight-on-bit (SWOB) measurements from a surface weight-on-bit (WOB) sensor and a plurality of downhole weight-on-bit (DWOB) measurements from a downhole WOB sensor. A ringout detection system may identify a decrease in a WOB ratio between the plurality of SWOB measurements and the plurality of DWOB measurements. A ringout detection system may determine that the decrease in the WOB ratio exceeds a WOB ratio threshold. A ringout detection system may identify that ringout has occurred at the reamer based at least in part on the decrease in the WOB ratio.
E21B 44/00 - Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systemsSystems specially adapted for monitoring a plurality of drilling variables or conditions
E21B 47/01 - Devices for supporting measuring instruments on drill bits, pipes, rods or wirelinesProtecting measuring instruments in boreholes against heat, shock, pressure or the like
E21B 10/32 - Drill bits with leading portion, i.e. drill bits with a pilot cutterDrill bits for enlarging the borehole, e.g. reamers with expansible cutting tools
98.
DEVICES, SYSTEMS, AND METHODS FOR A CLEANING ELEMENT
A downhole tool includes a body having a longitudinal axis and a fluid passage extending through the body. The downhole tool includes at least one blade having one or more engagement faces thereon. At least one junk slot extends adjacent to the at least one blade. The downhole tool includes a cleaning element at the longitudinal axis of the body. The cleaning element has a substrate bore in fluid communication with the fluid passage. The cleaning element includes at least one opening or passing a fluid from the substrate bore and out of the downhole tool through the at least one junk slot. A flow direction of the at least one opening is offset from the longitudinal axis.
A downhole tool includes a body having a longitudinal axis and a fluid passage extending through the body. The downhole tool includes at least one blade having one or more engagement faces thereon. At least one junk slot extends adjacent to the at least one blade. The downhole tool includes a cleaning element at the longitudinal axis of the body. The cleaning element has a substrate bore in fluid communication with the fluid passage. The cleaning element includes at least one opening or passing a fluid from the substrate bore and out of the downhole tool through the at least one junk slot. A flow direction of the at least one opening is offset from the longitudinal axis.
Devices, systems, and methods for drying wet cuttings for imaging are described herein. In some examples, one or more embodiments include a device comprising a frame, a perforated liner connected to the frame, where the perforated liner is to receive cuttings generated from a downhole tool during a drilling operation, and a cap connected to a top portion of the frame to prevent the cuttings from exiting the perforated liner.
E21B 49/00 - Testing the nature of borehole wallsFormation testingMethods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
E21B 21/06 - Arrangements for treating drilling fluids outside the borehole
G01N 15/0227 - Investigating particle size or size distribution by optical means using imagingInvestigating particle size or size distribution by optical means using holography
G01N 15/08 - Investigating permeability, pore volume, or surface area of porous materials
