An electric chemical injection (eCI) system may comprise a first injection line, a first on-off valve, and a screen. The screen may comprise a bypass, the screen being positioned between the first injection line and the first on-off valve. A first T-connector may be positioned between the first injection line and the screen. A choke may be configured to allow a given amount of fluid to flow, and the choke may comprise an indexer. A calibration pressure device may be included. A check valve may be provided, and the check valve may comprise a check valve ball and a spring. The check valve may be configured to allow fluid flow from a surface to a well through the first injection line while preventing reverse fluid flow.
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
Embodiments presented provide for formation testing in geological stratum that exhibit low permeability. In embodiments, a drill pipe supplied acid and/or proppant is injected into the low permeability stratum through action of a formation tester, thereby altering the permeability of the geological stratum.
E21B 49/00 - Testing the nature of borehole wallsFormation testingMethods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
A method for analyzing drilling cuttings includes extracting a sample of drilling cuttings from a subterranean formation, the sample including consolidated particles and unconsolidated material. The method includes photographing the sample to produce a photograph, performing an image analysis on the photograph to identify segments of the photograph visualizing the unconsolidated material and excluding visualization of the consolidated particles, and analyzing the segments by performing at least one of a spectral measurement, a texture analysis, a grain size distribution analysis, or a reservoir parameter estimation of the segments. The method enables extraction of geological information from both consolidated and unconsolidated fractions of drilling cuttings samples that would otherwise be discarded in conventional sieving processes, thereby preserving subsurface information including grain size, mineral composition, and other parameters for comprehensive geological characterization of subterranean formations.
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
G01N 15/0227 - Investigating particle size or size distribution by optical means using imagingInvestigating particle size or size distribution by optical means using holography
The present disclosure provides a method for predicting a target log frequency distribution within a depth interval. The method includes extracting drilling cuttings from a reference well and capturing a plurality of photographs of the drilling cuttings, wherein each photograph corresponds to a specific depth interval of a plurality of depth intervals. The method includes obtaining a reference target log from the reference well covering the plurality of depth intervals and extracting a plurality of image features from each photograph. The method includes capturing property variability within each depth interval including converting the plurality of image features and the reference target log into normalized frequency distributions. The method includes predicting model property variability by training a prediction model using the normalized frequency distributions of the image features as input data and the normalized frequency distribution of the reference target log as output data.
E21B 44/04 - Automatic control of the tool feed in response to the torque of the drive
E21B 45/00 - Measuring the drilling time or rate of penetration
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
5.
INSTRUMENTED ENGAGEMENT ELEMENT WITH INCREASED WEAR RESISTANCE
An instrument assembly for taking downhole measurements includes an engagement element housing (524) configured to connect to a body of a downhole tool having a diaphragm (536). An engagement element (521) is positioned within the engagement element housing and is rotatable within the engagement element housing about an axis of rotation (560) of the engagement element. The axis of rotation of the engagement element is transverse to a longitudinal axis (562) of the engagement element housing. An engagement sensor (523) is positioned on the diaphragm and configured to take one or more measurements based on the engagement element engaging a formation. The instrument assembly includes electronics including a processor and a power source.
A method includes identifying a cutting element wear library containing a plurality of cutting element items (610). Cutting element information of the cutting element items includes wear information, position information, and context information for cutting elements implemented in wellbore forming operations. A target application data set includes a set of cutting element items corresponding with an application criteria based on the cutting element information for the plurality of cutting element items (630). The set of cutting element items are grouped into a plurality of radial intervals corresponding with a tool radius of a target downhole tool based on the position information (640). The method includes selecting a radial interval based on the wear information of the grouped cutting element items at each radial interval (650), and indicating to position the instrumented engagement element on the target downhole tool within a rotational path and rotationally behind a cutting element in the selected radial interval (660).
A downhole tool (410) for forming a wellbore in a formation includes a rotary engagement component (420) including one or more penetrating elements (424) for forming a plurality of penetrations in the formation defining a rotational sweep (430) of the rotary engagement component, and a cutting structure (412) formed on a body of the downhole tool having one or more cutting elements (423) positioned thereon for degrading the formation. The downhole tool includes an instrumented engagement element (421) positioned on the cutting structure and positioned to engage the formation at an engagement radius that is outside of the rotational sweep of the rotary engagement component, and an engagement sensor connected to electronics for taking one or more measurements associated with the instrumented engagement element engaging the formation.
A system may obtain one or more engagement measurements including at least one engagement measurement of a surface in a wellbore from an engagement sensor, wherein the engagement sensor is housed in an electronics housing positioned within a body of a downhole tool. A system may obtain accelerometer data from an accelerometer that is concurrent with the one or more engagement measurements. A system may correlate data variations in the one or more engagement measurements and in the accelerometer data, wherein the data variations are values outside of a threshold value. A system may identify at least one drilling dysfunction based on correlated accelerometer data and engagement measurements. A system may change at least one wellbore parameter based on the correlated accelerometer data and engagement measurements.
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 47/013 - Devices specially adapted for supporting measuring instruments on drill bits
E21B 47/10 - Locating fluid leaks, intrusions or movements
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 31/00 - Fishing for or freeing objects in boreholes or wells
An instrument assembly includes a housing positioned within a body of a downhole tool, and electronics positioned within the housing including a processor and a power source. An instrumented engagement element is connected to the body of the downhole tool and positioned to engage a formation. An engagement sensor is connected to the electronics for taking one or more measurements associated with the instrumented engagement element engaging the formation.
E21B 47/01 - Devices for supporting measuring instruments on drill bits, pipes, rods or wirelinesProtecting measuring instruments in boreholes against heat, shock, pressure or the like
E21B 47/013 - Devices specially adapted for supporting measuring instruments on drill bits
10.
SYSTEMS FOR REMOVING CARBON DIOXIDE FROM A CARBON DIOXIDE‑CONTAINING GAS, AND RELATED METHODS
A system for recovering carbon dioxide from a carbon dioxide-containing gas includes an absorber configured to absorb carbon dioxide from the carbon dioxide-containing gas with a non-aqueous solvent to form a carbon dioxide-lean gas, the non-aqueous solvent comprising a nitrogenous base, regenerator configured to remove the carbon dioxide from the non-aqueous solvent after the non-aqueous solvent is loaded with carbon dioxide, and an acid wash column configured to remove a second portion of the nitrogenous base from the carbon dioxide-lean gas with a buffered acid solution. Related systems and methods of removing carbon dioxide from a carbon dioxide-containing gas are also disclosed.
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
B01D 21/26 - Separation of sediment aided by centrifugal force
Embodiments described herein provide perforating guns having one or more perforating charges and an initiator assembly. The initiator assembly includes one or more detonators configured to cause detonation of the one or more perforating charges. In addition, the initiator assembly includes one or more mechanical components configured to be actuated to transition the initiator assembly from a first mechanical configuration to a second mechanical configuration, wherein a detonation circuit of the initiator assembly is open when the initiator assembly is in the first mechanical configuration and the detonation circuit of the initiator assembly is closed when the initiator assembly is in the second mechanical configuration.
xx) from a gas flow into a solvent of a solvent flow to produce a treated gas flow. The system includes a regenerator configured to strip the carbon oxides from the solvent flow to produce a captured carbon oxides flow. The system further includes a wash system configured to wash the treated gas flow using water. The system also includes an appendix stripper system configured to separate a outflow stream into a reclaimed amine stream and a waste stream, wherein the outflow stream comprises the solvent and degraded components of the solvent, and the waste stream has a greater concentration of the degraded components than in the reclaimed amine stream.
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 of operating an instrumented engagement element positioned at an engagement radius on a rotating downhole tool includes taking one or more first measurements with a sensor of the instrumented engagement element at a first sampling frequency based on the engagement radius and based on a first rotational speed of the downhole tool (510). The method includes identifying a change in rotational speed of the rotating downhole tool from the first rotational speed to a second rotational speed (520). The method further includes taking one or more second measurements with the sensor of the instrumented engagement element at a second sampling frequency based on the engagement radius and based on the second rotational speed (530).
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 47/013 - Devices specially adapted for supporting measuring instruments on drill bits
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
14.
IMPLEMENTING OPERATION MODES FOR INSTRUMENTED ENGAGEMENT ELEMENT THROUGH DOWNLINKS
A method of operating an instrumented engagement element positioned on a downhole tool, the instrumented engagement element configured for engaging a formation within a wellbore, includes operating, in a first operating mode, an instrument assembly positioned within a body of the downhole tool, the instrument assembly including the instrumented engagement element, a sensor of the instrumented engagement element, and a processor (510). The method includes receiving, with the instrument assembly, a downlink encoded via a downhole parameter (520). The method includes operating the instrument assembly in a second operating mode based on decoding the downlink (530).
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 47/013 - Devices specially adapted for supporting measuring instruments on drill bits
E21B 47/16 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling using acoustic waves through the drill string or casing
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
15.
THERMAL BARRIERS FOR INSTRUMENTED ENGAGEMENT ELEMENT
A system for taking downhole measurements includes an instrument assembly positioned within a body of a downhole tool. The instrument assembly includes a housing (314), and electronics (325) positioned within the housing including a processor (325-1) and a power source (325-2). The instrument assembly includes an instrumented engagement element (321) extending at least partially from the downhole tool and configured to engage a formation, and an engagement sensor (323) for taking one or more measurements associated with the instrumented engagement element engaging the formation. The system includes means (332) for preventing the electronics of the instrument assembly from exceeding a temperature threshold of the electronics.
A method of operating an instrumented engagement element positioned on a downhole tool, the instrumented engagement element configured for engaging a formation within a wellbore, includes, operating, in a first operation mode, an instrument assembly positioned within a body of the downhole tool, the instrument assembly including the instrumented engagement element, an engagement sensor of the instrumented engagement element, and a processor (510). The method includes monitoring, with one or more sensors of the instrument assembly, one or more downhole parameters within the wellbore (520), the method includes determining a trigger (530) based on identifying a trigger signature in the one or more downhole parameters. The method includes operating the instrument assembly in a second operation mode in response to the trigger (540).
E21B 44/00 - Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systemsSystems specially adapted for monitoring a plurality of drilling variables or conditions
E21B 45/00 - Measuring the drilling time or rate of penetration
E21B 47/013 - Devices specially adapted for supporting measuring instruments on drill bits
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
17.
INSTRUMENTED ENGAGEMENT ELEMENT AND METHODS OF USE
An instrument assembly for taking downhole measurements includes an electronics housing (314) positioned within a body of a downhole tool, a processor (325-1) positioned within the electronics housing, and a power source (325-2) positioned in the electronics housing. The instrument assembly includes an instrumented engagement element positioned on the downhole tool, wherein the instrumented engagement element extends from the downhole tool and is oriented to engage a wellbore wall of a wellbore. The instrument assembly includes an engagement sensor for taking measurements associated with the instrumented engagement element engaging the wellbore wall.
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
A method can include acquiring sensor data from a facility; quantifying greenhouse gas emissions from equipment components at the facility; determining uncertainty for the greenhouse gas emissions from the equipment components; and issuing a control instruction to the facility to reduce the greenhouse gas emissions or to reduce the uncertainty.
E21B 47/10 - Locating fluid leaks, intrusions or movements
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 41/00 - Equipment or details not covered by groups
Systems and methods for well integrity evaluation are provided. A method for managing well completion includes: obtaining measurement data for a well completion in a geological formation where a wellbore of a well is disposed, pre-processing the measurement data to obtain raw dispersion estimates of frequency slowness content of acoustic energy corresponding to at least one borehole mode, obtaining a dispersion image including dispersion image data using the raw dispersion estimates, based on an accumulation of raw estimated dispersion estimates of frequency-slowness content of borehole acoustic modes, generating a template image using a template dispersion curve corresponding to at least one vicinity of the template dispersion curve, extracting a dispersion quality image of a borehole mode, extracting a dispersion quality metric of the borehole mode, and determining a confidence value for at least one estimated well property for the well based on the dispersion quality, using the template dispersion curve.
22, wherein the fluid maintains a viscosity of at least 70 cp after exposure to temperatures of 200°F to 300°F for at least 90 minutes. The foam fluid demonstrates thermal stability at high temperatures and maintains stable viscosity under high temperature and pressure conditions, making the fluid suitable for hydraulic fracturing applications in high-temperature reservoirs.
C09K 8/60 - Compositions for stimulating production by acting on the underground formation
C09K 8/74 - Eroding chemicals, e.g. acids combined with additives added for specific purposes
C09K 8/92 - Compositions for stimulating production by acting on the underground formation characterised by their form or by the form of their components, e.g. encapsulated material
C09K 8/80 - Compositions for reinforcing fractures, e.g. compositions of proppants used to keep the fractures open
E21B 43/267 - Methods for stimulating production by forming crevices or fractures reinforcing fractures by propping
21.
ROLLER CONE HYBRID BIT WITH PDC GAUGE TRANSITION REGION
A drill bit with fixed blades and roller cones that has a bit cutting profile. The bit cutting profile is made up of the fixed cutting profile and the roller cone cutting profile such that fixed cutting elements are positioned outside of the gauge of the drill bit in a portion of the gauge region and where the roller cone cutting elements are positioned outward from the fixed cutting elements in the innermost, central and transition regions of the drill bit.
E21B 10/14 - Roller bits combined with non-rolling cutters other than of leading-portion type
E21B 10/16 - Roller bits characterised by tooth form or arrangement
E21B 10/20 - Roller bits characterised by detachable or adjustable parts, e.g. legs or axles
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 10/567 - Button-type inserts with preformed cutting elements mounted on a distinct support, e.g. polycrystalline inserts
E21B 10/627 - Drill bits characterised by parts, e.g. cutting elements, which are detachable or adjustable with plural detachable cutting elements
E21B 10/55 - Drill bits characterised by wear resisting parts, e.g. diamond inserts the bit being of the rotary drag type, e.g. fork-type bits with preformed cutting elements
A guide arm assembly for incorporation into a derrick at an oilfield rig. The assembly includes a vertical support and an articulating arm which are conscious of the limited derrick floorspace available. The vertical support is secured at a frame of a V-door which defines a V-doorway. The V-doorway defines a point of entry or exit to the derrick floorspace and is also outside of the derrick floorspace. An articulating arm is coupled to the vertical support and is configured for physically manipulated guidance of an implement from one location at the derrick floorspace to another location of the derrick floorspace that includes a well center that is positioned over a wellsite below the rig.
E21B 19/14 - Racks, ramps, troughs or bins, for holding the lengths of rod singly or connectedHandling between storage place and borehole
E21B 19/24 - Guiding or centralising devices for drilling rods or pipes
E21B 15/00 - Supports for the drilling machine, e.g. derricks or masts
E21B 19/087 - Apparatus for feeding the rods or cablesApparatus for increasing or decreasing the pressure on the drilling toolApparatus for counterbalancing the weight of the rods by means of a swinging arm
23.
TECHNIQUES FOR GENERATING AND/OR TRAINING A MODEL FOR PREDICTING PARAMETERS ASSOCIATED WITH WELL OPERATIONS
Systems and methods configured to generate and/or train a model using downhole measurements for one or more well operations. After the model is generated and/or trained, the model can thereafter be used to calculate or estimate one or more downhole parameters for one or more subsequent well operations based on surface data associated with the subsequent well operations.
E21B 47/10 - Locating fluid leaks, intrusions or movements
E21B 49/00 - Testing the nature of borehole wallsFormation testingMethods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
A cutting element includes a body defining an upper surface. The upper surface includes a cutting tip, wherein a backrake angle of the body varies along the upper surface from the cutting tip toward a longitudinal axis of the body. The upper surface also includes a back tip positioned opposite the cutting tip, wherein the cutting tip and the back tip are each positioned above a center point of the upper surface positioned at the longitudinal axis of the body. The upper surface further includes a first lateral side between the cutting tip and the back tip, the first lateral side being positioned below the center point, wherein a flange angle of the body varies along the upper surface from the cutting tip toward the longitudinal axis.
E21B 10/567 - Button-type inserts with preformed cutting elements mounted on a distinct support, e.g. polycrystalline inserts
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
A logging system for a subsurface operation includes: a probe positioned within a wellbore extending through a target formation, the probe generating pressure pulses that propagate within a target formation proximate to the wellbore; and a wireline extending along at least a portion of the wellbore. The wireline detects the pressure pulses and generates an electrical signal indicative of an effective flowing thickness of the target formation.
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 evaluating a mining site as a potential candidate for application of an emerging mining technology includes acquiring at least one report that provides information about the mining site and generating evaluation queries and criteria related to an application of the emerging mining technology to the mining site. An artificial intelligence (AI) based engine is used to extract query relevant information from the at least one acquired report; classify the extracted query relevant information using the generated criteria; and generate an applicability score that assesses the viability of utilizing the emerging mining technology to mine the mining site.
Systems and methods presented herein generally relate to introducing degradable fibers into a clean fluid having no proppants contained therein to produce a fiber-containing fluid, and injecting the fiber-containing fluid into a wellbore extending through a subterranean formation during a PAD stage of a hydraulic fracturing operation. In general, the systems and methods presented herein block fluid leak-off flow through walls of fractures created during hydraulic fracturing operations. Advantages include the ability to definitively minimize fluid damage to the reservoir because less fluid is used and there is less water consumption.
A cutting element may include a polycrystalline diamond (PCD) table. A cutting element may include a body including: a carbide substrate bonded directly to the PCD table, the carbide substrate including a first plurality of carbide particles and a first matrix phase interspersed between the carbide particles of the first plurality of carbide particles, and a base layer bonded directly to the carbide substrate, the base layer including a second plurality of carbide particles and a second matrix phase interspersed between the carbide particles of the second plurality of carbide particles, wherein the second plurality of carbide particles has a second grain size greater than a first grain size of the first plurality of carbide particles.
A gas rejection device for an electric submersible pump (ESP) protector has a first fluid chamber having a pressure equalization port proximate a top thereof in fluid communication with an exterior of the ESP. A second fluid chamber is disposed above the first fluid chamber. The first and second fluid chambers are arranged to be disposed between a pump of an ESP system and the ESP protector. The second fluid chamber is arranged to be placed in fluid communication with an oil reservoir in the protector. The device comprises a fluid passage between an upper end of the at least a second fluid chamber and the exterior of the ESP, wherein gas accumulated in the upper end vents to the exterior of the ESP.
A cutting insert may include a substrate body and a cutting volume. The cutting volume is a non-planar cutting volume with a plurality of intersecting curvatures that extend from a lateral surface of the substrate body to form a cutting ridge and an apex of the cutting insert. The substrate body and the cutting volume being within a defined form factor of the cutting insert.
A system for cooling drilling fluid on a drilling rig includes a heat exchanger and a solid-state chiller including at least one of a magnetocaloric chiller, an electrocaloric chiller, and an elastocaloric chiller. A first pump is configured to circulate drilling fluid through the heat exchanger and a second pump is configured to circulate a coolant through the solid-state chiller and the heat exchanger. The solid-state chiller is configured to cool the coolant circulating therethrough and thereby cool drilling fluid circulating through the heat exchanger.
A bit may include a body. A bit may include a plurality of blades extending from the body. A bit may include a bit connection extending uphole from the body. A bit may include a skirt extending from the body, the skirt extending at least partially over the bit connection to form an annular connection space between the skirt and the bit connection.
A toe valve system positioned along a tubing string. The toe valve system a piston sleeve slidably disposed in an outer housing which has ports therethrough. The toe valve system comprises a shifting sleeve shiftable between positions with respect to the ports. A piston sleeve initially held in a position closing off the at least one port to prevent flow between the interior and exterior of the tubing string. A compensator sleeve mounted within the outer housing, wherein the compensator sleeve is free floating and can accommodate changes in tubing pressure. A piston chamber filled with a liquid which is located between the piston sleeve, the compensator sleeve and the outer housing. The liquid in the piston chamber is retained by a rupture disk that can release the liquid when sufficient pressure is applied within the toe valve system causing the piston sleeve to move and opening the ports.
E21B 34/14 - Valve arrangements for boreholes or wells in wells operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools
E21B 34/06 - Valve arrangements for boreholes or wells in wells
A cutting element may include a table at a first longitudinal end in a longitudinal direction of a longitudinal axis, the table having a table outer diameter transverse to the longitudinal direction and the table including an ultrahard material. A cutting element may include a core having a core outer diameter that is less than the table outer diameter, the core being coupled to and configured to receive heat from the table. A cutting element may include an annular sleeve radially outside of the core with a sleeve outer diameter no less than the table outer diameter.
E21B 10/573 - Button-type inserts with preformed cutting elements mounted on a distinct support, e.g. polycrystalline inserts characterised by support details, e.g. the substrate construction or the interface between the substrate and the cutting element
B22F 7/06 - Manufacture of composite layers, workpieces, or articles, comprising metallic powder, by sintering the powder, with or without compacting of composite workpieces or articles from parts, e.g. to form tipped tools
A method for repairing, rejuvenating or reviving at least one aging, or degraded, or underperforming electrolyzer cell, including an oxygen electrode and a hydrogen electrode in to improve, or to enhance electrolysis efficiency and/or to extend the service lifetime of the electrolyzer cell. The method includes providing one or more activation solutions to the electrolyzer cell. The method also includes providing one or more deposition solutions including one or more metal ions to deposit the one or more metals onto at least one of the oxygen electrode and hydrogen electrode after providing the one or more activation solutions. Further, the method includes forming an oxygen evolution reaction (OER) electrocatalyst onto the oxygen electrode using an OER precursor solution, a hydrogen evolution reaction (HER) electrocatalyst onto the hydrogen electrode using a HER precursor solution, or both, after providing the one or more deposition solutions.
C25B 11/053 - Electrodes comprising one or more electrocatalytic coatings on a substrate characterised by multilayer electrocatalytic coatings
C25B 11/075 - Electrodes formed of electrocatalysts on a substrate or carrier characterised by the electrocatalysts material consisting of a single catalytic element or catalytic compound
A system includes a tool string, a kinematic assembly, and a pulley assembly. The kinematic assembly includes a first link and a second link. A first end portion of the first link is rotably coupled to the tool string and a first end portion of the second link is rotably coupled to the tool string. The pulley assembly includes a first pulley coupled to the tool string, and a first cable at least partially reeved about the first pulley. A first end of the first cable is coupled to the kinematic assembly, and a second end of the first cable is coupled to an actuation assembly. The kinematic assembly at least partially retracts into the tool string in response to the actuation assembly pulling the first cable.
E21B 23/00 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells
E21B 41/00 - Equipment or details not covered by groups
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
37.
SYSTEMS AND METHODS FOR EM-ASSISTED IN-SITU BIOMINING
Systems and methods for electromagnetic (EM)-assisted in-situ biomining are provided. A method for in-situ mining in a rock formation in an area of interest includes: receiving a first micro-organism from a micro-organism source at a first well extending downward from a ground surface in the area of interest, injecting the first micro-organism into a permeable layer of the rock formation via the first well to dissolve a target material to form a solution containing the first micro-organism and the target material, applying an electric field to the first micro-organism by the first well operating as a first electrode and a second well operating as a second electrode, such that the electric field stimulates activity of the first micro-organism, receiving the solution via the second well, and pumping the solution, via the second well, to a processing plant to separate the target material from the first micro-organism.
A method can include receiving a digital well plan for a well at a field site; predicting power demand for execution of an action specified by the digital well plan using a model; and, based at least in part on the predicted power demand, controlling equipment at the field site to perform the action while controlling a power system at the field site to deliver power to the equipment.
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 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
E21B 41/00 - Equipment or details not covered by groups
A wellbore fluid includes an aqueous base fluid including water, and at least one salt. The wellbore fluid further includes a corrosion inhibitor composition including at least one of morpholine or hydroxyethyl morpholine, and ascorbic acid. The corrosion inhibitor composition includes at least about 0.80 part by weight of the at least one of morpholine or hydroxyethyl morpholine per every about 1.0 part by weight of the ascorbic acid. Related wellbore fluids, corrosion inhibitor compositions, and methods are also disclosed.
An electric submersible progressive cavity pump (ESPCP) system may include a vortex gas separator assembly (VGSA), comprising a head comprising holes for inserting pin for installation, grooves disposed at both ends for the pin installation, a stator having an internal bore, and a rotor disposed in the internal bore of the stator. The ESPCP system may comprise a flexible shaft unit (FSU) between the VGSA and the ESPCP.
F04D 29/044 - Arrangements for joining or assembling shafts
E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
B01D 45/14 - Separating dispersed particles from gases or vapours by gravity, inertia, or centrifugal forces by centrifugal forces generated by rotating vanes, discs, drums or brushes
A system includes a connector body, and a chain slider having a U-shaped structure that is removably installed on the connector body. The chain slider may include an outer groove forming a translation path, and the outer groove may be configured to receive a chain that slides along the translation path.
B63B 21/20 - Adaptations of chains, ropes, hawsers, or the like, or of parts thereof
B63B 21/50 - Anchoring arrangements for special vessels, e.g. for floating drilling platforms or dredgers
B63B 73/20 - Building or assembling prefabricated vessel modules or parts other than hull blocks, e.g. engine rooms, rudders, propellers, superstructures, berths, holds or tanks
A system includes: a connector body, a chain wheel configured to receive a chain, an axle extending through the chain wheel, a first rotation plate disposed on the axle on a first side of the chain wheel, a second rotation plate disposed on the axle on a second side of the chain wheel, and first and second maintain plates affixed to the axle. The first and second rotation plates allow rotation of the chain wheel, and the first and second maintain plates are configured to maintain the first and second rotation plates, respectively, on the axle during an operation. The chain wheel is removably installed on the connector body via the first and second rotation plates.
B63B 21/50 - Anchoring arrangements for special vessels, e.g. for floating drilling platforms or dredgers
B63B 73/20 - Building or assembling prefabricated vessel modules or parts other than hull blocks, e.g. engine rooms, rudders, propellers, superstructures, berths, holds or tanks
A mesoporous carbon sorbent for removal of carbon dioxide from a gaseous material includes a BJH average pore width greater than about 3 nm, and a selectivity of carbon dioxide to nitrogen greater than about 20.00 at about 30°C, a partial pressure of carbon dioxide of about 114 mmHg, and a partial pressure of nitrogen of about 646 mmHg. Related mesoporous carbon sorbents, and methods of forming the carbon sorbents are also disclosure.
A system includes a gas leak instrument configured to monitor for gas leaks from an emission source, wherein the gas leak instrument includes a gas sensor, a wind sensor, and a controller coupled to the gas sensor and the least one wind sensor. The controller has a processor, a memory, and instructions stored on the memory and executable by the processor to cause operations including determining a baseline gas concentration in an environment based on first gas measurements from the gas sensor and first wind measurements from the wind sensor and determining an emission gas rate based on the baseline gas concentration, second gas measurements from the gas sensor second wind measurements from the wind sensor, and the Gaussian plume model.
A system includes a tool string and a caliper assembly. The caliper assembly includes one or more first calipers rotably coupled to the tool string. The one or more first calipers are circumferentially arrayed about a longitudinal central axis of the tool string. The caliper assembly also includes one or more second calipers rotably coupled to the tool string. The one or more second calipers are circumferentially arrayed about the longitudinal central axis. The caliper assembly also includes a drive element disposed within the tool string and slidably coupled to the tool string. The one or more first calipers extend from the tool string in response to the drive element moving to a first position. The one or more second calipers extend from the tool string in response to the drive element moving to a second position.
A system includes a connector body having a bore therethrough, a chain locker disposed at an end of the connector body, and one or more components removably attached to the connector body that guide a chain that moves in tension through the system. The chain locker is integrated with the connector body. Further, the chain locker is fully mechanical and is able to move between a use position, a lock position, and an unlock position with respect to the chain.
A system includes a controller having one or more processors. The system also includes a memory, and instructions stored on the memory, and executable by the one or more processors to output a control signal that causes an actuation of a valve to move a test distance via an electromechanical actuator; receive electrical property data corresponding to the actuation over the test distance by the electromechanical actuator; evaluate a condition of the valve based on the electrical property data; and generate an output based on the condition of the valve.
A system is provided that includes an imaging system used to obtain images of one or more solids extracted from a reservoir during a projectile motion of the one or more solids, a processing circuitry, and a memory, accessible by the processing circuitry, the memory storing instructions that, when executed by the processing circuitry cause the processing circuitry to perform operations. The operations include controlling the imaging system to obtain the images of the one or more solids during the projectile motion and obtaining one or more physical properties of the one or more solids based on the images of the one or more solids during the projectile motion.
G01N 23/04 - Investigating or analysing materials by the use of wave or particle radiation, e.g. X-rays or neutrons, not covered by groups , or by transmitting the radiation through the material and forming images of the material
G01N 23/12 - Investigating or analysing materials by the use of wave or particle radiation, e.g. X-rays or neutrons, not covered by groups , or by transmitting the radiation through the material and measuring the absorption the material being a flowing fluid or a flowing granular solid
E21B 47/002 - Survey of boreholes or wells by visual inspection
49.
SYSTEMS AND METHODS FOR SURFACE SUPERVISION OF A DOWNHOLE TOOL
A system may obtain azimuth and inclination measurements from a downhole tool in a downhole environment. A system may obtain a downhole ROP and downhole DLS from a downhole control unit. A system may determine a corrected DLS demand based at least partially on a ratio of downhole ROP and surface ROP. A system may transmit a DLS demand setting to the downhole tool based at least partially on the corrected DLS demand and the downhole ROP. A system may drill at least a portion of a borehole with the downhole tool based at least partially on the corrected DLS demand.
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
Certain embodiments of the present disclosure are directed to techniques for creating a filler material within a slickwater slurry. The filler material is generated by adding a cationic additive to the slickwater slurry. The cationic additive can be introduced to the slurry either before, after, or simultaneously with the proppant or friction reducer. Upon addition and mixing with the friction reducer, the cationic additive reacts due to electrostatic attraction, forming gel-like substances or agglomerates. This process, which may be termed complex coacervation, agglomeration, or aggregation, may entrap proppant particles during formation, with proppant particles possibly being trapped within these agglomerates or aggregates. The operation then proceeds as a slickwater treatment. After the proppant is delivered into the fracture and subsequently transported and settled, the agglomerates act as fillers within the proppant pack, thereby reducing its bulk density.
A method may include drilling a portion of a borehole with a bottomhole assembly (BHA) including the downhole tool in an automated drilling routine. A method may include receiving, at a control unit of the BHA, a disengagement downlink communication having a disengagement magnitude and disengagement duration. A method may include, based at least partially on the disengagement downlink communication, disengaging the automated drilling routine.
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
A method may include drilling a portion of the borehole with a bottomhole assembly (BHA) including a downhole tool. A method may include receiving, at the downhole tool, a zero pulse. A method may include receiving, at the downhole tool, a stand pulse. A method may include determining an added stand length based at least partially on the stand pulse. A method may include adding the added stand length to a total string length.
A geopolymer precursor includes an alkaline reactive solid material containing aluminum, silicon, and oxygen, and a fluid loss control material having an ionic stability property that has a first value in water and a second value in a 3M solution of NaOH, wherein a ratio of the second value to the first value is in a range of 0.5 to 2.0. The fluid loss control material may be, or may include a crosslinked polymer, which may include a reaction product of one or more of acrylamide, 2-acrylamido-2-methyl propane sulfonic acid, N,N‑dimethylacrylamide, N,N‑diethylacrylamide, vinyl acetate, or another monomer, and a crosslinker including one or more of methylene bisacrylamide, triallyl amine, pentaerythritol allyl ether, triallyl-triazine-trione, or another material. The geopolymer precursor may include an activator, an alkaline solution having pH of at least about 9, or both.
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
C09K 8/487 - Fluid loss control additivesAdditives for reducing or preventing circulation loss
54.
PRESSURE AND/OR TEMPERATURE MONITORING OF AN ANNULUS
A system for monitoring an annulus in a well includes an inductive coupler. The inductive coupler includes a body, a power coil disposed around a first portion of the body, and a telemetry coil disposed around a second portion of the body separate from the first portion. A hole extends within the body, and a sensor is disposed in the hole.
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
55.
SYSTEMS AND METHODS FOR DEVELOPING AND UTILIZING A SURROGATE MODEL TO ESTIMATE PRODUCTION FLOW RATES FOR A WELL
A method including receiving a plurality of constraints related to extraction of hydrocarbons from a subsurface formation, running one or more simulations based on the constraints, determining an interference boundary based on the one or more simulations, wherein the interference boundary includes a distance between fractures where the interactions between the fractures are below a threshold value, organizing results of the one or more simulations into a first dataset associated with distances between the fractures less than the interference boundary and a second dataset associated with distances between the fractures greater than the interference boundary, generating a first predictive model based on the constraints and the first dataset and a second predictive model based on the constraints and the second dataset, generating a surrogate model based on the first predictive model and the second predictive model, and controlling one or more drilling tools based on the surrogate model.
A method includes receiving input data from a receiver operating in a subterranean environment. The method also includes receiving a set of hyperparameters based on the input data, wherein the set of hyperparameters are associated with the reception of the input data in the subterranean environment. Further, the method includes utilizing a Bayesian optimization policy to iteratively select a plurality of observation points from the set of hyperparameters. Further still, the method includes obtaining a performance metric value for each of the selected observation points. Further still, the method includes selecting a hyperparameter from the set of hyperparameters based on the performance metric values. Even further, the method includes generating corrected input data based on the selected hyperparameter.
A method for valve actuation includes detecting, via a sensor, a subterranean fluid property at a location near to the sensor, sending a first signal to a controller, where the first signal is indicative of the subterranean fluid property at the location proximate to the sensor, and converting the first signal into a second signal, where the second signal is indicative of a subterranean fluid property at a location near a valve. The method further includes determining a downhole condition based on the second signal and actuating the valve based on the downhole condition.
Embodiments of the disclosure provide for methods and apparatus related to fluid testing for geological analysis. Aspects disclose methods and apparatus related to fluid testing for carbon dioxide content in water. Embodiments enable precise detection and quantification of fluid properties in geological samples, supporting enhanced characterization of subsurface formations. The approaches further facilitate accurate measurement of carbon dioxide levels dissolved in water, allowing for environmental assessment and monitoring of geochemical processes. Such methods and apparatus are adaptable to a variety of geological settings, ensuring reliable results across diverse sample types and field 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
E21B 49/10 - Obtaining fluid samples or testing fluids, in boreholes or wells using side-wall fluid samplers or testers
E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
G01N 21/49 - Scattering, i.e. diffuse reflection within a body or fluid
A solids testing system includes a solids/liquids separator with a container and a screen. The solids testing system also includes an imaging device and a controller configured to control the solids/liquid separator to facilitate separation of a large solids fraction from a first fluid flow; control, the imaging device to capture imagery of the large solids fraction remaining on a first side of the screen after the separation of the large solids fraction from the first fluid flow; and analyze the imagery to identify one or more characteristics of the large solids fraction remaining on the first side of the screen after the separation of the large solids fraction from the first fluid flow. The solids testing system may identify one or more additional characteristics of a small solids fraction in the first fluid flow, wash and/or dry the large solids fraction, and/or dilute the small solids fraction.
A method may mix a nanodiamond powder with a salt to create a nanodiamond-salt mixture. A method may sinter the nanodiamond-salt mixture under high-pressure high-temperature (HPHT) conditions for a sintering duration to create a sintered nanodiamond-salt block. A method may wash at least a portion of the sintered nanodiamond-salt block with a fluid. A method may dissolve at least a portion of the salt from at least one fluorescent nanodiamond (FND) of the sintered nanodiamond-salt block. A method may separate a fluorescent nanodiamond from the salt.
A sealing device for sealing an interface between a first surface and a second surface includes a primary sealing element for forming a primary seal at the interface and a carrier body that is slidable with respect to the interface to engage the primary sealing element. A carrier sealing element is positioned on the carrier body, and is configured to seal the interface with a secondary seal. The carrier body is slidable to engage the primary sealing element based on the secondary seal sealing the interface.
A method includes receiving a reimaging package. The method also includes loading the reimaging package to a non-volatile memory of a computing system that stores a first disk in the volatile memory. Further, the method includes adjusting a firmware of the computing system based on the reimaging package. Further still, the method also includes performing a power cycle of the computing system based on the adjusted firmware. Even further, the method includes loading the reimaging package to a volatile memory of the computing system after the first power cycle. Even further, the method includes reimaging the computing system based on the reimaging package loaded to the volatile memory of the computing system.
G06F 11/14 - Error detection or correction of the data by redundancy in operation, e.g. by using different operation sequences leading to the same result
G06F 11/10 - Adding special bits or symbols to the coded information, e.g. parity check, casting out nines or elevens
An embodiment of a system includes an actuation assembly for a blowout preventer (BOP) stack. The actuation assembly includes a reservoir of actuation fluid at atmospheric pressure, a pump coupled to the reservoir to pressurize the actuation fluid, and a plurality of valves coupled between the pump and the BOP stack. Actuation of the valves is configured to communicate the actuation fluid to seal assemblies of the BOP stack. In addition, the system includes a controller coupled to the valves. The controller is configured to: receive an input indicative of an instruction to shut-in a wellbore and autonomously shut-in the wellbore in response to the input by actuating at least a subset of the valves according to a selected emergency function sequence of a plurality of emergency function sequences that are stored in a memory.
Embodiments presented provide for stress testing of downhole wireline formation testing equipment. Certain embodiments provide for stress testing of geological stratum which exhibit high permeability. A method to perform a stress test is disclosed. The method may comprise conveying a bottom hole assembly on a drill pipe to a testing location and setting at least two packers at the testing location. The method may comprise performing an injection of a fluid obtained from the drill pipe into the testing location and stopping the injection of the fluid from the drill pipe. The method may comprise performing at least one breakdown cycle injection with the fluid from the drill pipe and determining when the at least one breakdown cycle injection with fluid results in an open reservoir. The method may comprise performing an injection followed by falloff cycles using surface based pumps and deflating the at least two packers.
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 49/08 - Obtaining fluid samples or testing fluids, in boreholes or wells
E21B 33/129 - PackersPlugs with mechanical slips for hooking into the casing
E21B 23/06 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for setting packers
63063063063030 cycloalkyl acid. The wetting agent includes an alcohol alkoxylate. A ratio of the oil to the aqueous phase is about 85:15 to about 60:40 of the oil to the aqueous phase
Systems and methods for geological basin modeling are provided. A method includes: obtaining data representative of a plurality of cell areas of a geological basin having a reservoir including a target resource, the data including: a thickness of the reservoir in each cell area, a porosity of the reservoir in each cell area, and a concentration of a target resource in the reservoir in each cell area, calculating an amount of the target resource in each cell areas of the geological basin by multiplying the cell area, the thickness of the reservoir in the cell area, the porosity of the reservoir in the cell area, and the concentration of a target resource in the reservoir in the cell area, and displaying a map corresponding to the calculated amount of the target resource in the geological basin based on the amount of the target resource calculated for each cell area.
A binder composition includes a cement composition, a geopolymer composition, or a combination thereof. The binder composition includes a binder material including at least one of cement or at least one aluminosilicate source, a lost circulation composition, and a sodium silicate. The lost circulation composition includes a first fiber material including nylon having an average length from about 5.0 mm to about 25.0 mm, and a second fiber material including chopped glass. Related methods and geopolymer compositions are also disclosed.
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
C09K 8/487 - Fluid loss control additivesAdditives for reducing or preventing circulation loss
68.
GEOPOLYMER COMPOSITIONS INCLUDING A FLUID LOSS CONTROL MATERIAL, AND RELATED GEOPOLYMER SLURRIES AND METHODS
A geopolymer composition includes a solid alkaline reactive material comprising aluminum, silicon, and oxygen, a swellable clay material, the geopolymer composition including from about 0.5 weight percent to about 3.0 weight percent of the crystalline clay material by weight of the alkaline reactive material, another fluid loss control material, and a salt. The salt may constitute from about 0.5 weight percent to about 3.0 weight percent of the geopolymer composition by weight of aluminosilicate, and may be an organic salt, an inorganic salt, or combination thereof. Related geopolymer slurries and methods are also disclosed.
C09K 8/487 - Fluid loss control additivesAdditives for reducing or preventing circulation loss
C09K 8/467 - Compositions for cementing, e.g. for cementing casings into boreholesCompositions for plugging, e.g. for killing wells containing inorganic binders, e.g. Portland cement containing additives for specific purposes
C04B 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 compound for insulation may include a polymer and a filler. A method for insulating a wire using said compound comprises melting a polymer to form a molten polymer, mixing the molten polymer with a filler to form an insulation compound, applying the insulation compound along a wire, and cooling the insulation compound at a controlled rate to form a uniform crystal.
H01B 3/02 - Insulators or insulating bodies characterised by the insulating materialsSelection of materials for their insulating or dielectric properties mainly consisting of inorganic substances
H01B 3/42 - Insulators or insulating bodies characterised by the insulating materials; Selection of materials for their insulating or dielectric properties mainly consisting of organic substances waxes polyesters, polyethers, polyacetal
H01B 7/29 - Protection against damage caused by external factors, e.g. sheaths or armouring by extremes of temperature or by flame
A well cementing system may flow a carrier fluid into an annulus defined between an outer surface of a casing and a wellbore wall, the carrier fluid including reactive particles having a particle size between 1 nm and 1 μm. A well cementing system may coat at least a portion of an annular surface of the annulus with the reactive particles, the reactive particles formulated and configured to react with a reactant in the annulus to cause the reactive particles to increase in volume.
A cutting element including a base. The base including a cylindrical body having a body axis, and where the cylindrical body defines a fluid bore extending at least partially therethrough along to the body axis. A fluid conduit in fluid communication with the fluid bore and oriented transverse to the body axis. A cutting support extending from the cylindrical body and a ultrahard layer joined to the cutting support such that a cutting surface of the ultrahard layer is oriented transverse to the body axis.
A subsea winch assembly that includes a winch, a spooling device attached to the winch, one or more motor drive system attached to the winch and the spooling device, an outer housing to encase the winch and the one or more motor drives, and a bladder system located inside the outer housing, wherein the spooling device is located outside of the outer housing. In another embodiment, a subsea winch assembly arrangement is described to include a winch, a spooling device attached to the winch, one or more motor drive system attached to the winch and the spooling device, an outer housing to encase the winch, the spooling device, and the one or more motor drives, and a bladder system located inside the outer housing.
Systems and methods for performing local optimization of rock property estimation in geological formations are provided. A method includes: drilling into a rock formation using first drilling parameters, acquiring local data from a first sample from the drilling, acquiring test data from a second sample, selecting a local model input and output, receiving a pre-trained global model including a global model input and output, accessing the global model to extract global weights for global neuron layers, passing the global weights to a local model, training the local model with the local data using the passed global weights to generate local weight(s) corresponding to local neuron layer(s), feeding the test data into the trained local model to generate a prediction output, and based on the prediction: generating second drilling parameters to optimize drilling of the rock formation, and drilling into the rock formation using the second drilling parameters.
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 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
G01V 1/40 - SeismologySeismic or acoustic prospecting or detecting specially adapted for well-logging
G01V 3/32 - Electric or magnetic prospecting or detectingMeasuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for well-logging operating with electron or nuclear magnetic resonance
A method of manufacturing a corrosion-resistant wireline cable includes embedding a first layer of armor wires onto a core cable using a heated carbon fiber reinforced polymer. A second layer of carbon fiber reinforced polymer is then extruded to envelop the first layer of armor wires. In one method, a layer of virgin or colored polymer is extruded over the second layer, and a second layer of armor wires is embedded through the virgin or colored polymer, displacing it to envelop the outer armor wires. In another method, each wire in the second armor layer is coated with virgin polymer before being embedded into the second carbon fiber reinforced polymer layer. The assembly is then heated to cause the virgin polymer to migrate outward, forming an outermost layer. In both methods, a final jacket layer is applied over the exterior to complete the cable. The resulting cable provides corrosion resistance and mechanical reinforcement.
H01B 7/28 - Protection against damage caused by external factors, e.g. sheaths or armouring by moisture, corrosion, chemical attack or weather
H01B 3/44 - Insulators or insulating bodies characterised by the insulating materialsSelection of materials for their insulating or dielectric properties mainly consisting of organic substances plasticsInsulators or insulating bodies characterised by the insulating materialsSelection of materials for their insulating or dielectric properties mainly consisting of organic substances resinsInsulators or insulating bodies characterised by the insulating materialsSelection of materials for their insulating or dielectric properties mainly consisting of organic substances waxes vinyl resinsInsulators or insulating bodies characterised by the insulating materialsSelection of materials for their insulating or dielectric properties mainly consisting of organic substances plasticsInsulators or insulating bodies characterised by the insulating materialsSelection of materials for their insulating or dielectric properties mainly consisting of organic substances resinsInsulators or insulating bodies characterised by the insulating materialsSelection of materials for their insulating or dielectric properties mainly consisting of organic substances waxes acrylic resins
A drilling system and techniques for managing dynamic load during drilling operations. The system includes a drilling device prone to propagate a dynamic load such as vibration and/or shock during drilling and electronics that may be susceptible to such dynamic loads. Thus, a control unit is provided that is configured for communications with both the electronics and with equipment directing the drilling operations. The unit also accommodates processing for directing the operations in terms of adjustment to drilling device rpm and/or weight on bit as applied to the device depending on monitoring of the dynamic load and in light of certain dynamic thresholds. Thus, real-time operational adjustments may be made to avoid dynamic load damage to electronics while maintaining efficient drilling operations.
E21B 7/02 - Drilling rigs characterised by means for land transport, e.g. skid mounting or wheel mounting
E21B 17/20 - Flexible or articulated drilling pipes
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 operating a conveyance system implemented in a wellbore includes receiving surface measurements including surface load measurements, surface speed measurements, and depth of tool measurements for the conveyance system. The method includes, with a failure model, generating a threshold associated with at least one of a maximum run-in-hole speed, a maximum pull-out-of-hole speed, a maximum load, a minimum load, or a maximum depth of tool for the conveyance system. The method further includes adjusting the movement of the conveyance system based on identifying that the surface measurements surpass the threshold.
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 23/00 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells
77.
SYSTEMS AND METHODS FOR FACILITATING EFFECTIVE FRACTURE INITIATION
Systems and methods presented herein are configured to facilitate effective fracture initiation. For example, a method includes deploying a tool string into a wellbore extending through a subterranean formation, wherein the tool string comprises a perforating tool and a mechanical reactant delivery assembly; releasing a plurality of chemical reactants from the mechanical reactant delivery assembly while the tool string is deployed within the wellbore to enable the plurality of chemical reactants to mix to form a breakdown fluid; and firing one or more explosive charges of the perforating tool to inject the breakdown fluid into the subterranean formation to initiate one or more fractures in the subterranean formation.
A system and method are provided for stimulating heterogeneous subterranean formations using a tailored particulate diverter (PD). In some embodiments, a wellbore completion string includes an inflow control device (ICD) positioned in a high-permeability zone and an additional completion section positioned in a lower-permeability zone. The ICD includes restrictive openings, such as nozzles or valves, configured to impose a predictable pressure drop to balance inflow during production. During stimulation, the tailored particulate diverter comprising degradable diverter particles suspended in a carrier fluid is pumped into the completion string. The diverter particles exhibit a multimodal particle size distribution with at least four distinct size modes selected to bridge and seal the restrictive openings of the ICD, diverting stimulation fluid into the lower-permeability zone. Following treatment, the diverter particles degrade under downhole conditions to restore flow through the restrictive openings, improving stimulation coverage and enhancing overall production and/or injection efficiency.
E21B 43/38 - Arrangements for separating materials produced by the well in the well
E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
E21B 43/26 - Methods for stimulating production by forming crevices or fractures
79.
DETERMINATION OF CLUSTERS STIMULATION EFFICIENCY USING OFFSET WELL MONITORING WITH FIBER OPTICS AND ARTIFICIAL INTELLIGENCE SURFACE DATA PROCESSING OF THE STIMULATED WELL
Embodiments presented provide for determination of stimulation efficiency, In embodiments, offset well monitoring is performed with fiber optics and the data gains from the fiber optics are processed through an artificial intelligence system to calculate stimulation efficiency. A method is provided to calculate at least one value related to a hydraulic fracturing job being performed at a wellbore. The method may comprise measuring a formation strain rate at an offset wellbore. The method may further comprise obtaining pressure, rate, concentration data related to the wellbore. The method may further comprise calculating a most probable fracture parameter using a machine learning based algorithm. The method may further comprise recalculating the formation strain rate at the offset wellbore based upon a strain rate propagation model. The method may further comprise performing iterative calculations.
Embodiments presented provide for hydraulic fracture monitoring. The monitoring uses real-time pumping data as well as low-frequency acoustic data that is fed into a machine learning algorithm to precisely determine hydraulic fracturing monitoring.
Methods and systems for managing enhanced geothermal system fields are provided. The fields may be managed by monitoring the fields using both point and distributed sensors. Measurements from the sensors may be used to model the fields, and potential scenarios for the fields. The measurements may also be used to revise the models for the fields, such as corrections of incorrect assumptions regarding the fields. The models may also be used to proactively alert and/or take automated actions to address occurrence of undesired events in the fields.
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
82.
CONTROL SYSTEMS AND METHODS FOR RCD ACTIVE PRESSURE COMPENSATION
A method for operating a system for in-situ mining in a rock formation in an area of interest includes: receiving a lixiviant at a first well extending downward, injecting the lixiviant into a permeable layer of the rock formation via the first well to dissolve a target material to form a solution containing the lixiviant and the target material, and applying an electric field to at least one of the lixiviant or the solution by the first well as a first electrode and a second well as a second electrode, receiving the solution via the second well extending downward, and pumping the solution, via the second well, to a processing plant to separate the target material from the lixiviant, wherein one or both of the injecting the lixiviant or the applying the electric field are changed according to a timing sequence during an operational period of the in-situ mining.
Aspects of the disclosure provide techniques and apparatus for performing predictive health management for a fiber optic monitoring system. An example technique includes obtaining an indication of one or more parameters of a fiber optic monitoring system for one or more well completions. The fiber optic monitoring system includes at least one monitoring device and one or more fiber optic cables coupled to the at least one monitoring device. At least one failure mode of the fiber optic monitoring system is predicted based at least in part on evaluating the one or more parameters with one or more trained machine learning (ML) models. An indication of the at least one failure mode is provided.
A system is provided that includes an intake system configured to supply a blended well fluid to a metal extraction system. The intake system includes a manifold including a plurality of fluid inlets, an internal flow path coupled to the plurality of fluid inlets, and a fluid outlet coupled to the internal flow path. The intake system also includes a plurality of sensors used to obtain sensor feedback of one or more parameters of the plurality of well fluids. The plurality of flow controls is coupled to each of the plurality of fluid inlets and the plurality of flow controls to adjust a blend of the one more parameters in the blended well fluid including metal within a concentration range used for metal extraction by the metal extraction system.
The invention relates to a facility (2) for producing dihydrogen, comprising: • a heating system (6) configured to provide at least one heated-water stream (8); and • an electrochemical system (4) which has a plurality of stacks (10), each configured to produce an outlet gas stream (12) from a respective heated-water stream; the heating system comprising: • a primary heating device (18) configured to bring the inlet water stream to an intermediate temperature, so as to form an intermediate water stream (22); and • a plurality of secondary heating devices (20), each being connected at the outlet of the primary heating device (18) so as to receive a respective fraction of the intermediate water stream, and being configured to bring the fraction received to a nominal operating temperature of a corresponding stack (10), so as to form the heated-water stream (8) supplying the stack (10).
Embodiments of the disclosure provide for methods and apparatus related to downhole tool intervention activities. Aspects disclose methods and apparatus related to a system and method to intercept components lost or dropped during field wellbore activities. These systems are designed to enhance operational efficiency and safety by ensuring the recovery and management of critical components in challenging wellbore environments.
Systems and methods for horizontal wells for in-situ mining are provided. A system for in-situ mining includes: an injection well including: a first vertical portion (VP) extending downward from a ground surface, the first VP receiving a lixiviant, and a first horizontal portion (HP) connected to the first VP and extending horizontally through the ground, the first HP receiving the lixiviant from the first VP, and injecting the lixiviant into the ground to dissolve a target material forming a solution, and a production well including: a second HP extending horizontally parallel to the first HP through the ground, the second HP receiving the solution from the first HP, and a second VP connected to the second HP and extending upward to the ground surface, the second VP: receiving the solution from the second HP, and pumping the solution to a processing plant to separate the target material from the lixiviant.
A temperature sensing device for use with a tubular in a wellbore includes a housing configured to mount to an outer surface of the tubular, the housing having a first sensor port and a second sensor port. The temperature sensing device includes a first sensor positioned in the first sensor port and positioned in an annular space around the tubular such that the first sensor directly contacts a flow of an annular fluid flowing in the annular space. The temperature sensing device also includes a second sensor positioned in the second sensor port and positioned flush with an inner surface of the tubular to directly contact a flow of a tubing fluid within the tubular without disrupting the flow of the tubing fluid.
Systems and methods including a screen assembly with a screen frame configured to couple to a screen filter. The screen frame includes a leading edge with a ramp to facilitate sliding the screen frame relative to a clamp of a shaker system. The leading edge may contain an engagement surface and/or mechanism that can help facilitate the clamping of the screen within the shaker system as well as allow for one screen to be engaged with another screen.
Described herein are methods of recovering metal ions from thermally treated earth materials and/or making polymers from the thermally treated earth materials. A thermally treated earth material is obtained, for example by treating an earth material using plasma, microwaves, flash calcination, or any combination thereof. A metal is removed from the thermally treated earth material, for example by mixing with an organic solvent or aqueous solution having pH less than about 9. The remaining earth material is alkali reactive and can be formed into an aluminosilicate polymer by exposure to a high pH aqueous solution.
B01J 19/08 - Processes employing the direct application of electric or wave energy, or particle radiationApparatus therefor
B01J 19/12 - Processes employing the direct application of electric or wave energy, or particle radiationApparatus therefor employing electromagnetic waves
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
C22B 3/06 - Extraction of metal compounds from ores or concentrates by wet processes by leaching in inorganic acid solutions
C22B 3/16 - Extraction of metal compounds from ores or concentrates by wet processes by leaching in organic solutions
C22B 3/22 - Treatment or purification of solutions, e.g. obtained by leaching by physical processes, e.g. by filtration, by magnetic means
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
C22B 3/42 - Treatment or purification of solutions, e.g. obtained by leaching by ion-exchange extraction
C22B 3/44 - Treatment or purification of solutions, e.g. obtained by leaching by chemical processes
C22B 4/00 - Electrothermal treatment of ores or metallurgical products for obtaining metals or alloys
B01D 45/02 - Separating dispersed particles from gases or vapours by gravity, inertia, or centrifugal forces by utilising gravity
B01D 45/12 - Separating dispersed particles from gases or vapours by gravity, inertia, or centrifugal forces by centrifugal forces
B01D 45/16 - Separating dispersed particles from gases or vapours by gravity, inertia, or centrifugal forces by centrifugal forces generated by the winding course of the gas stream
B01D 61/00 - Processes of separation using semi-permeable membranes, e.g. dialysis, osmosis or ultrafiltrationApparatus, accessories or auxiliary operations specially adapted therefor
B01J 8/00 - Chemical or physical processes in general, conducted in the presence of fluids and solid particlesApparatus for such processes
B01J 8/08 - Chemical or physical processes in general, conducted in the presence of fluids and solid particlesApparatus for such processes with moving particles
B01J 8/18 - Chemical or physical processes in general, conducted in the presence of fluids and solid particlesApparatus for such processes with fluidised particles
B04C 3/02 - Apparatus in which the axial direction of the vortex remains unchanged with heating or cooling, e.g. quenching, means
A method of removing a calcareous material from sand while processing the sand includes mining sand at a location proximate a wellbore extending into an earth formation, and contacting the sand with an aqueous treatment fluid to remove calcareous materials from the sand and form treated hydraulic fracturing sand, the aqueous treatment fluid including a corrosion inhibitor composition. The corrosion inhibitor composition includes an alkenylphenone, and a substituted 1-azanapthalene. Related methods of inhibiting corrosion and of sand processing equipment during processing of hydraulic fracturing sand and removing calcareous materials from sand are also disclosed.
A system and method for determining the location of a droppable object in a wellbore. The droppable object includes an integrated locating system that detects completion components as the object moves through a casing string. The locating system includes an actuation device that is activated based on detection of the components. When activated, the actuation device exerts a radially directed frictional pressure against the inner wall of the casing string, thereby generating pressure pulse telemetry signals that are detected and analyzed by surface equipment to determine the object's downhole location.
E21B 47/092 - Locating or determining the position of objects in boreholes or wellsIdentifying the free or blocked portions of pipes by detecting magnetic anomalies
E21B 33/16 - Methods or devices for cementing, for plugging holes, crevices or the like for cementing casings into boreholes using plugs for isolating cement chargePlugs therefor
Geopolymer precursors are presented that are useful for subterranean wells. The precursors contain an aluminosilicate source, an alkali activator, an acid responsive solid component, and an aqueous medium. The acid responsive solid additive allows the geopolymer system obtained from hardening the geopolymer precursor to be altered by treatment using acid.
C09K 8/467 - Compositions for cementing, e.g. for cementing casings into boreholesCompositions for plugging, e.g. for killing wells containing inorganic binders, e.g. Portland cement containing additives for specific purposes
C04B 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
The present disclosure also generally provides methods of recovering oil. The methods include receiving data representing one or more physical characteristics of a subterranean formation. A first model of the subterranean formation is obtained. An oil phase proximal to an oil-water contact is identified based on the first model of the subterranean formation and the one or more physical characteristics. A tool is disposed at or above the oil-water contact. The tool is fluidly coupled to an aqueous fluid line and an organic fluid line. A first aqueous solvent, having a first viscosity, is injected from the aqueous fluid line into an aqueous phase proximal to the oil-water contact. The first aqueous solvent includes a surfactant. The aqueous phase proximal to the oil-water contact including a second viscosity. The first viscosity is greater than the second viscosity. An organic solvent is injected above the first aqueous solvent.
51351212 alkoxylated alcohol including two or fewer than two alkylene oxide groups. The emulsifier composition exhibits a pour point lower than about 0°C. Related methods of forming a borehole extending through an earth formation, and related wellbore fluids including the emulsifier composition are also disclosed.
A well system that includes an electric device disposed in a wellbore and more than one energy harvesting device attached to the electric device and adapted to transform external energy in the wellbore to electric power. A method that includes the steps of deploying an electric device in a wellbore, wherein more than one energy harvesting device is attached to the electric device, transforming, with the more than one energy harvesting device, external energy in the wellbore to electric power, and supplying the electric power from the more than one energy harvesting device to the electric device.
A downhole tool may store a well plan on a hardware storage device of a downhole tool. A downhole tool may drill a first portion of a borehole according to a first stage of the well plan with the downhole tool. A downhole tool may change at least one of a dogleg severity (DLS) and a rate of penetration (ROP) of the downhole tool based on a second stage of the well plan stored on the hardware storage device. A downhole tool may drill a second portion of the borehole according to the second stage of the well plan.
Techniques and apparatus for determining quadrant-based locations of casing defects based on multi-frequency, non-collocated, induction measurements are described. An electromagnetic (EM) inspection tool is operated inside of a well including multiple casings. The EM inspection tool includes a triaxial transmitter and multiple triaxial receivers, each being located at a different spacing from the triaxial transmitter. The triaxial transmitter is configured to emit primary time-varying magnetic field signals in a radial direction, a tangential direction, and an axial direction. Each respective primary time-varying magnetic field signal induces corresponding secondary time-varying magnetic field signal(s) in the radial direction, the tangential direction, and the axial direction that are detected by one or more of the triaxial receivers. Induction measurements of the casings are obtained using the EM inspection tool, and a quadrant of a casing in which a defect of the casing is located is determined based on the induction measurements.
G01V 3/30 - Electric or magnetic prospecting or detectingMeasuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for well-logging operating with electromagnetic waves
G01V 3/12 - Electric or magnetic prospecting or detectingMeasuring magnetic field characteristics of the earth, e.g. declination or deviation operating with electromagnetic waves
100.
MULTI-CASING EVALUATION USING MULTI-FREQUENCY, NON-COLLOCATED, INDUCTION MEASUREMENTS
Techniques and apparatus for evaluating sensor placement and frequency selection for an electromagnetic inspection tool, and determining casing count and casing sizes in a multi-casing well are described. The electromagnetic inspection tool includes a transmitter and multiple receivers configured to operate at one or more frequencies. Each receiver is located at a different spacing from the transmitter. At least one of a casing count for a well or a respective size of each casing in the well is determined using multi-frequency, non-collocated induction measurements obtained via the electromagnetic inspection tool. The size of an innermost casing may be determined based on slope(s) of high frequency response(s) at spacings in a direct coupling zone of an electromagnetic field distribution. Each size of an outer casing(s) may be determined based in part on null frequency locations within the frequency domain responses at spacings in the transition zone of the electromagnetic field distribution.
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
