An electro-hydraulic control system for actuating a control valve includes a control module. The control module is coupled to the surface via at least one hydraulic line and two electrical power lines. The control module uses one of the hydraulic lines as a “supply” line and the other line as a “return” line if included. Each hydraulic line of the at least one hydraulic lines can be used as an “open” line or a “close” line to open or close the control valve. The control module includes two normally closed (NC) solenoid valves (SOVs) that are coupled to the electrical power lines and can be controlled from the surface to open or close. The opening or closing of the NC SOVs in cooperation with hydraulic pressure on a “supply” line of the hydraulic lines operates (i.e., closes or opens) the control valve.
E21B 34/06 - Aménagements des vannes pour les trous de forage ou pour les puits dans les puits
E21B 23/04 - Appareils pour déplacer, mettre en place, verrouiller, libérer ou retirer, les outils, les packers ou autres éléments dans les trous de forage mis en œuvre à l'aide de moyens fluides, p.ex. actionnés par explosion
E21B 33/035 - Têtes de puits; Leur mise en place spécialement adaptées aux installations sous l'eau
E21B 34/10 - Aménagements des vannes pour les trous de forage ou pour les puits dans les puits actionnés par un fluide de commande provenant de l'extérieur du trou de forage
E21B 34/14 - Aménagements des vannes pour les trous de forage ou pour les puits dans les puits actionnés par le mouvement des outils, p.ex. obturateurs à manchons actionnés par des pistons ou par des outils à câble
F16K 31/40 - Moyens de fonctionnement; Dispositifs de retour à la position de repos actionnés par un fluide et dans lesquels il y a alimentation constante du moteur à fluide par le fluide provenant de la canalisation avec un organe actionné électriquement dans la décharge du moteur
G05D 16/20 - Commande de la pression d'un fluide caractérisée par l'utilisation de moyens électriques
2.
BOREHOLE CORRECTION FOR RESISTIVITY LWD TOOLS WITH ULTRASONIC LOG WHILE DRILLING CALIPER
Aspects of the subject technology relate to systems, methods, and computer-readable media for identifying a borehole correction factor for determining a true resistivity by selecting a model to apply in identifying the borehole correction factor and applying the model to an apparent resistivity to identify the borehole correction factor. To perform borehole correction, a multiplicative coefficient is needed to apply to the apparent resistivity. A database of this multiplicative coefficient, called the borehole correction factor, is generated based on the borehole correction model. The technology described herein allows operators to avoid time-consuming variable borehole diameter sweeps and complex borehole diameter inversion current used in resistivity logging software.
E21B 44/00 - Systèmes de commande automatique spécialement adaptés aux opérations de forage, c. à d. systèmes à fonctionnement autonome ayant pour rôle d'exécuter ou de modifier une opération de forage sans l'intervention d'un opérateur humain, p.ex. systèmes de ; Systèmes spécialement adaptés à la surveillance de plusieurs variables ou conditions de forage
E21B 47/0228 - Détermination de l'inclinaison ou de la direction du trou de forage, p.ex. à l'aide de géomagnétisme utilisant l'énergie électromagnétique ou des détecteurs y étant adaptés
E21B 47/085 - Mesure du diamètre ou des dimensions correspondantes des trous de forage utilisant des moyens de radiation, p.ex. des moyens acoustiques, radioactifs ou électromagnétiques
E21B 49/00 - Test pour déterminer la nature des parois des trous de forage; Essais de couches; Procédés ou appareils pour prélever des échantillons du terrain ou de fluides en provenance des puits, spécialement adaptés au forage du sol ou aux puits
A detonator housing facilitates assembly of detonator components of a perforating gun. In an example, the detonator housing comprises a housing body configured for coupling to a charge tube of a perforating gun. A detonator receptacle is formed on the housing body for receiving a detonator. A detonating cord receptacle is formed on the housing body adjacent the detonator receptacle for receiving an end portion of a detonating cord in an overlapping relationship with the detonator. A detonating cord stop is formed on the detonating cord receptacle to limit an insertion depth of the detonating cord within the detonating cord receptacle.
A detonator housing facilitates assembly of detonator components of a perforating gun. In an example, the detonator housing comprises a housing body configured for coupling to a charge tube of a perforating gun. A detonator receptacle is formed on the housing body for receiving a detonator. A detonating cord receptacle is formed on the housing body adjacent the detonator receptacle for receiving an end portion of a detonating cord in an overlapping relationship with the detonator. A detonating cord stop is formed on the detonating cord receptacle to limit an insertion depth of the detonating cord within the detonating cord receptacle.
A method for configuring a learning machine to predict a flow rate of at least one phase of a fluid. The method comprises determining a feature set for the learning machine, the feature set including information derived from a signal generated by a flow of the fluid interacting with a fluidic oscillator in a wellbore. The method comprises configuring the learning machine with the feature set including information derived from the signal.
G01F 1/32 - Mesure du débit volumétrique ou du débit massique d'un fluide ou d'un matériau solide fluent, dans laquelle le fluide passe à travers un compteur par un écoulement continu en utilisant des effets mécaniques par détection des effets dynamiques de l’écoulement utilisant des débitmètres à tourbillons
E21B 47/10 - Localisation des fuites, intrusions ou mouvements du fluide
G01F 1/661 - Mesure du débit volumétrique ou du débit massique d'un fluide ou d'un matériau solide fluent, dans laquelle le fluide passe à travers un compteur par un écoulement continu en mesurant la fréquence, le déphasage, le temps de propagation d'ondes électromagnétiques ou d'autres types d'ondes, p.ex. en utilisant des débitmètres à ultrasons en utilisant la lumière
G01V 8/16 - Détection, p.ex. en utilisant des barrières de lumière en utilisant un émetteur et un récepteur en utilisant des fibres optiques
A method including entraining carbon dioxide (CO2) in a cement slurry composition and subjecting the cement slurry composition to conditions under which the CO2 achieves and maintains a supercritical state; and allowing the cement slurry composition to harden to form a hardened cement having CO2 sequestered therein.
An electric submersible pump (ESP) assembly. The ESP assembly comprises an electric motor; a seal section coupled to an uphole end of the electric motor; a fluid intake coupled to an uphole end of the seal section, wherein the fluid intake defines a plurality of inlet ports; a gas separator coupled to an uphole end of the fluid intake, wherein the gas separator has a plurality of gas phase discharge ports; a pump assembly coupled to an uphole end of the gas separator; and an intake extension tubular, wherein an uphole end of the intake extension tubular is coupled to the fluid intake uphole of the inlet ports, and wherein an annulus defined between an inside of the intake extension tubular and an outside of the seal section defines a fluid flow path from a downhole end of the intake extension tubular to the inlet ports of the fluid intake.
An electric submersible pump (ESP) assembly. The ESP assembly comprises an electric motor; a seal section coupled to the electric motor; a fluid intake coupled to an uphole end of the seal section, wherein the fluid intake defines a plurality of inlet ports; a gas separator comprising a plurality of gas phase discharge ports, and at least one liquid phase discharge port, wherein the gas separator is located uphole of the fluid intake; a centrifugal pump comprising a fluid inlet at a downhole end, wherein the at least one liquid phase discharge port of the gas separator is fluidically coupled to the fluid inlet of the centrifugal pump; and an inverted shroud assembly, wherein a downhole end of the inverted shroud assembly is coupled to an outside of the gas separator downhole of the gas phase discharge ports of the gas separator and uphole of the fluid intake.
A system can include a filter assembly with a filter and a substance in the filter assembly, and at least one optical computing device having an integrated computational element which receives electromagnetic radiation from the substance. A method can include receiving electromagnetic radiation from a substance in a filter assembly, the electromagnetic radiation from the substance being received by at least one optical computing device having an integrated computational element, and the receiving being performed while a filter is positioned in the filter assembly. A detector may receive electromagnetic radiation from the integrated computational element and produce an output correlated to a characteristic of the substance. A mitigation technique may be selected, based on the detector output.
A method and system for generating an acoustic log. The method may comprise disposing an acoustic logging tool in a wellbore, broadcasting a shaped signal with the acoustic logging tool such that the shaped signal interacts with a boundary of a casing and a material, recording a result signal from the boundary with the acoustic logging tool, and decomposing the result signal into a resonance mode. The method may further comprise applying a bandpass filter to the resonance mode to form a filtered signal, selecting a baseline signal from the filtered signal, removing the baseline signal from the filtered signal, and generating a log from the filtered signal. The system may comprise an acoustic logging tool. The acoustic logging tool may comprise at least one transmitter and at least one receiver. The system may further comprise a conveyance and an information handling system communicatively connected to the acoustic logging tool.
Described herein are systems and techniques for monitoring for monitoring and evaluating conditions associated with a wellbore and wellbore operations that use neural operators instead of computationally intensive iterative differential equations. Such systems and techniques allow for determinations to be made as operations associated with a wellbore are performed. Instead of having to wait for computationally intensive tasks to be performed or take risks of proceeding with a wellbore operation without real-time evaluations being performed, these wellbore operations may be continued while determinations are timely made, thus improving operation of computing systems that perform evaluations and that make decisions regarding safely and efficiently performing wellbore operations such as drilling a wellbore, cementing wellbore casings in place, or injecting fluids into formations of the Earth.
E21B 44/00 - Systèmes de commande automatique spécialement adaptés aux opérations de forage, c. à d. systèmes à fonctionnement autonome ayant pour rôle d'exécuter ou de modifier une opération de forage sans l'intervention d'un opérateur humain, p.ex. systèmes de ; Systèmes spécialement adaptés à la surveillance de plusieurs variables ou conditions de forage
A system for inspecting a tubular may comprise an electromagnetic (EM) logging tool and information handling system. The EM logging tool may further include a mandrel, one or more sensor pads attached to the mandrel by one or more extendable arms, and one or more partial saturation eddy current sensors disposed on each of the one or more sensor pads.
E21B 47/002 - Relevés dans les trous de forage ou dans les puits par inspection visuelle
E21B 47/0228 - Détermination de l'inclinaison ou de la direction du trou de forage, p.ex. à l'aide de géomagnétisme utilisant l'énergie électromagnétique ou des détecteurs y étant adaptés
E21B 47/085 - Mesure du diamètre ou des dimensions correspondantes des trous de forage utilisant des moyens de radiation, p.ex. des moyens acoustiques, radioactifs ou électromagnétiques
13.
TREE-BASED LEARNING METHODS THROUGH TUBING CEMENT SHEATH QUALITY ASSESSMENT
Aspects of the subject technology relate to systems and methods for identifying the quality of cement bonding of an exterior surface of a wellbore casing to an Earth formation. Methods of the present disclosure may allow for bond indexes to be identified in real-time as a cementing operation is performed even when tools that perform the cementing operation generate acoustic noise that interfere with measurements used to evaluate cement bonding quality. These methods may include transmitting acoustic signals, receiving acoustic signals, filtering the received acoustic signals, identifying magnitude and attenuation values to associate with the received acoustic signals, and comparing trends in the magnitudes with the identified attenuation values. These methods may also include correcting attenuation values associated with measured data based on a set of correction rules such that bond indexes can be identified. Such correction rules may be associated with data generated by a computer model.
E21B 47/14 - Moyens pour la transmission de signaux de mesure ou signaux de commande du puits vers la surface, ou de la surface vers le puits, p.ex. pour la diagraphie pendant le forage utilisant des ondes acoustiques
A shifting sleeve tieback seal system may include a body portion and a swellable material disposed about a circumference of the body portion. The swellable material is configured to expand in response to exposure to wellbore fluids. Further, the system may include an upper end ring disposed in a position axially above the swellable material, a lower end ring disposed in a position axially below the swellable material, and a sleeve disposed radially outward from the swellable material and sealed against the upper end ring and/or the lower end ring in a run-in position to isolate the swellable material from wellbore fluids. The sleeve is configured to contact a downhole feature in a setting position and contact with the downhole feature is configured to move the sleeve to expose the swellable material to wellbore fluids such that the swellable material expands to seal against a downhole tubular.
E21B 33/129 - Packers; Bouchons à patins mécaniques pour accrochage dans le tubage
E21B 23/06 - Appareils pour déplacer, mettre en place, verrouiller, libérer ou retirer, les outils, les packers ou autres éléments dans les trous de forage pour le montage des packers
E21B 34/10 - Aménagements des vannes pour les trous de forage ou pour les puits dans les puits actionnés par un fluide de commande provenant de l'extérieur du trou de forage
15.
TREE-BASED LEARNING METHODS THROUGH TUBING CEMENT SHEATH QUALITY ASSESSMENT
Aspects of the subject technology relate to systems and methods for identifying the quality of cement bonding of an exterior surface of a wellbore casing to an Earth formation. Methods of the present disclosure may allow for bond indexes to be identified in real-time as a cementing operation is performed even when tools that perform the cementing operation generate acoustic noise that interfere with measurements used to evaluate cement bonding quality. These methods may include transmitting acoustic signals, receiving acoustic signals, filtering the received acoustic signals, identifying magnitude and attenuation values to associate with the received acoustic signals, and comparing trends in the magnitudes with the identified attenuation values. These methods may also include correcting attenuation values associated with measured data based on a set of correction rules such that bond indexes can be identified. Such correction rules may be associated with data generated by a computer model.
G06F 30/27 - Optimisation, vérification ou simulation de l’objet conçu utilisant l’apprentissage automatique, p.ex. l’intelligence artificielle, les réseaux neuronaux, les machines à support de vecteur [MSV] ou l’apprentissage d’un modèle
G01V 99/00 - Matière non prévue dans les autres groupes de la présente sous-classe
A method includes operating a wellsite apparatus at a wellsite utilizing mechanical energy or electricity produced at least in part from hydrogen in a fuel source comprising hydrogen. Utilizing mechanical energy or electricity produced at least in part from the hydrogen in the fuel source comprising hydrogen can further include: (a) converting the hydrogen in the fuel source to electricity in one or more fuel cells and utilizing the electricity to operate the wellsite apparatus; and/or (b) combusting the hydrogen in the fuel source in a power generation apparatus to produce electricity and utilizing the electricity to operate the wellsite apparatus; and/or (c) combusting the hydrogen in the fuel source to produce mechanical energy and utilizing the mechanical energy to operate the wellsite apparatus. A system for carrying out the method is also provided.
A method and system for identifying scale. The method may include disposing a fluid sampling tool into a wellbore. The fluid sampling tool may comprise at least one probe configured to fluidly connect the fluid sampling tool to a formation in the wellbore and at least one passageway that passes through the at least one probe and into the fluid sampling tool. The method may further comprise drawing a formation fluid, as a fluid sample, through the at least one probe and through the at least one passageway, perturbing the formation fluid, and analyzing the fluid sample in the fluid sampling tool for one or more indications of scale.
Enclosed herein are a method and system for reduction of a tool wave excited by a transmitter of the well logging tool. In one embodiment, a method comprises transmitting, by a primary transmitter, a primary acoustic wave into a geologic formation which excites a tool wave and a formation wave in the geologic formation, wherein the logging tool comprises a tool wave propagating factor which is different from a formation wave propagating factor; receiving, by one or more receivers, the formation wave and the tool wave; propagating waveform data associated with the received tool wave and formation wave based on a distance between the auxiliary receiver and a primary receiver; and reducing the tool wave in waveform data associated with the formation wave and the tool wave received by a primary receiver of the one or more receivers based on the propagated waveform data.
A method may include: introducing a resin modified cement slurry into a wellbore penetrating a subterranean formation, the subterranean formation comprising a caprock and a carbon dioxide injection zone, the resin modified cement slurry comprising: a resin; a hardener; a hydraulic cement; and water; and setting the resin modified cement slurry to form a set cement wherein the set cement forms a carbonation-resistant barrier in the carbon dioxide injection zone in the subterranean formation.
C09K 8/467 - Compositions de cimentation, p.ex. pour la cimentation des tubes dans les trous de forage; Compositions de bouchage, p.ex. pour tuer des puits contenant des liants inorganiques, p.ex. ciment Portland contenant des additifs pour des utilisations spécifiques
C04B 24/28 - Composés macromoléculaires obtenus autrement que par des réactions faisant intervenir uniquement des liaisons non saturées carbone-carbone
C04B 28/02 - Compositions pour mortiers, béton ou pierre artificielle, contenant des liants inorganiques ou contenant le produit de réaction d'un liant inorganique et d'un liant organique, p.ex. contenant des ciments de polycarboxylates contenant des ciments hydrauliques autres que ceux de sulfate de calcium
E21B 33/14 - Procédés ou dispositifs de cimentation, de bouchage des trous, des fissures ou analogues pour la cimentation des tubes dans les trous de forage ou de sondage
20.
DISTRIBUTED SENSING WITH TUBING ENCASED CONDUCTORS (TEC)
A method comprising transmitting, by an electric conductor disposed in a wellbore, a time-varying electric signal to a first reflector wirelessly coupled to the electric conductor and a sensor, wherein the sensor is wirelessly coupled to the electric conductor via the first reflector, receiving a first reflected signal from the first reflector, analyzing the first reflected signal to determine a sensor value for the sensor, and determining, based on the sensor value, one or more downhole parameters.
E21B 47/125 - Moyens pour la transmission de signaux de mesure ou signaux de commande du puits vers la surface, ou de la surface vers le puits, p.ex. pour la diagraphie pendant le forage utilisant la terre comme conducteur électrique
A method and system for identifying scale. The method may include disposing a fluid sampling tool into a wellbore. The fluid sampling tool may comprise at least one probe configured to fluidly connect the fluid sampling tool to a formation in the wellbore and at least one passageway that passes through the at least one probe and into the fluid sampling tool. The method may further comprise drawing a formation fluid, as a fluid sample, through the at least one probe and through the at least one passageway, perturbing the formation fluid, and analyzing the fluid sample in the fluid sampling tool for one or more indications of scale.
Cement bonding evaluation and logging in a wellbore environment are described. The cement bonding evaluation is performed using data associated with and processed from the measurement of sonic waves directed to and dissipated by the casing present in the wellbore.
E21B 47/005 - Surveillance ou contrôle de la qualité ou du niveau de cimentation
E21B 47/14 - Moyens pour la transmission de signaux de mesure ou signaux de commande du puits vers la surface, ou de la surface vers le puits, p.ex. pour la diagraphie pendant le forage utilisant des ondes acoustiques
A method may include: circulating an oil-based drilling fluid though a drill string to extend a wellbore through a subterranean formation, wherein the oil-based drilling fluid comprises an invert emulsion; separating at least a portion of the oil-based drilling fluid from the circulated oil-based drilling fluid to form a separated portion of oil-based drilling fluid; mixing a metal salt and a metal oxide into the separated portion of the oil-based drilling fluid to form a chemical sealing pill; introducing the chemical sealing pill into the drill string and flowing the chemical sealing pill into a lost circulation zone in the subterranean formation; allowing at least a portion of the chemical sealing pill to set in the lost circulation zone to form a set plug, wherein the set plug seals the lost circulation zone and reduces loss of fluid into the lost circulation zone from subsequently introduced fluids; and preventing loss of fluid into the lost circulation zone from subsequently introduced fluids with the set plug.
Systems and methods are provided for determining the wideband spectrum of downhole fluids based on downhole optical measurements. In some aspects, a plurality of optical data measurements associated with a subsurface fluid can be obtained from a subsurface optical measurement device. In some cases, a comparison can be made between the plurality of optical data measurements associated with the subsurface fluid and one or more sets of optical data stored in an optical data library. In some examples, the one or more sets of optical data can correspond to a plurality of different fluid samples. In some instances, a first fluid sample from the plurality of fluid samples that corresponds to at least a portion of the subsurface fluid can be identified based on the comparison. In some aspects, an absorbance spectrum of the subsurface fluid can be determined based on the first fluid sample.
A method comprising transmitting, by an electric conductor disposed in a wellbore, a time-varying electric signal to a first reflector wirelessly coupled to the electric conductor and a sensor, wherein the sensor is wirelessly coupled to the electric conductor via the first reflector, receiving a first reflected signal from the first reflector, analyzing the first reflected signal to determine a sensor value for the sensor, and determining, based on the sensor value, one or more downhole parameters.
G01D 5/20 - Moyens mécaniques pour le transfert de la grandeur de sortie d'un organe sensible; Moyens pour convertir la grandeur de sortie d'un organe sensible en une autre variable, lorsque la forme ou la nature de l'organe sensible n'imposent pas un moyen de conversion déterminé; Transducteurs non spécialement adaptés à une variable particulière utilisant des moyens électriques ou magnétiques influençant la valeur d'un courant ou d'une tension en faisant varier l'inductance, p.ex. une armature mobile
An environmental-efficiency fluid is designed by a system and/or method. The fluid can be for use in a down-hole operation in a well. The design produces the environmental-efficiency fluid from a treatment fluid and drill cuttings. For example, the system and method can include creating an analysis of a rheological model generated from a set of wellbore conditions and a set of drill-cutting properties to determine a set of rheological properties for the treatment fluid and a concentration of drill cuttings, which allow for use of the drill cuttings with the treatment fluid; and producing the environmental-efficiency fluid based on the rheological properties and the concentration of drill cuttings.
Provided is a multilateral junction and a well system. The multilateral junction, in one aspect, includes a housing, the housing including a first housing end and a second housing end, a bore extending through the housing from the first housing end to the second housing end, and a bore coupling profile located along an inside surface of the bore proximate the second housing end. The multilateral junction, according to this aspect, further includes a multilateral bore leg extending into the bore, the multilateral bore leg including a tubular having a first tubular end and a second tubular end, and a tubular coupling profile located along an outside surface of the tubular proximate the first tubular end. The multilateral junction, according to this aspect, further includes an arced coupling located between the bore and the tubular and engaged with the bore coupling profile and the tubular coupling profile.
Provided is a multilateral junction and a well system. The multilateral junction, in one aspect, includes a housing, the housing including a first housing end and a second housing end, a bore extending through the housing from the first housing end to the second housing end, and a toothed coupling profile located along an inside surface of the bore proximate the second housing end. The multilateral junction, according to this aspect, further includes a multilateral bore leg extending into the bore, the multilateral bore leg including a tubular having a first tubular end and a second tubular end. The multilateral junction, according to this aspect, further includes a toothed coupling located between the bore and the tubular and engaged with the toothed coupling profile and the tubular to axially fix the housing and the multilateral bore leg relative to one another.
Systems and methods are provided for determining the wideband spectrum of downhole fluids based on downhole optical measurements. In some aspects, a plurality of optical data measurements associated with a subsurface fluid can be obtained from a subsurface optical measurement device. In some cases, a comparison can be made between the plurality of optical data measurements associated with the subsurface fluid and one or more sets of optical data stored in an optical data library. In some examples, the one or more sets of optical data can correspond to a plurality of different fluid samples. In some instances, a first fluid sample from the plurality of fluid samples that corresponds to at least a portion of the subsurface fluid can be identified based on the comparison. In some aspects, an absorbance spectrum of the subsurface fluid can be determined based on the first fluid sample.
A flow control system for use in controlling flow of a fluid composition in a subterranean well is disclosed. The flow control system includes a flow chamber that includes an inlet and an outlet oriented such that the fluid composition flows circuitously through the chamber, forming a vortex at least at the outlet. The flow control system further comprises at least one flow control structure shaped and positioned in the flow chamber such that a velocity of the circuitous flow is reduced and the vortex is eliminated or substantially reduced.
E21B 43/12 - Procédés ou appareils pour commander l'écoulement du fluide extrait vers ou dans les puits
E21B 34/08 - Aménagements des vannes pour les trous de forage ou pour les puits dans les puits sensibles à l'écoulement ou à la pression du fluide obtenu
A shifting sleeve tieback seal system may include a body portion and a swellable material disposed about a circumference of the body portion. The swellable material is configured to expand in response to exposure to wellbore fluids. Further, the system may include an upper end ring disposed in a position axially above the swellable material, a lower end ring disposed in a position axially below the swellable material, and a sleeve disposed radially outward from the swellable material and sealed against the upper end ring and/or the lower end ring in a run-in position to isolate the swellable material from wellbore fluids. The sleeve is configured to contact a downhole feature in a setting position and contact with the downhole feature is configured to move the sleeve to expose the swellable material to wellbore fluids such that the swellable material expands to seal against a downhole tubular.
E21B 23/06 - Appareils pour déplacer, mettre en place, verrouiller, libérer ou retirer, les outils, les packers ou autres éléments dans les trous de forage pour le montage des packers
34.
SUPPLY CHAIN QUALITY ASSURANCE FOR WELL COMPLETION USING BLOCKCHAIN
Systems, methods, and computer-readable media are provided for performing a well completion. Specifically, a distributed ledger associated with a supply chain for a well completion is accessed. The distributed ledger can include a first entry associated with a first entity in the supply chain that is indicative of an identification of the first entity and characteristics of a material implemented in the well completion. The ledger can also include a second entry associated with a second entity in the supply chain that is indicative of the second entity and the characteristics of the material at the second entity. Integration of the material in the well completion can be controlled based on the first entry and the second entry.
E21B 43/26 - Procédés pour activer la production par formation de crevasses ou de fractures
G05B 13/04 - Systèmes de commande adaptatifs, c. à d. systèmes se réglant eux-mêmes automatiquement pour obtenir un rendement optimal suivant un critère prédéterminé électriques impliquant l'usage de modèles ou de simulateurs
35.
DETERMINATION OF LOCATION AND TYPE OF RESERVOIR FLUIDS BASED ON DOWNHOLE PRESSURE GRADIENT IDENTIFICATION
A method comprises receiving a measurement of a pressure in a subsurface formation at a number of depths in a wellbore formed in the subsurface formation across a sampling depth range of the subsurface formation to generate a number of pressure-depth measurement pairs and partitioning the sampling depth range into a number of fluid depth ranges. The method comprises performing a fitting operation over each of the number of fluid depth ranges to determine a fluid gradient for the type of the reservoir fluid for each of the number of fluid depth ranges. The method comprises generating a solution set of one or more solutions based on the fluid gradient of the reservoir fluid for each of the number of fluid depth ranges determined from performing the fitting operation, wherein each solution defines a partitioning of the sampling depth range and the fluid gradient of each fluid depth range.
An acoustic actuator for scale removal and prevention in a wellbore is described herein. For example, a system can include a tubing string deployed downhole in a wellbore. A downhole tool can be coupled to the tubing string. An acoustic actuator can be coupled to the tubing string and positioned proximate to the downhole tool. The acoustic actuator can generate an acoustic signal that can vibrate the tubing string to generate a fluidic disturbance in downhole fluid within the tubing string for removing contaminants from, or preventing formation of contaminants, on the downhole tool.
E21B 31/00 - Repêchage ou dégagement d'objets dans les trous de forage ou dans les puits
E21B 34/06 - Aménagements des vannes pour les trous de forage ou pour les puits dans les puits
E21B 36/02 - Aménagements pour le chauffage, le refroidissement, l'isolation, dans les trous de forage ou dans les puits, p.ex. pour être utilisés dans les zones de permagel utilisant des brûleurs
E21B 43/38 - Aménagements pour séparer les matériaux produits par le puits dans le puits
37.
CLOUD-BASED MANAGEMENT OF A HYDRAULIC FRACTURING OPERATION IN A WELLBORE
The method includes receiving raw data at a cloud service relating to a hydraulic fracturing operation. The raw data can be streamed to the cloud service. The method further includes pre-processing the raw data to generate pre-processed data. The pre-processed data can be ingestible by a cloud-based dashboard. Additionally, the method includes identifying at least one parameter relating to the hydraulic fracturing operation using the pre-processed data. The method can further include determining a difference between the at least one parameter and at least one optimized parameter. Further, the method can include adjusting the hydraulic fracturing operation based the difference between the at least one parameter and the at least one optimized parameter.
Cement bonding evaluation and logging in a wellbore environment are described. The cement bonding evaluation is performed using data associated with and processed from the measurement of sonic waves directed to and dissipated by the casing present in the wellbore.
E21B 47/005 - Surveillance ou contrôle de la qualité ou du niveau de cimentation
G01B 17/06 - Dispositions pour la mesure caractérisées par l'utilisation de vibrations infrasonores, sonores ou ultrasonores pour mesurer des contours ou des courbes
An acoustic actuator for scale removal and prevention in a wellbore is described herein. For example, a system can include a tubing string deployed downhole in a wellbore. A downhole tool can be coupled to the tubing string. An acoustic actuator can be coupled to the tubing string and positioned proximate to the downhole tool. The acoustic actuator can generate an acoustic signal that can vibrate the tubing string to generate a fluidic disturbance in downhole fluid within the tubing string for removing contaminants from, or preventing formation of contaminants, on the downhole tool.
E21B 47/14 - Moyens pour la transmission de signaux de mesure ou signaux de commande du puits vers la surface, ou de la surface vers le puits, p.ex. pour la diagraphie pendant le forage utilisant des ondes acoustiques
E21B 34/10 - Aménagements des vannes pour les trous de forage ou pour les puits dans les puits actionnés par un fluide de commande provenant de l'extérieur du trou de forage
B06B 1/02 - Procédés ou appareils pour produire des vibrations mécaniques de fréquence infrasonore, sonore ou ultrasonore utilisant l'énergie électrique
40.
Enhanced sensing of subsea wells using optical fiber
A system and method for deploying a fiber optic sensing (FOS) system. The system may include a deployment package that is marinized. The deployment package may include a connection housing for connecting the deployment package to a subsea tree, a valve disposed on the connection housing, and a chamber connected to the valve. The deployment package may also include a cap attached to an end of the chamber opposite the valve and one or more optical connections disposed within the cap. Additionally, the deployment package may include a self-propelling vehicle that is disposed within the chamber and a downhole sensing fiber connected to the self-propelling vehicle.
E21B 47/135 - Moyens pour la transmission de signaux de mesure ou signaux de commande du puits vers la surface, ou de la surface vers le puits, p.ex. pour la diagraphie pendant le forage par énergie électromagnétique, p.ex. gammes de fréquence radio utilisant des ondes lumineuses, p.ex. ondes infrarouges ou ultraviolettes
G01D 5/353 - Moyens mécaniques pour le transfert de la grandeur de sortie d'un organe sensible; Moyens pour convertir la grandeur de sortie d'un organe sensible en une autre variable, lorsque la forme ou la nature de l'organe sensible n'imposent pas un moyen de conversion déterminé; Transducteurs non spécialement adaptés à une variable particulière utilisant des moyens optiques, c. à d. utilisant de la lumière infrarouge, visible ou ultraviolette avec atténuation ou obturation complète ou partielle des rayons lumineux les rayons lumineux étant détectés par des cellules photo-électriques en modifiant les caractéristiques de transmission d'une fibre optique
G01H 9/00 - Mesure des vibrations mécaniques ou des ondes ultrasonores, sonores ou infrasonores en utilisant des moyens sensibles aux radiations, p.ex. des moyens optiques
G01V 1/22 - Transmission des signaux sismiques aux appareils d'enregistrement ou de traitement
41.
FLUID TIGHT FLOAT FOR USE IN A DOWNHOLE ENVIRONMENT
Provided is a float for use with a fluid flow control device, a fluid flow control device, a method for manufacturing a float, and a well system. The float, in one aspect, includes a fluid tight enclosure. The float, according to this aspect, further includes density specific material located within the fluid tight enclosure, the fluid tight enclosure and the density specific material creating a net density for the float that is between a first density of a desired fluid and a second density of an undesired fluid, such that the float may control fluid flow through a flow control device when encountering the desired fluid or the undesired fluid.
E21B 21/08 - Commande ou surveillance de la pression ou de l'écoulement du fluide de forage, p.ex. remplissage automatique des trous de forage, commande automatique de la pression au fond
E21B 34/06 - Aménagements des vannes pour les trous de forage ou pour les puits dans les puits
42.
MULTILATERAL JUNCTION INCLUDING A TOOTHED COUPLING
Provided is a multilateral junction and a well system. The multilateral junction, in one aspect, includes a housing, the housing including a first housing end and a second housing end, a bore extending through the housing from the first housing end to the second housing end, and a toothed coupling profile located along an inside surface of the bore proximate the second housing end. The multilateral junction, according to this aspect, further includes a multilateral bore leg extending into the bore, the multilateral bore leg including a tubular having a first tubular end and a second tubular end. The multilateral junction, according to this aspect, further includes a toothed coupling located between the bore and the tubular and engaged with the toothed coupling profile and the tubular to axially fix the housing and the multilateral bore leg relative to one another.
Provided is a subsurface safety valve (SSSV), a well system, and a method. The subsurface safety valve (SSSV), in one aspect, includes an outer housing, a valve closure mechanism coupled to the outer housing, and a bore flow management actuator disposed in the central bore, the bore flow management actuator configured to slide from a first state to a second state to move the valve closure mechanism between a closed state and an open state. The subsurface safety valve (SSSV), in this aspect, additionally includes an electromagnet positioned at: 1) a first location, the first location in the outer housing proximate where the bore flow management actuator resides when the bore flow management actuator is in the second state; or 2) a second location, the second location coupled proximate a downhole end of the bore flow management actuator.
E21B 34/06 - Aménagements des vannes pour les trous de forage ou pour les puits dans les puits
E21B 34/10 - Aménagements des vannes pour les trous de forage ou pour les puits dans les puits actionnés par un fluide de commande provenant de l'extérieur du trou de forage
44.
PHASE CONTROL FOR SUBTERRANEAN CARBON CAPTURE, UTILIZATION AND STORAGE
Injection into a subterranean formation is optimized using a computation model to optimize injection. An optimization objective is to maximize the cumulative fluid mass rates injection that span over the remaining life of the field, while maintaining a dense or supercritical phase and operating within the equipment operational parameters. The phase at each location may be determined based on pressure and temperature, and flow is dynamically adjusted to maintain a phase having at least a threshold density of the carbon dioxide injected at each injection location.
A downhole transducer can include at least one single-crystal piezoelectric material, the at least one single-crystal piezoelectric material being positioned in the downhole transducer that is deployed downhole in a wellbore. Additionally, the downhole transducer can include at least one pair of electrodes positioned adjacent to the at least one single-crystal piezoelectric material for determining wellbore parameter measurements using one or more acoustic signals transmitted in the wellbore. The single-crystal piezoelectric material can include PIN-PZN-PT.
G01V 1/44 - Séismologie; Prospection ou détection sismique ou acoustique spécialement adaptées au carottage en utilisant des générateurs et des récepteurs situés dans le même puits
G01V 1/52 - Séismologie; Prospection ou détection sismique ou acoustique spécialement adaptées au carottage - Détails de structure
E21B 47/14 - Moyens pour la transmission de signaux de mesure ou signaux de commande du puits vers la surface, ou de la surface vers le puits, p.ex. pour la diagraphie pendant le forage utilisant des ondes acoustiques
E21B 47/01 - Dispositifs pour supporter des instruments de mesure sur des trépans, des tubes, des tiges ou des câbles de forage; Protection des instruments de mesure dans les trous de forage contre la chaleur, les chocs, la pression ou similaire
46.
REAL-TIME CEMENT BOND LOGGING BASED ON CORRELATION
Aspects of the subject technology relate to systems and methods for identifying the quality of cement bonding of an exterior surface of a wellbore casing to an Earth formation. Methods of the present disclosure may allow for bond indexes to be identified in real-time as a cementing operation is performed even when tools that perform the cementing operation generate acoustic noise that interfere with measurements used to evaluate cement bonding quality. These methods may include transmitting acoustic signals, receiving acoustic signals, filtering the received acoustic signals, identifying magnitude and attenuation values to associate with the received acoustic signals, and comparing trends in the magnitudes with the identified attenuation values. These methods may also include correcting attenuation values associated with measured data based on a set of correction rules such that bond indexes can be identified. Such correction rules may be associated with data generated by a computer model.
G01V 1/40 - Séismologie; Prospection ou détection sismique ou acoustique spécialement adaptées au carottage
E21B 47/14 - Moyens pour la transmission de signaux de mesure ou signaux de commande du puits vers la surface, ou de la surface vers le puits, p.ex. pour la diagraphie pendant le forage utilisant des ondes acoustiques
47.
FLOW CONTROL SYSTEM FOR USE IN A SUBTERRANEAN WELL
A flow control system for use in controlling flow of a fluid composition in a subterranean well is disclosed. The flow control system includes a flow chamber that includes an inlet and an outlet oriented such that the fluid composition flows circuitously through the chamber, forming a vortex at least at the outlet. The flow control system further comprises at least one flow control structure shaped and positioned in the flow chamber such that a velocity of the circuitous flow is reduced and the vortex is eliminated or substantially reduced.
Provided is a subsurface safety valve (SSSV), a well system, and a method. The subsurface safety valve (SSSV), in one aspect, includes an outer housing, a valve closure mechanism coupled to the outer housing, and a bore flow management actuator disposed in the central bore, the bore flow management actuator configured to slide from a first state to a second state to move the valve closure mechanism between a closed state and an open state. The subsurface safety valve (SSSV), in this aspect, additionally includes an electromagnet positioned at: 1) a first location, the first location in the outer housing proximate where the bore flow management actuator resides when the bore flow management actuator is in the second state; or 2) a second location, the second location coupled proximate a downhole end of the bore flow management actuator.
Provided is a multilateral junction and a well system. The multilateral junction, in one aspect, includes a housing, the housing including a first housing end and a second housing end, a bore extending through the housing from the first housing end to the second housing end, and a bore coupling profile located along an inside surface of the bore proximate the second housing end. The multilateral junction, according to this aspect, further includes a multilateral bore leg extending into the bore, the multilateral bore leg including a tubular having a first tubular end and a second tubular end, and a tubular coupling profile located along an outside surface of the tubular proximate the first tubular end. The multilateral junction, according to this aspect, further includes an arced coupling located between the bore and the tubular and engaged with the bore coupling profile and the tubular coupling profile.
Provided is a float for use with a fluid flow control device, a fluid flow control device, a method for manufacturing a float, and a well system. The float, in one aspect, includes a fluid tight enclosure. The float, according to this aspect, further includes density specific material located within the fluid tight enclosure, the fluid tight enclosure and the density specific material creating a net density for the float that is between a first density of a desired fluid and a second density of an undesired fluid, such that the float may control fluid flow through a flow control device when encountering the desired fluid or the undesired fluid.
E21B 43/12 - Procédés ou appareils pour commander l'écoulement du fluide extrait vers ou dans les puits
E21B 34/08 - Aménagements des vannes pour les trous de forage ou pour les puits dans les puits sensibles à l'écoulement ou à la pression du fluide obtenu
51.
WELL BARRIERS FOR SUBTERRANEAN STORAGE OF CARBON DIOXIDE
A method may include: introducing a resin modified cement slurry into a wellbore penetrating a subterranean formation, the subterranean formation comprising a caprock and a carbon dioxide injection zone, the resin modified cement slurry comprising: a resin; a hardener; a hydraulic cement; and water; and setting the resin modified cement slurry to form a set cement wherein the set cement forms a carbonation-resistant barrier in the carbon dioxide injection zone in the subterranean formation.
E21B 33/13 - Procédés ou dispositifs de cimentation, de bouchage des trous, des fissures ou analogues
E21B 43/16 - Procédés de récupération assistée pour l'extraction d'hydrocarbures
C09K 8/467 - Compositions de cimentation, p.ex. pour la cimentation des tubes dans les trous de forage; Compositions de bouchage, p.ex. pour tuer des puits contenant des liants inorganiques, p.ex. ciment Portland contenant des additifs pour des utilisations spécifiques
52.
DETERMINATION OF LOCATION AND TYPE OF RESERVOIR FLUIDS BASED ON DOWNHOLE PRESSURE GRADIENT IDENTIFICATION
A method comprises receiving a measurement of a pressure in a subsurface formation at a number of depths in a wellbore formed in the subsurface formation across a sampling depth range of the subsurface formation to generate a number of pressure-depth measurement pairs and partitioning the sampling depth range into a number of fluid depth ranges. The method comprises performing a fitting operation over each of the number of fluid depth ranges to determine a fluid gradient for the type of the reservoir fluid for each of the number of fluid depth ranges. The method comprises generating a solution set of one or more solutions based on the fluid gradient of the reservoir fluid for each of the number of fluid depth ranges determined from performing the fitting operation, wherein each solution defines a partitioning of the sampling depth range and the fluid gradient of each fluid depth range.
A system can display confidence values in a wellbore inversion model using a visual indicator. The system can receive downhole data relating to the wellbore from a downhole tool deployed in a wellbore of a geological formation during a wellbore operation. The system can additionally generate an inversion model of the geological formation by performing inversion processing on the downhole data. Furthermore, the system can determine confidence values for the downhole data in the inversion model. Additionally, the system can determine a depth of detection limit for the downhole data based on the confidence values. The system can output the inversion model, the depth of detection limit, and a visual indicator based on the confidence values for display at a display device for use in adjusting the wellbore operation.
E21B 44/00 - Systèmes de commande automatique spécialement adaptés aux opérations de forage, c. à d. systèmes à fonctionnement autonome ayant pour rôle d'exécuter ou de modifier une opération de forage sans l'intervention d'un opérateur humain, p.ex. systèmes de ; Systèmes spécialement adaptés à la surveillance de plusieurs variables ou conditions de forage
E21B 7/06 - Modification de la direction du trou de forage
54.
Phase Control For Subterranean Carbon Capture, Utilization And Storage
Injection into a subterranean formation is optimized using a computation model to optimize injection. An optimization objective is to maximize the cumulative fluid mass rates injection that span over the remaining life of the field, while maintaining a dense or supercritical phase and operating within the equipment operational parameters. The phase at each location may be determined based on pressure and temperature, and flow is dynamically adjusted to maintain a phase having at least a threshold density of the carbon dioxide injected at each injection location.
A microsampling device for taking fluid samples in a wellbore. The microsampling device may comprise a microsampling tube in which one or more microsamplers disposed in the microsampling tube. Additionally, the microsampling device may comprise a fluid flow line connected to the microsampling tube in which a fluid sample traverses and a secondary fluid flow line in which at least a part of the fluid sample may traverse from the microsampling tube through the secondary fluid flow line and into a wellbore.
E21B 49/10 - Prélèvement d'échantillons de fluides ou test des fluides dans les trous de forage ou dans les puits utilisant des appareils d'échantillonnage ou de test de fluide venant s'appliquer latéralement contre la paroi du puits
E21B 49/08 - Prélèvement d'échantillons de fluides ou test des fluides dans les trous de forage ou dans les puits
56.
Method For Enhancing Reactivity Of Pozzolanic Materials
A method of cementing may include preparing a cement slurry by mixing at least water and a cement dry blend, wherein the cement dry blend comprises a cement and an activated pozzolan; and introducing the cement slurry into a wellbore penetrating a subterranean formation; and allowing the cement slurry to set to form a hardened mass.
C09K 8/46 - Compositions de cimentation, p.ex. pour la cimentation des tubes dans les trous de forage; Compositions de bouchage, p.ex. pour tuer des puits contenant des liants inorganiques, p.ex. ciment Portland
C04B 40/00 - Procédés, en général, pour influencer ou modifier les propriétés des compositions pour mortiers, béton ou pierre artificielle, p.ex. leur aptitude à prendre ou à durcir
E21B 33/14 - Procédés ou dispositifs de cimentation, de bouchage des trous, des fissures ou analogues pour la cimentation des tubes dans les trous de forage ou de sondage
57.
DISPLAYING CONFIDENCE VALUES IN WELLBORE INVERSION MODELING USING A VISUAL INDICATOR
A system can display confidence values in a wellbore inversion model using a visual indicator. The system can receive downhole data relating to the wellbore from a downhole tool deployed in a wellbore of a geological formation during a wellbore operation. The system can additionally generate an inversion model of the geological formation by performing inversion processing on the downhole data. Furthermore, the system can determine confidence values for the downhole data in the inversion model. Additionally, the system can determine a depth of detection limit for the downhole data based on the confidence values. The system can output the inversion model, the depth of detection limit, and a visual indicator based on the confidence values for display at a display device for use in adjusting the wellbore operation.
A cement slurry including graphene, a cementitious material, and water; the graphene comprises bioderived renewable graphene (BRG). The cement slurry can comprise from about 0.01 to about 20, from about 0.1 to about 15, from about 0.5 to about 5 percent graphene by weight of cementitious material (% graphene bwoc). The cement slurry can have enhanced stability, as evidenced by a uniform density of the slurry and a reduction in free fluid, according to API 10B-2, relative to a same cement slurry absent the graphene.
C09K 8/467 - Compositions de cimentation, p.ex. pour la cimentation des tubes dans les trous de forage; Compositions de bouchage, p.ex. pour tuer des puits contenant des liants inorganiques, p.ex. ciment Portland contenant des additifs pour des utilisations spécifiques
C04B 28/02 - Compositions pour mortiers, béton ou pierre artificielle, contenant des liants inorganiques ou contenant le produit de réaction d'un liant inorganique et d'un liant organique, p.ex. contenant des ciments de polycarboxylates contenant des ciments hydrauliques autres que ceux de sulfate de calcium
A cement slurry including graphene, a cement, and water; the graphene comprises bioderived renewable graphene (BRG). The cement slurry has reduced transient gel formation relative to a same cement slurry absent the graphene. Methods of mitigating transient gels in cement are also provided.
E21B 33/14 - Procédés ou dispositifs de cimentation, de bouchage des trous, des fissures ou analogues pour la cimentation des tubes dans les trous de forage ou de sondage
E21B 21/06 - Dispositions pour traiter les fluides de forage à l'extérieur du trou de forage
E21B 43/26 - Procédés pour activer la production par formation de crevasses ou de fractures
C09K 8/46 - Compositions de cimentation, p.ex. pour la cimentation des tubes dans les trous de forage; Compositions de bouchage, p.ex. pour tuer des puits contenant des liants inorganiques, p.ex. ciment Portland
A cement slurry includes a set retarder comprising graphene, a cementitious material, and water; the graphene comprises bioderived renewable graphene (BRG). The cement slurry has from about 0.01 to about 20, from about 0.1 to about 15, or from about 0.5 to about 5 percent graphene by weight of cementitious material (% graphene bwoc). The cement slurry has an increased thickening time relative to a same cement slurry absent the graphene.
C09K 8/467 - Compositions de cimentation, p.ex. pour la cimentation des tubes dans les trous de forage; Compositions de bouchage, p.ex. pour tuer des puits contenant des liants inorganiques, p.ex. ciment Portland contenant des additifs pour des utilisations spécifiques
C04B 28/02 - Compositions pour mortiers, béton ou pierre artificielle, contenant des liants inorganiques ou contenant le produit de réaction d'un liant inorganique et d'un liant organique, p.ex. contenant des ciments de polycarboxylates contenant des ciments hydrauliques autres que ceux de sulfate de calcium
A drilling assembly control system is designed to mitigate drilling vibration by detecting and classifying lateral vibrations. Vibrations are detected along a bottom hole assembly using one or more inertial measurement units, those vibration measurements are classified by lateral vibration type, and mitigating actions are determined.
E21B 44/00 - Systèmes de commande automatique spécialement adaptés aux opérations de forage, c. à d. systèmes à fonctionnement autonome ayant pour rôle d'exécuter ou de modifier une opération de forage sans l'intervention d'un opérateur humain, p.ex. systèmes de ; Systèmes spécialement adaptés à la surveillance de plusieurs variables ou conditions de forage
E21B 47/12 - Moyens pour la transmission de signaux de mesure ou signaux de commande du puits vers la surface, ou de la surface vers le puits, p.ex. pour la diagraphie pendant le forage
62.
DOWNHOLE TRANSDUCER WITH A PIEZOELECTRIC CRYSTAL MATERIAL
A downhole transducer can include at least one single-crystal piezoelectric material, the at least one single-crystal piezoelectric material being positioned in the downhole transducer that is deployed downhole in a wellbore. Additionally, the downhole transducer can include at least one pair of electrodes positioned adjacent to the at least one single-crystal piezoelectric material for determining wellbore parameter measurements using one or more acoustic signals transmitted in the wellbore. The single-crystal piezoelectric material can include PIN-PZN-PT.
B06B 1/06 - Procédés ou appareils pour produire des vibrations mécaniques de fréquence infrasonore, sonore ou ultrasonore utilisant l'énergie électrique fonctionnant par effet piézo-électrique ou par électrostriction
E21B 47/00 - Relevés dans les trous de forage ou dans les puits
A blender power unit (BPU) for use in fracturing jobs. The BPU comprises a transformer having an input and an output and configured to receive electrical power via the input at a first voltage to output electrical power via the output at a second voltage; a motor power bus coupled to the output of the transformer; a motor starter bus; at least one motor soft starter having an input coupled to the motor power bus and having an coupled to the motor starter bus; a plurality of electric power relays coupled to the motor power bus and configured to supply electric power from the motor power bus to a load when in a closed state; and a plurality of start electric power relays coupled to the motor starter bus and configured to supply electric power from the motor starter bus to a load when in a closed state.
A variety of methods and compositions are disclosed, including, in one embodiment, A friction reducer comprising: a continuous phase comprising a base oil and a secondary oil, wherein the secondary oil is different than the base oil; a discontinuous phase dispersed in the continuation phase, wherein the discontinuous phase comprises water and a water-soluble polymer; and an emulsifying surfactant.
Aspects of the subject technology relate to systems and methods for identifying the quality of cement bonding of an exterior surface of a wellbore casing to an Earth formation. Methods of the present disclosure may allow for bond indexes to be identified in real-time as a cementing operation is performed even when tools that perform the cementing operation generate acoustic noise that interfere with measurements used to evaluate cement bonding quality. These methods may include transmitting acoustic signals, receiving acoustic signals, filtering the received acoustic signals, identifying magnitude and attenuation values to associate with the received acoustic signals, and comparing trends in the magnitudes with the identified attenuation values. These methods may also include correcting attenuation values associated with measured data based on a set of correction rules such that bond indexes can be identified. Such correction rules may be associated with data generated by a computer model.
Systems and techniques are described for a fluid diode. In some examples, a fluid diode can include a first fluid path for a first flow of fluid to traverse the fluid diode via a first flow direction and a second fluid path for a second flow of fluid to traverse the fluid diode via a second flow direction. The first flow direction can be associated with a first pressure drop and the second flow direction can be associated with a second pressure drop that is different than the first pressure drop. Moreover, the first fluid path and the second fluid path can be configured to remain open to the first flow and the second flow in the first flow direction and the second flow direction.
E21B 47/06 - Mesure de la température ou de la pression
E21B 49/08 - Prélèvement d'échantillons de fluides ou test des fluides dans les trous de forage ou dans les puits
G01N 11/08 - Recherche des propriétés d'écoulement des matériaux, p.ex. la viscosité, la plasticité; Analyse des matériaux en déterminant les propriétés d'écoulement en mesurant l'écoulement du matériau à travers un passage étroit, p.ex. un tube, une ouverture en mesurant la pression nécessaire à la production d'un écoulement connu
Systems and techniques are described for a fluid diode. In some examples, a fluid diode can include a first fluid path for a first flow of fluid to traverse the fluid diode via a first flow direction and a second fluid path for a second flow of fluid to traverse the fluid diode via a second flow direction. The first flow direction can be associated with a first pressure drop and the second flow direction can be associated with a second pressure drop that is different than the first pressure drop. Moreover, the first fluid path and the second fluid path can be configured to remain open to the first flow and the second flow in the first flow direction and the second flow direction.
E21B 34/08 - Aménagements des vannes pour les trous de forage ou pour les puits dans les puits sensibles à l'écoulement ou à la pression du fluide obtenu
E21B 43/12 - Procédés ou appareils pour commander l'écoulement du fluide extrait vers ou dans les puits
E21B 41/00 - Matériel ou accessoires non couverts par les groupes
E21B 47/00 - Relevés dans les trous de forage ou dans les puits
68.
DETECTION, CLASSIFICATION AND MITIGATION OF LATERAL VIBRATIONS ALONG DOWNHOLE DRILLING ASSEMBLIES
A drilling assembly control system is designed to mitigate drilling vibration by detecting and classifying lateral vibrations. Vibrations are detected along a bottom hole assembly using one or more inertial measurement units, those vibration measurements are classified by lateral vibration type, and mitigating actions are determined.
E21B 49/00 - Test pour déterminer la nature des parois des trous de forage; Essais de couches; Procédés ou appareils pour prélever des échantillons du terrain ou de fluides en provenance des puits, spécialement adaptés au forage du sol ou aux puits
E21B 44/02 - Commande automatique de l'avance de l'outil
A composition including a particulate, water, and a suspension aid comprising graphene, wherein the graphene comprises bioderived renewable graphene (BRG) and wherein the particulate is suspended in the composition. Methods of making and using the composition are also provided.
C09K 8/50 - Compositions pour le plâtrage des parois de trous de forage, c. à d. compositions pour la consolidation temporaire des parois des trous de forage
C09K 8/42 - Compositions de cimentation, p.ex. pour la cimentation des tubes dans les trous de forage; Compositions de bouchage, p.ex. pour tuer des puits
A mechanical clutch allows for transfer of torque downhole that may avoid the need for a hydraulic electrical coil-driven piston. In one or more examples, an anti-rotation guide for a downhole clutch includes a guide track and a follower moveable along the guide track for guiding relative movement between an upper armature and a lower armature. The guide track includes an axially-extending portion terminating in a circumferential loop. The axially extending portion guides the upper armature into axial engagement with the lower armature in response to rotation of the input shaft. The circumferential loop thereafter allows rotation of the upper and lower armatures together in response to further rotation of the input shaft.
E21B 34/14 - Aménagements des vannes pour les trous de forage ou pour les puits dans les puits actionnés par le mouvement des outils, p.ex. obturateurs à manchons actionnés par des pistons ou par des outils à câble
E21B 41/00 - Matériel ou accessoires non couverts par les groupes
F16D 23/00 - ACCOUPLEMENTS POUR LA TRANSMISSION DES MOUVEMENTS DE ROTATION; EMBRAYAGES; FREINS - Détails des embrayages actionnés mécaniquement et non spécifiques d'un type distinct; Dispositions pour la synchronisation des embrayages
A composition including a particulate, water, and a suspension aid comprising graphene, wherein the graphene comprises bioderived renewable graphene (BRG) and wherein the particulate is suspended in the composition. Methods of making and using the composition are also provided.
C09K 8/467 - Compositions de cimentation, p.ex. pour la cimentation des tubes dans les trous de forage; Compositions de bouchage, p.ex. pour tuer des puits contenant des liants inorganiques, p.ex. ciment Portland contenant des additifs pour des utilisations spécifiques
A cement slurry includes a set retarder comprising graphene, a cementitious material, and water; the graphene comprises bioderived renewable graphene (BRG). The cement slurry has from about 0.01 to about 20, from about 0.1 to about 15, or from about 0.5 to about 5 percent graphene by weight of cementitious material (% graphene bwoc). The cement slurry has an increased thickening time relative to a same cement slurry absent the graphene.
C09K 8/467 - Compositions de cimentation, p.ex. pour la cimentation des tubes dans les trous de forage; Compositions de bouchage, p.ex. pour tuer des puits contenant des liants inorganiques, p.ex. ciment Portland contenant des additifs pour des utilisations spécifiques
A cement slurry including graphene, a cement, and water; the graphene comprises bioderived renewable graphene (BRG). The cement slurry has reduced transient gel formation relative to a same cement slurry absent the graphene. Methods of mitigating transient gels in cement are also provided.
A cement slurry including graphene, a cementitious material, and water; the graphene comprises bioderived renewable graphene (BRG). The cement slurry can comprise from about 0.01 to about 20, from about 0.1 to about 15, from about 0.5 to about 5 percent graphene by weight of cementitious material (% graphene bwoc). The cement slurry can have enhanced stability, as evidenced by a uniform density of the slurry and a reduction in free fluid, according to API 10B-2, relative to a same cement slurry absent the graphene.
C04B 40/00 - Procédés, en général, pour influencer ou modifier les propriétés des compositions pour mortiers, béton ou pierre artificielle, p.ex. leur aptitude à prendre ou à durcir
C09K 8/467 - Compositions de cimentation, p.ex. pour la cimentation des tubes dans les trous de forage; Compositions de bouchage, p.ex. pour tuer des puits contenant des liants inorganiques, p.ex. ciment Portland contenant des additifs pour des utilisations spécifiques
E21B 33/13 - Procédés ou dispositifs de cimentation, de bouchage des trous, des fissures ou analogues
Apparatus and methods are disclosed for securing a component, such as a sealing element, to a tubular member, such as a mandrel, of a downhole tool. In at least one example, a retaining ring is used to secure the component to a mandrel. The retaining ring is secured to the mandrel with a plurality of discrete retention segments disposed within a channel at least partially defined by an internal groove on the retaining ring and an external groove on the mandrel. The retention segments are individually insertable into the channel through an access opening on the retaining ring. A compression spring may be provided in the channel to provide compressive engagement of the retention segments. Various closure configurations are also disclosed for closing the access opening once the retention segments have been inserted.
A method and system for performing a pressure test. The method may include inserting a formation testing tool into a wellbore to a first location within the wellbore based at least in part on a figure of merit. The formation testing tool may include at least one probe, a pump disposed within the formation testing tool and connect to the at least one probe by at least one probe channel and at least one fluid passageway, and at least one stabilizer disposed on the formation testing tool. The method may further include activating the at least one stabilizer, wherein the at least one stabilizer is activated into a surface of the wellbore and performing the pressure test and determining at least one formation property from the pressure test.
The disclosure presents processes to determine one or more recommendations to well construction operations, generated by analyzing impacts on well construction operations. The impacts can include impacts to the drilling assembly, impacts of the subterranean formation characteristics, impacts on cost, time and performance of the well construction operation, impacts on the service quality, impacts to system integrity, impacts to surface equipment, as well as other impact types, such as geological surveys, seismic surveys, stratigraphic analysis, or reservoir estimations. Each impact can be analyzed using an impact parameter and a softness parameter. An impact map can be computed for each of the parameters, and then the impact maps can be combined to compute one or more integrated impact maps from which the recommendations can be determined. The recommendations can be communicated to a well construction system, such as a geo-steering system, a user system, a well site controller, or other systems.
E21B 44/00 - Systèmes de commande automatique spécialement adaptés aux opérations de forage, c. à d. systèmes à fonctionnement autonome ayant pour rôle d'exécuter ou de modifier une opération de forage sans l'intervention d'un opérateur humain, p.ex. systèmes de ; Systèmes spécialement adaptés à la surveillance de plusieurs variables ou conditions de forage
E21B 47/12 - Moyens pour la transmission de signaux de mesure ou signaux de commande du puits vers la surface, ou de la surface vers le puits, p.ex. pour la diagraphie pendant le forage
A sealed enclosure can include a glass portion that can be positioned with respect to an electromagnetic component that is in an area defined by the sealed enclosure. The enclosure can prevent fluid from a wellbore environment from contacting the electromagnetic component and to allow the electromagnetic component to wirelessly communicate with a component external to the sealed enclosure. A second portion interfaces with the glass portion for preventing the fluid from the wellbore environment from contacting the electromagnetic component.
G01V 3/18 - Prospection ou détection électrique ou magnétique; Mesure des caractéristiques du champ magnétique de la terre, p.ex. de la déclinaison ou de la déviation spécialement adaptée au carottage
E21B 47/13 - Moyens pour la transmission de signaux de mesure ou signaux de commande du puits vers la surface, ou de la surface vers le puits, p.ex. pour la diagraphie pendant le forage par énergie électromagnétique, p.ex. gammes de fréquence radio
E21B 47/01 - Dispositifs pour supporter des instruments de mesure sur des trépans, des tubes, des tiges ou des câbles de forage; Protection des instruments de mesure dans les trous de forage contre la chaleur, les chocs, la pression ou similaire
79.
MODIFIED VEGETABLE OIL AS FLUID LOSS CONTROL ADDITIVE
Invert emulsions can be used in oil and gas operations. A fluid loss control additive (FLCA) is a component of the fluid that can be utilized to control or minimize fluid loss into a subterranean formation. The FLCA can be a chemically modified vegetable oil that is biodegradable. Vegetable oils having some or all of the functional groups sulfonated can be used as FLCA. A water-soluble salt that has been dissolved in the discontinuous phase of the invert emulsion can combine with the FLCA to form a wax-like, solid mass.
The disclosure presents processes to determine one or more recommendations to well construction operations, generated by analyzing impacts on well construction operations. The impacts can include impacts to the drilling assembly, impacts of the subterranean formation characteristics, impacts on cost, time and performance of the well construction operation, impacts on the service quality, impacts to system integrity, impacts to surface equipment, as well as other impact types, such as geological surveys, seismic surveys, stratigraphic analysis, or reservoir estimations. Each impact can be analyzed using an impact parameter and a softness parameter. An impact map can be computed for each of the parameters, and then the impact maps can be combined to compute one or more integrated impact maps from which the recommendations can be determined. The recommendations can be communicated to a well construction system, such as a geo-steering system, a user system, a well site controller, or other systems.
A mechanical clutch allows for transfer of torque downhole that may avoid the need for a hydraulic electrical coil-driven piston. In one or more examples, an anti-rotation guide for a downhole clutch includes a guide track and a follower moveable along the guide track for guiding relative movement between an upper armature and a lower armature. The guide track includes an axially-extending portion terminating in a circumferential loop. The axially extending portion guides the upper armature into axial engagement with the lower armature in response to rotation of the input shaft. The circumferential loop thereafter allows rotation of the upper and lower armatures together in response to further rotation of the input shaft.
E21B 4/00 - Moyens d'entraînement dans le trou de forage
E21B 34/06 - Aménagements des vannes pour les trous de forage ou pour les puits dans les puits
E21B 34/10 - Aménagements des vannes pour les trous de forage ou pour les puits dans les puits actionnés par un fluide de commande provenant de l'extérieur du trou de forage
82.
A POSITION SENSOR ASSEMBLY WITH CIRCUMFERENTIAL MAGNETIC COUPLING FOR WELLBORE OPERATIONS
A downhole tool can include a position sensor comprising a first set of magnets and an internal slider. The downhole tool can also include a valve magnet assembly comprising a second set of magnets magnetically couplable to the first set of magnets. The second set of magnets can be positionable circumferentially around an outer diameter of the position sensor. The valve magnet assembly can be configured to move in response to a fluid valve. The valve magnet assembly can be configured to cause the internal slider of the position sensor to move in response to movement of the valve magnet assembly.
E21B 34/10 - Aménagements des vannes pour les trous de forage ou pour les puits dans les puits actionnés par un fluide de commande provenant de l'extérieur du trou de forage
E21B 34/08 - Aménagements des vannes pour les trous de forage ou pour les puits dans les puits sensibles à l'écoulement ou à la pression du fluide obtenu
E21B 47/01 - Dispositifs pour supporter des instruments de mesure sur des trépans, des tubes, des tiges ou des câbles de forage; Protection des instruments de mesure dans les trous de forage contre la chaleur, les chocs, la pression ou similaire
gravel pack screen solution; oil and gas well completion equipment, namely, metal sand control screens; oil and gas well completion tool used for placement down-hole in a well bore of an oil and/or gas well, namely, flow control valves for regulating the flow of gases and liquids, said completion tool used in connection with drill strings, and sand control screens and tubes, for controlling the inflow of oil, water and gas from an oil and/or gas reservoir into the oil and/or gas well
84.
GENERATING PRESSURE WAVES IN A FLOWLINE OR A WELLBORE
A system can be used for generating a pressure signal in a flow path defined by a tubular. The system can include a pressure source, a valve, and a controller. The controller can output a command to control the pressure source for outputting a fluid hammer, according to the command, through the valve and into a flow path defined by a wellbore tubular. The system can be positioned external to the flow path. The system can determine, based on the reflection signal, a presence of a deposition, a blockage, or a leak within the flowline while the flowline is in operation.
E21B 21/08 - Commande ou surveillance de la pression ou de l'écoulement du fluide de forage, p.ex. remplissage automatique des trous de forage, commande automatique de la pression au fond
E21B 21/10 - Aménagements des vannes dans les systèmes de circulation des fluides de forage
85.
Multi-Activation Reamer With Activation Confirmation
A multi-activation reamer optionally includes modular activation and pulse confirmation blocks for activating the reamer and confirming activation. A reamer activation signal may be communicated downhole, optionally using an activation sequence of drill string flow and rotation detectable by downhole sensors. An on-board controller receives the activation signal and opens an activation flow path in the activation block to hydraulically actuate the reamer arms. A pulse flow path is also opened in the pulse confirmation block, optionally using pressure from the activation flow path. Flow along the pulse flow path is modulated to generate a flow pattern detectable uphole of the reamer to confirm activation of the reamer.
E21B 7/28 - Elargissement des trous forés, p.ex. par forage à contresens
E21B 10/32 - Trépans avec une partie pilote, c. à d. trépans comportant un organe coupant pilote; Trépans pour élargir le trou de forage, p.ex. alésoirs à organes coupants expansibles
86.
FLUID OPTICAL DATABASE RECONSTRUCTION METHODS AND APPLICATIONS THEREOF
A method includes receiving first material property data for a first material in one or more second materials, detecting material sensor data from at least one sensor, and applying an inverse model and a forward model to the first material property data to provide, at least in part, synthetic sensor measurement data for the one or more second materials.
G06F 16/11 - Administration des systèmes de fichiers, p.ex. détails de l’archivage ou d’instantanés
E21B 49/08 - Prélèvement d'échantillons de fluides ou test des fluides dans les trous de forage ou dans les puits
G01N 21/3577 - Couleur; Propriétés spectrales, c. à d. comparaison de l'effet du matériau sur la lumière pour plusieurs longueurs d'ondes ou plusieurs bandes de longueurs d'ondes différentes en recherchant l'effet relatif du matériau pour les longueurs d'ondes caractéristiques d'éléments ou de molécules spécifiques, p.ex. spectrométrie d'absorption atomique en utilisant la lumière infrarouge pour l'analyse de liquides, p.ex. l'eau polluée
G01N 21/94 - Recherche de souillures, p.ex. de poussières
Systems and methods of the present disclosure relate to actuator assemblies for downhole tools. An actuator assembly comprises a ball screw; a ball nut disposed around the ball screw; a cam disposed around the ball nut; a rail disposed adjacent to the cam, the rail operable to stop rotation of the cam to extend the cam axially as the ball nut traverses the ball screw.
E21B 34/06 - Aménagements des vannes pour les trous de forage ou pour les puits dans les puits
E21B 34/10 - Aménagements des vannes pour les trous de forage ou pour les puits dans les puits actionnés par un fluide de commande provenant de l'extérieur du trou de forage
88.
GENERATING PRESSURE WAVES IN A FLOWLINE OR A WELLBORE
A system can be used for generating a pressure signal in a flow path defined by a tubular. The system can include a pressure source, a valve, and a controller. The controller can output a command to control the pressure source for outputting a fluid hammer, according to the command, through the valve and into a flow path defined by a wellbore tubular. The system can be positioned external to the flow path. The system can determine, based on the reflection signal, a presence of a deposition, a blockage, or a leak within the flowline while the flowline is in operation.
E21B 47/18 - Moyens pour la transmission de signaux de mesure ou signaux de commande du puits vers la surface, ou de la surface vers le puits, p.ex. pour la diagraphie pendant le forage utilisant des ondes acoustiques à travers le fluide du puits
E21B 47/06 - Mesure de la température ou de la pression
E21B 21/08 - Commande ou surveillance de la pression ou de l'écoulement du fluide de forage, p.ex. remplissage automatique des trous de forage, commande automatique de la pression au fond
89.
DETERMINING RELATIVE PERMEABILITY IN A ROCK SAMPLE
Aspects of the subject technology relate to systems, methods, and computer-readable media for identifying a relative permeability of a core sample through a computerized representation of a pore structure of the sample. Specifically, a computerized representation of a three-dimensional (3D) pore structure of a core sample can be accessed. A relative permeability of oil through the 3D pore structure can be determined in three dimensions. Further, a relative permeability of water through the 3D pore structure can be determined in the three dimensions. Average relative permeabilities of oil and water of the 3D pore structure can be identified based on the relative permeability of the oil in the three dimensions and the relative permeability of the water in the three dimensions.
A downhole tool can include a position sensor comprising a first set of magnets and an internal slider. The downhole tool can also include a valve magnet assembly comprising a second set of magnets magnetically couplable to the first set of magnets. The second set of magnets can be positionable circumferentially around an outer diameter of the position sensor. The valve magnet assembly can be configured to move in response to a fluid valve. The valve magnet assembly can be configured to cause the internal slider of the position sensor to move in response to movement of the valve magnet assembly.
E21B 47/092 - Localisation ou détermination de la position d'objets dans les trous de forage ou dans les puits; Identification des parties libres ou bloquées des tubes par détection d'anomalies magnétiques
E21B 34/12 - Aménagements des vannes pour les trous de forage ou pour les puits dans les puits actionnés par le mouvement des tubages ou des colonnes de production
91.
ELECTRONICS ENCLOSURE WITH GLASS PORTION FOR USE IN A WELLBORE
A sealed enclosure can include a glass portion that can be positioned with respect to an electromagnetic component that is in an area defined by the sealed enclosure. The enclosure can prevent fluid from a wellbore environment from contacting the electromagnetic component and to allow the electromagnetic component to wirelessly communicate with a component external to the sealed enclosure. A second portion interfaces with the glass portion for preventing the fluid from the wellbore environment from contacting the electromagnetic component.
Systems and methods of the present disclosure relate to actuator assemblies for downhole tools. An actuator assembly comprises a ball screw; a ball nut disposed around the ball screw; a cam disposed around the ball nut; a rail disposed adjacent to the cam, the rail operable to stop rotation of the cam to extend the cam axially as the ball nut traverses the ball screw.
Aspects of the subject technology relate to systems, methods, and computer-readable media for identifying a relative permeability of a core sample through a computerized representation of a pore structure of the sample. Specifically, a computerized representation of a three-dimensional (3D) pore structure of a core sample can be accessed. A relative permeability of oil through the 3D pore structure can be determined in three dimensions. Further, a relative permeability of water through the 3D pore structure can be determined in the three dimensions. Average relative permeabilities of oil and water of the 3D pore structure can be identified based on the relative permeability of the oil in the three dimensions and the relative permeability of the water in the three dimensions.
E21B 49/02 - Test pour déterminer la nature des parois des trous de forage; Essais de couches; Procédés ou appareils pour prélever des échantillons du terrain ou de fluides en provenance des puits, spécialement adaptés au forage du sol ou aux puits par prélèvements mécaniques d'échantillons du terrain
G01N 15/08 - Recherche de la perméabilité, du volume des pores ou de l'aire superficielle des matériaux poreux
94.
Distributed control system with failover capabilities for physical well equipment
A distributed control system can be used to implement failover capabilities for control units that control well equipment during a well operation. For example, a system can include first well equipment that performs a first physical task and second well equipment that performs a second physical task different from the first physical task. Additionally, the system can include a distributed control system with a first control unit coupled to the first well equipment and a second control unit coupled to the second well equipment. Both control units may include a first control module and a second control module for automatically controlling the first physical task and the second physical task, respectively. The distributed control system can detect a failure of the second control unit and initiate a failover process in which the first control unit takes over control of the second physical task by enabling the second control module.
G01V 1/44 - Séismologie; Prospection ou détection sismique ou acoustique spécialement adaptées au carottage en utilisant des générateurs et des récepteurs situés dans le même puits
95.
Monitoring a wellbore operation using distributed artificial intelligence
Distributed artificial intelligence (AI) can be used to monitor a wellbore operation in some examples described herein. In one such example, physical equipment can be positioned at a surface of a wellsite to support a drilling operation at the wellsite. Each piece of physical equipment may include a sensor module, a processor communicatively coupled to the sensor module, and a memory. The memory can include an AI module configured to determine a condition associated with the equipment by analyzing sensor data from the sensor module using one or more machine-learning models. The memory additionally can include a warning module for causing the processor to output a warning notification based on the condition. The memory further can include a communications module for causing the processor to transmit a communication indicating the condition to a destination via a network. The communication may be different from the warning notification.
G05B 13/02 - Systèmes de commande adaptatifs, c. à d. systèmes se réglant eux-mêmes automatiquement pour obtenir un rendement optimal suivant un critère prédéterminé électriques
E21B 41/00 - Matériel ou accessoires non couverts par les groupes
G01M 99/00 - Matière non prévue dans les autres groupes de la présente sous-classe
G08B 21/08 - Alarmes pour assurer la sécurité des personnes réagissant à un état anormal d'une masse d'eau
A body of a shear pin can be positioned in a pad stopper of a steering pad of a rotary steerable system. The rotary steerable system can be used to steer a drill in a wellbore. The steering pad can be positioned on the rotary steerable system such that a head of the shear pin is coupled with a lateral pad of the rotary steerable system. The head of the shear pin can deactivate the steering pad by preventing the steering pad from actuating. A fluid pulse can be output in the wellbore to break the shear pin for enabling the steering pad to actuate to cause the rotary steerable system to steer the drill in the wellbore.
Provided is a density sensor, a downhole tool, and a well system. The density sensor, in one aspect, includes one or more float chambers, and two or more floats located within the one or more float chambers. In one aspect, the two or more floats have a density ranging from.08 sg to 2.1 sg, and further a first of the two or more floats has a first known density (ρ1) and a second of the two or more floats has a second known density (ρ2) greater than the first known density (ρ1). The density sensor, according to this aspect, may further include one or more sensors located proximate the one or more float chambers, the one or more sensors configured to sense whether ones of the two or more floats sink or float within production fluid having an unknown density (ρf).
E21B 47/10 - Localisation des fuites, intrusions ou mouvements du fluide
E21B 41/00 - Matériel ou accessoires non couverts par les groupes
E21B 43/12 - Procédés ou appareils pour commander l'écoulement du fluide extrait vers ou dans les puits
E21B 47/12 - Moyens pour la transmission de signaux de mesure ou signaux de commande du puits vers la surface, ou de la surface vers le puits, p.ex. pour la diagraphie pendant le forage
98.
SENSOR FOR QUANTIFYING PRODUCTION FLUID PERCENTAGE CONTENT
1go2oww). The downhole tool, according to this aspect, further includes two or more non-contact proximity sensors configured to sense a radial location of the two or more floats to determine a gas:oil ratio and oil:water ratio.
E21B 47/10 - Localisation des fuites, intrusions ou mouvements du fluide
E21B 41/00 - Matériel ou accessoires non couverts par les groupes
E21B 47/12 - Moyens pour la transmission de signaux de mesure ou signaux de commande du puits vers la surface, ou de la surface vers le puits, p.ex. pour la diagraphie pendant le forage
E21B 43/12 - Procédés ou appareils pour commander l'écoulement du fluide extrait vers ou dans les puits
A body of a shear pin can be positioned in a pad stopper of a steering pad of a rotary steerable system. The rotary steerable system can be used to steer a drill in a wellbore. The steering pad can be positioned on the rotary steerable system such that a head of the shear pin is coupled with a lateral pad of the rotary steerable system. The head of the shear pin can deactivate the steering pad by preventing the steering pad from actuating. A fluid pulse can be output in the wellbore to break the shear pin for enabling the steering pad to actuate to cause the rotary steerable system to steer the drill in the wellbore.
E21B 17/10 - Protecteurs contre l'usure; Dispositifs de centrage
E21B 7/06 - Modification de la direction du trou de forage
E21B 34/10 - Aménagements des vannes pour les trous de forage ou pour les puits dans les puits actionnés par un fluide de commande provenant de l'extérieur du trou de forage
100.
STEERING VALVE FOR DEACTIVATING A STEERING PAD OF A ROTARY STEERABLE SYSTEM
A rotary steerable drilling system can be positioned in a subterranean formation to steer a drill to form a wellbore in the subterranean formation. An orientation of a steering valve, which is positioned in the rotary steerable drilling system, can be adjusted to cover each channel of one or more channels of a valve seat adjacent the steering valve to deactivate each steering pad of one or more steering pads of the rotary steerable drilling system. The orientation of the steering valve can be adjusted to activate at least one steering pad of the one or more steering pads of the rotary steerable drilling system.
E21B 7/06 - Modification de la direction du trou de forage
E21B 44/00 - Systèmes de commande automatique spécialement adaptés aux opérations de forage, c. à d. systèmes à fonctionnement autonome ayant pour rôle d'exécuter ou de modifier une opération de forage sans l'intervention d'un opérateur humain, p.ex. systèmes de ; Systèmes spécialement adaptés à la surveillance de plusieurs variables ou conditions de forage
E21B 44/02 - Commande automatique de l'avance de l'outil