A method can include receiving strain data associated with propagation of a hydraulic fracture in a subsurface geologic region; performing a comparison between the strain data and simulation results generated using a mesh model of the subsurface geologic region and enrichment equations that represent one or more discontinuities in the subsurface geologic region; and, based on the comparison, characterizing the subsurface geologic region.
E21B 47/005 - Surveillance ou contrôle de la qualité ou du niveau de cimentation
E21B 43/26 - Procédés pour activer la production par formation de crevasses ou de fractures
E21B 49/00 - Test pour déterminer la nature des parois des trous de forageEssais de couchesProcédés ou appareils pour prélever des échantillons du terrain ou de fluides en provenance des puits, spécialement adaptés au forage du sol ou aux puits
G01V 1/44 - SéismologieProspection ou détection sismique ou acoustique spécialement adaptées au carottage en utilisant des générateurs et des récepteurs situés dans le même puits
A downhole valve assembly includes a safety valve and an actuator that opens and/or closes the valve. The actuator can be an electro-hydraulic actuator (EHA), an electro mechanical actuator (EMA), or an electro hydraulic pump (EHP). The downhole safety valve can also include an electric magnet. The electric magnet can act as or control a magnetic decoupling mechanism to control closure of the safety valve.
A method of optimizing production from a wellbore. The method may include receiving pressure data from the wellbore, determining a gradient measurement based on the received pressure data, performing an automated flow control device sequence in a plurality of zones of the wellbore when the gradient measurement exceeds or drops below a predetermined threshold to provide a plurality of stabilized gradient measurements, and normalizing the gradient measurement based on the stabilized gradient measurements to provide a fluid characteristic for each of the zones. Each of the plurality of stabilized gradient measurements may correspond to one of the plurality of zones. Performing the automated flow control device sequence may include stopping a flow within one of the plurality of zones, detecting change in the gradient measurement while the flow within the first zone is stopped, recording a stabilized gradient measurement, and then resuming the flow within the first zone.
The present disclosure relates to hydrogen swellable fillers, methods for their preparation and their use in, for example, oil-field exploration, production, testing, underground gas storage, production and transportation. The hydrogen swellable material can include an elastomer and a filler. The elastomer can have a hardness between about 40 and about 80 shore A, and the hydrogen swellable material swells in volume between about 40% and about 100% upon contact with hydrogen.
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
Systems and methods for a multi-finger caliper (MFC) tool are provided. A method for an MFC tool on a digital slickline (DSL) in a well at a wellsite includes: collecting MFC raw data from a plurality of fingers of an MFC tool while downhole, processing the MFC raw data, the processing including: determining values for each of the plurality of fingers of the MFC tool from the MFC raw data over time, generating calibrated data by applying a calibration to the MFC raw data and to the processed determined values, and extracting key information from the calibrated data and values for each finger of the MFC tool the key information including a calibrated minimum, maximum, and average radius values for all fingers together, sorting the extracted key information, including generating a log of the key information, and electronically transmitting the log on the DSL to a surface of the wellsite.
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 47/024 - Détermination de l'inclinaison ou de la direction des dispositifs dans le trou de forage
E21B 47/08 - Mesure du diamètre ou des dimensions correspondantes des trous de forage
6.
SYSTEMS AND METHODS FOR DETECTING DEPOSIT ACCUMULATION WITHIN A MULTIPHASE FLOW METER
A multiphase flow meter comprising a venturi channel through a multiphase stream of fluid is enabled to flow, a multivariable transmitter adapted to measure a pressure differential across the venturi channel, and a controller adapted to a plurality of measurements indicative of a pressure differential across the venturi channel during a first period of time, determine a baseline value for a statistical characteristic associated with pressure differential across the venturi channel, receive a new measurement indicative of pressure differential across the venturi channel after the first period of time, a new value for the statistical characteristic associated with pressure differential across the venturi channel, determine whether a difference between the baseline value and the new value exceeds a threshold, and responsive to determining that the difference between the baseline value and the new value exceeds the threshold, generate an alert that indicative of deposit accumulation in the multiphase flow meter.
G01F 15/063 - Dispositifs d'indication ou d'enregistrement pour l'indication à distance utilisant des moyens électriques
G01F 1/34 - 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 en mesurant la pression ou la différence de pression
7.
SELF-SUPERVISED LEARNING WITH CROSS-TRAINING BETWEEN CONVOLUTIONAL NEURAL NETWORK AND TRANSFORMER FOR LOW-FREQUENCY ENHANCEMENTS
A method for enhancing seismic data comprises receiving seismic data associated with a subsurface formation, training a convolutional neural network and a transformer neural network in a self-supervised cross-training framework, and applying the trained transformer neural network to the seismic data to generate enhanced seismic data. The training includes generating training pairs by applying high-pass filtering to the seismic data, generating a first prediction from the convolutional neural network and a second prediction from the transformer neural network using the training pairs, and establishing bidirectional flow of outputs between the convolutional neural network and the transformer neural network.
G01V 1/36 - Exécution de corrections statiques ou dynamiques sur des enregistrements, p. ex. correction de l'étalementÉtablissement d'une corrélation entre signaux sismiquesÉlimination des effets produits par un excès d'énergie
G01V 1/28 - Traitement des données sismiques, p. ex. pour l’interprétation ou pour la détection d’événements
G01V 1/38 - SéismologieProspection ou détection sismique ou acoustique spécialement adaptées aux zones recouvertes d'eau
Aspects of the present disclosure provide for a cable. The cable includes a fiber bundle including a plurality of optical fibers, a first layer in contact with an outer surface of the fiber bundle, a second layer in contact with an outer diameter of the first layer, a polymeric jacket extruded over an outer diameter of the second layer, a strengthening layer disposed about the polymeric jacket, and a metallic tubular disposed about the strengthening layer.
A method for automating corrosion detection for process equipment includes receiving a raw image of the process equipment from an imaging device. The method also includes generating input prompts based upon the raw image, where the input prompts are generated by a prompt engine. The method further includes identifying, with a pretrained generative artificial intelligence (AI) model, one or more segmentations of corrosion on the process equipment based on the input prompts and the raw image. The method may also include determining a corrosion condition for each segmentation of the one or more segmentations of corrosion.
G06V 10/774 - Génération d'ensembles de motifs de formationTraitement des caractéristiques d’images ou de vidéos dans les espaces de caractéristiquesDispositions pour la reconnaissance ou la compréhension d’images ou de vidéos utilisant la reconnaissance de formes ou l’apprentissage automatique utilisant l’intégration et la réduction de données, p. ex. analyse en composantes principales [PCA] ou analyse en composantes indépendantes [ ICA] ou cartes auto-organisatrices [SOM]Séparation aveugle de source méthodes de Bootstrap, p. ex. "bagging” ou “boosting”
G06V 10/82 - Dispositions pour la reconnaissance ou la compréhension d’images ou de vidéos utilisant la reconnaissance de formes ou l’apprentissage automatique utilisant les réseaux neuronaux
10.
MONITORING AN INDUSTRIAL FACILTY EMPLOYING INDUSTRIAL INTERNET OF THINGS (IIOT) SENSORS USING A TACTICAL COMPUTE APPLICATION
Systems and methods are provided for monitoring operations of an industrial facility. A gateway device is located at the industrial facility and operably coupled to sensors disposed at the industrial facility. The gateway device executes tasks configured to i) monitor alarms or triggers or other events related to operating conditions of the industrial facility, ii) identify a particular alarm or trigger or other event that is activated or set, iii) identify at least one risk associated with the particular alarm or trigger or other event that is activated or set, and iv) dynamically construct a causal network to evaluate the at least one risk. The tasks can be implemented by a behavior tree (BT) that combines automated causal network generation and risk analysis. The BT performs real-time analysis of the sensor data to generate actions or indicators from the sensor data for input to the causal network for risk analysis.
H04L 41/069 - Gestion des fautes, des événements, des alarmes ou des notifications en utilisant des journaux de notificationsPost-traitement des notifications
H04L 41/142 - Analyse ou conception de réseau en utilisant des méthodes statistiques ou mathématiques
H04L 41/16 - Dispositions pour la maintenance, l’administration ou la gestion des réseaux de commutation de données, p. ex. des réseaux de commutation de paquets en utilisant l'apprentissage automatique ou l'intelligence artificielle
H04L 67/12 - Protocoles spécialement adaptés aux environnements propriétaires ou de mise en réseau pour un usage spécial, p. ex. les réseaux médicaux, les réseaux de capteurs, les réseaux dans les véhicules ou les réseaux de mesure à distance
A method can include issuing control instructions by a controller to control rig equipment for drilling of a borehole in a subsurface environment, where the rig equipment includes a drawworks for control of weight-on-bit of a drillstring disposed in part in the borehole, and where the controller includes a tunable weight-on-bit set point control loop; during the drilling of the borehole, receiving sensor data as feedback; dynamically determining a tuning parameter value for the tunable weight-on-bit set point control loop using the feedback and an agent, wherein the agent prioritizes pre-defined drilling behavior; determining a control instruction using the controller and the tuning parameter value for the tunable weight-on-bit set point control loop in the tunable weight-on-bit set point control loop; and issuing the control instruction by the controller to control the rig equipment for drilling of the borehole according to the pre-defined drilling behavior.
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 forage commandés par ordinateurSystèmes spécialement adaptés à la surveillance de plusieurs variables ou conditions de forage
E21B 45/00 - Mesure du temps de forage ou de la vitesse de pénétration
A gas lift valve includes a backcheck valve including a rupture disc configured to rupture at a threshold pressure, a sleeve held in place by a circumferential spring disposed within a circumferential groove in a housing containing the sleeve in a pre-shear state and a valve element movable by a longitudinal force caused by a linear spring in a chamber formed between the housing and a shelf of the sleeve in response to the rupture of the rupture disc, wherein the longitudinal force overcomes a frictional force of the circumferential spring holding the sleeve in place.
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
F16K 3/24 - Robinets-vannes ou tiroirs, c.-à-d. dispositifs obturateurs dont l'élément de fermeture glisse le long d'un siège pour l'ouverture ou la fermeture à faces d'obturation en forme de surfaces de solides de révolution avec corps de tiroir cylindrique
F16K 17/196 - Soupapes ou clapets d'équilibrage, principalement pour réservoirs actionnés par ressort
F16K 31/122 - Moyens de fonctionnementDispositifs de retour à la position de repos actionnés par un fluide le fluide agissant sur un piston
A method may include receiving, at a processing system, surface data associated with a liner hanger system during performance of a liner hanger job from multiple sensors at a wellsite. The method also may include identifying, via the processing system, features associated with each event in a series of events associated with the liner hanger job and identifying parameters for machine learning models based on cross-validation of the surface data. The method may further include training, via the processing system, the machine learning models to identify the series of events in the liner hanger job based on the identified features and the identified parameters, where each machine learning model is associated with an event in the series of events. Additionally, the method may include generating, via the machine learning models, an inference as to a completion of an event based on the surface data.
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
G06N 5/04 - Modèles d’inférence ou de raisonnement
14.
METHOD FOR DEGRADATION OF PFAS BASED ON SONOCATALYSIS
Certain aspects of the present disclosure provide a method for removing PFAS contaminants from a PFAS contaminated aqueous stream. The method includes introducing the PFAS contaminated aqueous stream into a reactor with a photocatalyst reagent in the presence of UV radiation and ultrasonic energy to degrade the PFAS contaminants and produce a treated aqueous stream comprising byproducts of the degraded PFAS contaminants.
A method for predicting buckling behavior in a torque and drag analysis of a tubular string in a wellbore includes performing a first finite element analysis (FEA) on the tubular string. The method also includes determining one or more first properties of the tubular string based upon the first FEA. The method also includes identifying a possible buckling zone in the tubular string based upon the one or more first properties. The method also includes splitting the possible buckling zone into a plurality of segments. The method also includes performing a second FEA on one or more of the segments. The method also includes determining one or more second properties of the tubular string based upon the second FEA. The method also includes comparing the one or more first properties of first FEA to the one or more second properties of second FEA to identify incremental changes therebetween.
G06F 30/20 - Optimisation, vérification ou simulation de l’objet conçu
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 forage commandés par ordinateurSystèmes spécialement adaptés à la surveillance de plusieurs variables ou conditions de forage
E21B 47/007 - Mesure des contraintes dans le cuvelage ou la tige de forage
16.
TRANSITIONING A PRODUCTION FACILITY TO A TARGET OPERATING STATE BASED ON CARBON DIOXIDE EMISSIONS
A production facility control system may apply a first predictive controller to the current operating state to generate a first transitionary state between the current operating state and a target operating state. The first transitionary state utilizes a first combination of equipment operating in the current operating state and results in first carbon dioxide emissions. A production facility control system may apply a second predictive controller to the current operating state to generate a second transitionary state between the current operating state and the target operating state. The second transitionary state utilizes a second combination of equipment different than the first combination of equipment and resulting in second carbon dioxide emissions. A production facility control system may select one of the first transitionary state or the second transitionary based on the first carbon dioxide emissions and the second carbon dioxide emissions.
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
17.
WELL INTEGRITY EVALUATION WITH EDDY CURRENT DIFFUSION TIME RESPONSE
Certain aspects of the present disclosure provide a system for eddy current logging in a well. The system includes one or more transmitter coils in the well configured to generate an excitation current. The system includes one or more receiver coils in the well configured to measure an eddy current response signal, the eddy current response signal comprising a voltage response. The system includes one or more processors configured to determine a frequency-domain transfer function based on a ratio of the voltage response to the excitation current; suppress mutual inductance from the frequency-domain transfer function; and generate a time-domain waveform based on the mutual inductance suppressed frequency-domain transfer function. The system may include a display configured to display information associated with the time-domain waveform.
G01V 3/28 - Prospection ou détection électrique ou magnétiqueMesure des caractéristiques du champ magnétique de la terre, p. ex. de la déclinaison ou de la déviation spécialement adaptée au carottage fonctionnant au moyen de champs magnétiques ou électriques produits ou modifiés par la formation terrestre environnante ou par les dispositifs de détection en utilisant des bobines d'induction
E21B 47/00 - Relevés dans les trous de forage ou dans les puits
G01V 3/38 - Traitement de données, p. ex. pour l'analyse, pour l'interprétation ou pour la correction
A method includes receiving seismic data of a subsurface. The method also includes color processing the seismic data to produce color-processed seismic data. The method also includes performing a seismic interpretation on the color-processed seismic data to identify regional geologic features. The method also includes performing first mapping along the regional geologic features to identify local geologic features. The method also includes extracting reservoir bodies from the local geologic features based upon the first mapping. The method also includes performing second mapping along the local geologic features to embed the local geological features into the regional geologic features. The method also includes delineating boundaries of reservoirs or seals in the subsurface based upon the local geologic features that are embedded into the regional geologic features. The method also includes de-risking a fluid prospect in a fluid reservoir based upon the boundaries of the reservoirs or the seals.
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 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 forage commandés par ordinateurSystèmes spécialement adaptés à la surveillance de plusieurs variables ou conditions de forage
19.
USER INTERFACE FOR PROVIDING GUIDANCE ON DRILLING OPERATIONS AND DYNAMIC REPORTING OF RELEVANT DATA
Methods, computing systems, and computer-readable media for dynamically presenting different types of data in an interface at different stages of a plan based on the monitoring the progression of the plan. The method includes receiving a selection of a goal for an operation, determining a plan based on the selected goal, determining different types of data to present at different stages of the plan, continuously receiving data representing one or more measurements taken during the operation, identifying a progression of the plan based on the continuously receiving the data, and dynamically presenting the different types of data in an interface at different stages of the plan based on the identifying the progression of the plan. The dynamically presenting the different types of data directs a user’s attention to the different types of data relevant at the different stages of the plan.
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 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 forage commandés par ordinateurSystèmes spécialement adaptés à la surveillance de plusieurs variables ou conditions de forage
G06Q 10/0631 - Planification, affectation, distribution ou ordonnancement de ressources d’entreprises ou d’organisations
G06F 3/0481 - Techniques d’interaction fondées sur les interfaces utilisateur graphiques [GUI] fondées sur des propriétés spécifiques de l’objet d’interaction affiché ou sur un environnement basé sur les métaphores, p. ex. interaction avec des éléments du bureau telles les fenêtres ou les icônes, ou avec l’aide d’un curseur changeant de comportement ou d’aspect
The present disclosure relates to systems and methods for automatically sending data collected at a well during flowback operations to a reservoir modelling platform. The systems and methods send the data to a reservoir modelling platform as the data is received from the well. The systems and methods automate the reporting of the data by displaying on a user interface the data received from the well.
G06F 30/28 - Optimisation, vérification ou simulation de l’objet conçu utilisant la dynamique des fluides, p. ex. les équations de Navier-Stokes ou la dynamique des fluides numérique [DFN]
E21B 41/00 - Matériel ou accessoires non couverts par les groupes
E21B 47/003 - Détermination des volumes du puits ou trou de forage
The present disclosure relates to systems and methods for identifying metrics of different features of an application operated by microservices of the application running on a cloud service provider. The systems and methods generate a data structure for the microservices using the telemetry data obtained from the application and the microservice metric obtained for the microservices. The systems and methods use the data structure to determine a metric of different features of the application.
A multiphase flowmeter (MPFM) liquid referencing vehicle having a portable multiphase flowmeter (MPFM). A multiphase flowmeter (MPFM) coupled to a pipeline may be calibrating using the portable multiphase flowmeter (MPFM) and without opening the upper flange coupled to the multiphase flowmeter (MPFM). The nuclear energy rate from the multiphase flowmeter (MPFM) may be measured and compared to a threshold decay margin. If the nuclear energy rate is below the threshold decay margin, the multiphase flowmeter (MPFM) liquid referencing vehicle may be used to calibrate the multiphase flowmeter (MPFM).
G01F 25/10 - Test ou étalonnage des appareils pour la mesure du volume, du débit volumétrique ou du niveau des liquides, ou des appareils pour compter par volume des débitmètres
23.
WELL INJECTIVITY PROFILING USING DISTRIBUTED TEMPERATURE SENSING TRANSIENT DATA
A system for determining an injectivity profile of an injection well penetrating a subsurface formation includes at least one distributed temperature sensing (DTS) cable deployed along at least a portion of the injection well to provide temperature measurements along the well depth over time, memory storing instructions, and at least one processor configured to execute the instructions to generate a temperature transient in the injection well, receive temperature measurements from the DTS cable, automatically simulate transient thermal and fluid flow behavior of the wellbore and subsurface formation using a model, automatically solve a supplementary inverse problem based on comparing simulated transient thermal behavior and received temperature measurements, estimate an inlet injection temperature at or above the top of a perforated interval, automatically solve a main inverse problem to fine tune model parameters, and estimate an injectivity profile along the perforated interval.
G01K 11/32 - Mesure de la température basée sur les variations physiques ou chimiques, n'entrant pas dans les groupes , , ou utilisant des changements dans la transmittance, la diffusion ou la luminescence dans les fibres optiques
G06F 30/20 - Optimisation, vérification ou simulation de l’objet conçu
E21B 43/12 - Procédés ou appareils pour commander l'écoulement du fluide extrait vers ou dans les puits
24.
Devices, systems, and methods for identifying a radial position of an expandable tool
An expandable tool may include a housing including an opening. An expandable tool may include an expandable block configured to extend through the opening, the expandable block including a first sensor element. An expandable tool may include a moving member located at a first end of the expandable block, the moving member including a second sensor element aligned with the first sensor element.
E21B 10/32 - Trépans avec une partie pilote, c.-à-d. trépans comportant un organe coupant piloteTrépans pour élargir le trou de forage, p. ex. alésoirs à organes coupants expansibles
E21B 47/092 - Localisation ou détermination de la position d'objets dans les trous de forage ou dans les puitsIdentification des parties libres ou bloquées des tubes par détection d'anomalies magnétiques
E21B 47/013 - Dispositifs spécialement adaptés pour supporter des instruments de mesure sur des trépans de forage
Embodiments presented provide for a method for determining a hydrocarbon American Petroleum density in real-time. Aspects provide for using a formation testing apparatus to pump reservoir fluid and, based on downhole optical spectroscopy measurement as well as hydrocarbon density measurement determine the Americal Petroleum density.
An artificial intelligence (AI) agent receives a natural language request from a user application to retrieve a seismic survey having a seismic profile matching a reference seismic profile of a geological model. A large language model (LLM) processes the natural language request to generate processing steps and identify corresponding tools to retrieve the seismic survey. The AI agent constructs an execution graph based on the processing steps. The execution graph includes instantiating nodes corresponding to the tools for the processing steps, and edges connecting the nodes. The AI agent executes the execution graph to obtain the seismic survey having the seismic profile matching the reference seismic profile.
A plugging tool includes a tool mandrel adapted to traverse an interior of a wellbore or well tubular. The mandrel has a seal section thereon, the seal section including longitudinally spaced apart extrusion barriers. The seal section includes a mechanism to urge the extrusion barriers toward each other. At least one elastomer sealing element is disposed between the extrusion barriers and arranged to radially expand when the extrusion barriers are urged toward each other.
Example multiphase fluid meters and related methods are disclosed herein. An example apparatus includes a fluid conduit coupled to tubing. A multiphase fluid is to flow from the tubing into the fluid conduit. The example apparatus includes a flow channel defined in the fluid conduit. The fluid is to flow through the flow channel. The flow channel has a cross-sectional shape different from a cross-sectional shape of the tubing. The example apparatus includes one or more sensors coupled to the flow channel to generate data indicative of a property of the multiphase fluid.
G01F 1/56 - 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 électriques ou magnétiques
G01F 1/74 - Dispositifs pour la mesure du débit d'un matériau fluide ou du débit d'un matériau solide fluent en suspension dans un autre fluide
G01F 15/02 - Compensation ou correction des variations de pression, de poids spécifique ou de température
G01F 15/063 - Dispositifs d'indication ou d'enregistrement pour l'indication à distance utilisant des moyens électriques
29.
CARBON-CARBON COMPOSITE SORBENT FORMULATIONS FOR CARBON DIOXIDE ADSORPTION, AND RELATED METHODS
A carbon-carbon composite sorbent form removing carbon dioxide from a gaseous material includes a base material including a porous carbon material including pores having an average diameter within a range of from about 2 nm to about 50 nm, and an adsorption material on surfaces of the base material and surfaces defining the pores, the adsorption material having a different material composition than the base material. The adsorption material has a higher nitrogen content than the base material and includes greater than about 2.0 atomic percent nitrogen exclusive of hydrogen in the adsorption material. Related methods of forming the carbon-carbon composite sorbents and additional carbon-carbon composite sorbents are disclosed.
B01J 20/20 - Compositions absorbantes ou adsorbantes solides ou compositions facilitant la filtrationAbsorbants ou adsorbants pour la chromatographieProcédés pour leur préparation, régénération ou réactivation contenant une substance inorganique contenant du carbone libreCompositions absorbantes ou adsorbantes solides ou compositions facilitant la filtrationAbsorbants ou adsorbants pour la chromatographieProcédés pour leur préparation, régénération ou réactivation contenant une substance inorganique contenant du carbone obtenu par des procédés de carbonisation
B01D 53/02 - Séparation de gaz ou de vapeursRécupération de vapeurs de solvants volatils dans les gazÉpuration chimique ou biologique des gaz résiduaires, p. ex. gaz d'échappement des moteurs à combustion, fumées, vapeurs, gaz de combustion ou aérosols par adsorption, p. ex. chromatographie préparatoire en phase gazeuse
B01J 20/28 - Compositions absorbantes ou adsorbantes solides ou compositions facilitant la filtrationAbsorbants ou adsorbants pour la chromatographieProcédés pour leur préparation, régénération ou réactivation caractérisées par leur forme ou leurs propriétés physiques
B01J 20/30 - Procédés de préparation, de régénération ou de réactivation
A method for hybridizing a physics-based simulator with a machine learning (ML) model includes receiving input data. The method may also include simulating variables based upon the input data. The method may also include predicting closures based upon the input data and the variables. The method may also include simulating outputs based upon the closures. The method may also include determining a loss function based upon the closures and/or the outputs. The method may also include determining gradients of the loss function. The method may also include updating a machine-learning (ML) model based upon the gradients to produce an updated ML model. The method may also include generating a hybrid output using the updated ML 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
G06F 30/28 - Optimisation, vérification ou simulation de l’objet conçu utilisant la dynamique des fluides, p. ex. les équations de Navier-Stokes ou la dynamique des fluides numérique [DFN]
31.
METHOD FOR SIMULTANEOUSLY COMBINING A PRODUCTION NETWORK AND AN INJECTION NETWORK WITHIN A SINGLE WORKFLOW
A method for optimizing an integrated network related to a wellsite. The method includes inputting data related to an integrated network of a wellsite, simultaneously simulating a flow within a first and second plurality of flowlines within the integrated network based on the input data, and determining a first output for the well based on the simultaneously simulated flows within the first and second plurality of flowlines. The input data related to the integrated network may be revised so that a flow within the first and second plurality of flowlines may be simultaneously re-simulated within the integrated network based on the revised input data. A further output for the well may be then determined and displayed on a screen.
A method for hybridizing a physics-based simulator with a machine learning (ML) model includes receiving input data. The method also includes simulating variables based upon the input data. The method also includes predicting closures based upon the input data and the variables. The method also includes simulating outputs based upon the closures. The method may also include determining a loss function based upon the closures and/or the outputs. The method may also include determining gradients of the loss function. The method may also include updating a machine-learning (ML) model based upon the gradients to produce an updated ML model. The method also includes generating a hybrid output using the updated ML 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
G06F 30/28 - Optimisation, vérification ou simulation de l’objet conçu utilisant la dynamique des fluides, p. ex. les équations de Navier-Stokes ou la dynamique des fluides numérique [DFN]
A valve assembly includes a pipe defining a passageway, a flapper disposed within the pipe and pivotable between an open position and a closed position, wherein in the closed position the flapper extends across the passageway to block flow therethrough, and a sleeve disposed within the passageway and positioned to prevent the flapper from pivoting to the closed position, wherein the sleeve is formed from a dissolvable material. The sleeve defines a seat configured to receive a ball formed from a dissolvable material. The ball lands on the seat and blocks flow through the passageway such that pressure applied above the ball displaces the sleeve from a position that prevents the flapper from pivoting to the closed position. The sleeve includes an anchor configured to hold the sleeve in position within the passageway during run-in-hole operations.
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 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 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 system for real-time monitoring of fluid flow rate in a wellbore penetrating a subsurface formation includes at least one distributed temperature sensing (DTS) system deployed along at least a portion of the wellbore and configured to provide real-time temperature measurements along a depth of the wellbore, at least one additional sensor at a surface configured to measure well head pressure or temperature, memory storing instructions, and at least one processor. The processor is configured to automatically receive the real-time temperature measurements and well head pressure or temperature measurements, automatically simulate transient thermal and fluid flow behavior using a model, automatically solve an inverse problem to fine tune model parameters by iteratively determining residuals and adjusting parameters to minimize differences, and automatically determine a real-time fluid flow rate profile based on the fine-tuned model.
G01V 1/42 - SéismologieProspection ou détection sismique ou acoustique spécialement adaptées au carottage en utilisant des générateurs dans un puits et des récepteurs dans un autre endroit ou vice versa
E21B 47/113 - Localisation des fuites, intrusions ou mouvements du fluide utilisant des signaux électriquesLocalisation des fuites, intrusions ou mouvements du fluide utilisant un rayonnement lumineux
G01D 5/26 - Moyens mécaniques pour le transfert de la grandeur de sortie d'un organe sensibleMoyens 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 déterminéTransducteurs non spécialement adaptés à une variable particulière utilisant des moyens optiques, c.-à-d. utilisant de la lumière infrarouge, visible ou ultraviolette
G01V 1/20 - Aménagements d'éléments récepteurs, p. ex. oscillogrammes géophoniques
G01K 11/32 - Mesure de la température basée sur les variations physiques ou chimiques, n'entrant pas dans les groupes , , ou utilisant des changements dans la transmittance, la diffusion ou la luminescence dans les fibres optiques
G01V 1/22 - Transmission des signaux sismiques aux appareils d'enregistrement ou de traitement
G01V 8/16 - Détection, p. ex. en utilisant des barrières de lumière en utilisant un émetteur et un récepteur en utilisant des fibres optiques
35.
SUMMARIZING DOCUMENTS WITH LANGUAGE MODELS USING PAGE AND CONTENT RANKING
A method implements summarizing documents with language models using page and content ranking. The method involves processing a document and a query to generate one or more of a set of index pages and a query embedding. The method further involves executing selection instructions to generate a set of selected pages from the document. The set of selected pages includes the one or more of a set of index selected pages and a set of query selected pages. The set of index selected pages is selected using the set of index pages. The set of query selected pages is selected using the query embedding. The method further involves executing summarization instructions to generate a query-based summary using the set of selected pages and content ranking.
G06F 16/383 - Recherche caractérisée par l’utilisation de métadonnées, p. ex. de métadonnées ne provenant pas du contenu ou de métadonnées générées manuellement utilisant des métadonnées provenant automatiquement du contenu
36.
SEAL ASSEMBLIES FOR ROTARY CONTROL DEVICES (RCD) OF DRILLING SYSTEMS AND RELATED METHODS
An embodiment of a rotating control device (RCD) for a drilling system includes a housing and a drive ring positioned within the housing and configured to rotate relative to the housing. The drive ring includes a throughbore that is configured to receive a drill string therethrough. In addition, the RCD includes a seal assembly positioned between the drive ring and the housing. The seal assembly includes a rotary seal that is sealingly engaged with a radially outer surface of the drive ring. In addition, the seal assembly includes a piston that is coupled to the rotary seal so that a first pressure acting on a first side of the rotary seal is configured to move the piston to apply a second pressure to a second side of the rotary seal. The second pressure is different from the first pressure.
Methods and systems are provided for automated closed-loop control of drilling trajectory during directional drilling to a geological target, which employ a surface-located predictive controller that interfaces to and cooperates with a downhole trajectory control system to automatically control the drilling direction of a drilling tool during the directional drilling. The predictive controller is configured to receive data representing a new reference trajectory for a given measured depth and generate output data representing a sequence of set-points for the new reference trajectory. The predictive controller is further configured to communicate the output data to the downhole trajectory control system to automatically control the drilling direction of the drilling tool to follow the new reference trajectory.
E21B 44/00 - 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 forage commandés par ordinateurSystèmes spécialement adaptés à la surveillance de plusieurs variables ou conditions de forage
E21B 7/06 - Modification de la direction du trou de forage
E21B 47/022 - Détermination de l'inclinaison ou de la direction du trou de forage, p. ex. à l'aide de géomagnétisme
38.
DEVICES, SYSTEMS, AND METHODS FOR HIGH FREQUENCY OSCILLATION MITIGATION
High frequency oscillation (HFO) comes in at least two types. Type 1 HFO is lower frequency and often associated with a motor. Type 2 HFO is higher frequency and often independent of a motor. To mitigate torsional strain due to Type 2 HFO, an HFO mitigation mechanism can be placed based on an oscillation node location to move the oscillation node to a new position which may be uphole of a tool or the BHA, or to a less vulnerable location. Mitigation can also include placing an energy damping component based on the oscillation node. This may be at a high displacement location distanced from the oscillation node or may include placement at the oscillation node with an additional HFO mitigation mechanism to move the oscillation node away from the installation location. Oscillations may be damped by using any combination of flow restrictions, fluid bypasses, or axially compliant elements.
A method includes receiving a well log having a signal. The method also includes identifying in the signal a first change point that demarcates a first signal region and a second signal region. The method also includes determining that the first signal region is inconsistent in comparison to the second signal region. The method also includes producing a modified well log by removing the first signal region from the signal in response to determining that the first signal region is inconsistent in comparison to the second signal region.
E21B 49/00 - Test pour déterminer la nature des parois des trous de forageEssais de couchesProcédés ou appareils pour prélever des échantillons du terrain ou de fluides en provenance des puits, spécialement adaptés au forage du sol ou aux puits
40.
PRESSURE RESPONSE TEST TO DETECT LEAKAGE OF ROTATING CONTROL DEVICE
A method includes initiating a managed pressure drilling (MPD) operation in an MPD system including a rotating control device (RCD) including at least one sealing element and a plurality of pressures sensors placed relative to the at least one sealing element. The RCD is positioned in the MPD system so as to receive fluid exiting an annulus of a wellbore. Further, the method includes creating a pressure spike in the annulus of the wellbore during the MPD operation, and monitoring a pressure differential between the plurality of pressure sensors to determine whether there is a leakage within the RCD. The MPD system further includes a choke manifold connected the RCD via a primary line and a fluid source connected to a backpressure line, which is a dedicated test line that is directly and fluidly connected to the RCD.
A bottom hole assembly (BHA) configured for drilling a subterranean wellbore, the BHA including a drill bit for drilling the wellbore; a rotary steerable tool for controlling direction of drilling by the drill bit; and a sleeve operably coupled between the rotary steerable tool and the drill bit, wherein the sleeve is configured to increase a moment of inertia of the BHA by at least 20%.
E21B 7/06 - Modification de la direction du trou de forage
E21B 10/567 - Parties rapportées du type bouton comportant des éléments de coupe préformés montés sur un support distinct, p. ex. parties rapportées polycristallines
A method of forming a mesoporous carbon sorbent for removal of carbon dioxide from a gaseous material includes mixing, polymerizing, and pyrolyzing materials. The method includes mixing a nitrogen-containing material with a hydroxylated benzene and an aldehyde in a solvent. The method includes polymerizing the hydroxylated benzene and the aldehyde to form a porous polymer including the nitrogen-containing material. The method includes pyrolyzing the porous polymer to for a mesoporous carbon sorbent having an average pore width greater than about 3 nm.
B01J 20/20 - Compositions absorbantes ou adsorbantes solides ou compositions facilitant la filtrationAbsorbants ou adsorbants pour la chromatographieProcédés pour leur préparation, régénération ou réactivation contenant une substance inorganique contenant du carbone libreCompositions absorbantes ou adsorbantes solides ou compositions facilitant la filtrationAbsorbants ou adsorbants pour la chromatographieProcédés pour leur préparation, régénération ou réactivation contenant une substance inorganique contenant du carbone obtenu par des procédés de carbonisation
B01D 53/04 - Séparation de gaz ou de vapeursRécupération de vapeurs de solvants volatils dans les gazÉpuration chimique ou biologique des gaz résiduaires, p. ex. gaz d'échappement des moteurs à combustion, fumées, vapeurs, gaz de combustion ou aérosols par adsorption, p. ex. chromatographie préparatoire en phase gazeuse avec adsorbants fixes
B01J 20/28 - Compositions absorbantes ou adsorbantes solides ou compositions facilitant la filtrationAbsorbants ou adsorbants pour la chromatographieProcédés pour leur préparation, régénération ou réactivation caractérisées par leur forme ou leurs propriétés physiques
B01J 20/30 - Procédés de préparation, de régénération ou de réactivation
43.
MULTIMODAL PROCESSING OF PULSED EDDY CURRENT RESPONSE SIGNAL FOR WELL INTEGRITY EVALUATION
Certain aspects of the present disclosure provide a system for eddy current testing in a well. The system includes one or more transmitter coils in the well configured to generate an excitation current and one or more receiver coils in the well configured to measure an eddy current response signal from a plurality of pipes in the well. The system includes one or more processors configured to generate a time-domain waveform; determine a plurality of waveform lobes of the time-domain waveform, wherein each of the plurality of waveform lobes is associated with at least one of the plurality of pipes and with a different time interval of the time-domain waveform; and estimate one or more parameters of at least one pipe of the plurality of pipes based on one or more waveform lobes, of the plurality of waveform lobes, associated with the at least one pipe.
G01N 27/90 - Recherche ou analyse des matériaux par l'emploi de moyens électriques, électrochimiques ou magnétiques en recherchant des variables magnétiques pour rechercher la présence des criques en utilisant les courants de Foucault
E21B 47/00 - Relevés dans les trous de forage ou dans les puits
E21B 47/007 - Mesure des contraintes dans le cuvelage ou la tige de forage
E21B 47/08 - Mesure du diamètre ou des dimensions correspondantes des trous de forage
G01B 7/06 - Dispositions pour la mesure caractérisées par l'utilisation de techniques électriques ou magnétiques pour mesurer la longueur, la largeur ou l'épaisseur pour mesurer l'épaisseur
Embodiments of the disclosure provide for methods and apparatus related to downhole fluid testing. Aspects disclose methods and apparatus related to high-flow downhole fluid testing with downhole fluid analyzers. These methods and apparatus enable precise and efficient fluid characterization in extreme subsurface conditions. By having the ability to reverse flows within the testing apparatus, the disclosed embodiments ensure accurate real-time analysis of fluid properties, enhancing decision making in drilling operations and reservoir management.
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
F04B 9/113 - "Machines" ou pompes à piston caractérisées par les moyens entraînants ou entraînés liés à leurs organes de travail les moyens étant à fluide le fluide étant liquide avec plusieurs chambres de pompage avec deux organes de pompage liés mécaniquement le mouvement alternatif des organes de pompage étant obtenu par un moteur hydraulique à double effet
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 43/12 - Procédés ou appareils pour commander l'écoulement du fluide extrait vers ou dans les puits
F04B 49/00 - Commande des "machines", pompes ou installations de pompage ou mesures de sécurité les concernant non prévues dans les groupes ou présentant un intérêt autre que celui visé par ces groupes
A method for training a machine-learning (ML) model processing seismic data may include obtaining input data including a target dataset and user-defined inputs. The target dataset may include the seismic data. The method may also include generating a synthetic dataset including synthetic seismic data based on the seismic data of the target datasets. The method may further include generating a ground-truth dataset based on the synthetic dataset and the user-defined inputs. The method may also include generating one or more training pairs based on the ground-truth dataset and the synthetic dataset. The method may also include training the machine-learning (ML) model based on the one or more training pairs to generate a trained ML model.
An electrochemical system produces a gas from an aqueous solution. A liquid is circulated from a half-cell to a reaction vessel and then returned to the half-cell. A redox mediator in the liquid is converted from a first state to a second state in the half-cell and reacts to form a gas in the reaction chamber while being returned to its first state. The circulating liquid also includes a high molecular weight linear polymer or a viscoelastic surfactant which forms wormlike micelles enabling it to be in a state of elastic turbulence and the reaction chamber is configured to compel changes of flow direction so that the liquid is in a state of elastic turbulence as it flows through the reaction chamber. The half-cell may be configured such that the liquid is in a state of elastic turbulence as it flows through the half-cell.
A method may include receiving transverse relaxation time (T2) distribution data associated with a geological formation, the T2 distribution data being acquired by a nuclear magnetic resonance (NMR) tool. The method may also involve decomposing the T2 distribution data into Gaussian distributions using inversion techniques, computing reconstructed acoustic values associated with the geological formation based on a first Gaussian distribution and a first pore type, receiving measured acoustic values associated with the geological formation, determining that the first pore type corresponds to the first Gaussian distribution based on the one or more reconstructed acoustic values and the one or more measured acoustic values, and in response to determining that the first pore type corresponds to the first Gaussian distribution, determining a pore size distribution (PSD) for the first Gaussian distribution based on an aspect ratio associated with the first pore type.
G01N 24/08 - Recherche ou analyse des matériaux par l'utilisation de la résonance magnétique nucléaire, de la résonance paramagnétique électronique ou d'autres effets de spin en utilisant la résonance magnétique nucléaire
G01R 33/50 - Systèmes d'imagerie RMN basés sur la détermination des temps de relaxation
G01V 3/32 - Prospection ou détection électrique ou magnétiqueMesure des caractéristiques du champ magnétique de la terre, p. ex. de la déclinaison ou de la déviation spécialement adaptée au carottage fonctionnant par résonance magnétique électronique ou nucléaire
G01V 3/38 - Traitement de données, p. ex. pour l'analyse, pour l'interprétation ou pour la correction
48.
DYNAMIC MULTI-FLOWLINE CONTROL SYSTEM FOR DOWNHOLE TOOLS
Embodiments presented provide for a multi-flowline control system and methods for dynamically switching fluid flow in downhole tools. The method may include operating the downhole tool in a first valve configuration, the downhole tool configured to sample fluid from a geological stratum, sending an actuation signal to the first valve configuration, receiving the actuation signal at the first valve configuration, altering the first valve configuration to a second valve configuration, where the first valve configuration allows for sampling of fluids from the geological stratum outside the downhole tool to the second valve configuration and where the downhole tool is configured to operate in a closed-loop configuration wherein sampling of fluids from the geological stratum is not possible, and circulating fluids within the closed loop configuration.
A computer-implemented method for seismic processing includes receiving a seismic training input image, generating, using a first portion of a machine learning model, a first output based at least in part on the seismic training input image, generating, using a second portion of the machine learning model, a second output based at least in part on the seismic training input image, generating a loss function based at least in part on comparing at least two of the first output, a deterministic first label synthetically generated and representing a deterministic ground truth for the first output, the second output, and a non-deterministic second label representing a non-deterministic ground truth for the second output, and refining the first portion, the second portion, or both of the machine learning model based at least in part on the loss function.
A validation engine may receive first drilling equipment properties for a first plurality of drilling equipment used in a section of a wellbore. A validation engine may, based on the first drilling equipment properties, identifying first wellbore properties for the section of the wellbore. A validation engine may receive second drilling equipment properties for a second plurality of drilling equipment used in the section of the wellbore. A validation engine may validate that the second plurality of drilling equipment is usable in the section of the wellbore based at least in part on a comparison between the second drilling equipment properties and the first wellbore properties.
Systems and methods presented herein generally relate to introducing degradable fibers into a clean fluid having no proppants contained therein to produce a fiber-containing fluid, and injecting the fiber-containing fluid into a wellbore extending through a subterranean formation during a pad stage of a hydraulic fracturing operation. In general, the systems and methods presented herein block fluid leak-off flow through walls of fractures created during hydraulic fracturing operations. Advantages include the ability to definitively minimize fluid damage to the reservoir because less fluid is used and there is less water consumption.
E21B 43/26 - Procédés pour activer la production par formation de crevasses ou de fractures
C09K 8/70 - Compositions pour la formation de crevasses ou de fractures caractérisées par leur forme ou par la forme de leurs composants, p. ex. mousses
C09K 8/80 - Compositions pour renforcer les fractures, p. ex. compositions pour agents de soutènement utilisés pour maintenir les fractures ouvertes
E21B 33/138 - Plâtrage de la paroi du trou de forageInjections dans la formation
E21B 49/00 - Test pour déterminer la nature des parois des trous de forageEssais de couchesProcédés ou appareils pour prélever des échantillons du terrain ou de fluides en provenance des puits, spécialement adaptés au forage du sol ou aux puits
Systems and methods for monitoring and control in downhole well applications are provided. The system and methodology may be combined with a variety of completions or other types of well equipment deployed downhole to enable electrical, fiber optic, hydraulic, and/or control lines communication with downhole components. For example, the completion may be in the form of a two-stage completion having a lower completion and an upper completion which enable the desired communication when joined.
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
53.
SYSTEMS AND METHODS FOR EVALUATING MULTIPHASE MIXTURES
A method of determining salinity includes isolating a reference water phase from a multiphase mixture to identify a reference salinity value, and generating a reference oil-water line for the reference salinity value with a multiphase oil-water salinity model that relates conductivity and permittivity for multiphase oil-water mixtures. With a microwave sensor, the multiphase mixture is sampled to determine a plurality of sample mixture conductivity values and sample mixture permittivity values. A sample sand-water line for the multiphase mixture is generated from the plurality of sample mixture conductivity and permittivity values. The multiphase sand-water salinity model is generated from the multiphase oil-water salinity model and a sand permittivity offset of the sample sand-water line. With the microwave sensor, an active mixture permittivity value and an active mixture conductivity value of the multiphase mixture is measured to determine an active salinity value with the multiphase sand-water salinity model.
G01N 27/12 - Recherche ou analyse des matériaux par l'emploi de moyens électriques, électrochimiques ou magnétiques en recherchant l'impédance en recherchant la résistance d'un corps solide dépendant de l'absorption d'un fluideRecherche ou analyse des matériaux par l'emploi de moyens électriques, électrochimiques ou magnétiques en recherchant l'impédance en recherchant la résistance d'un corps solide dépendant de la réaction avec un fluide
G01N 27/22 - Recherche ou analyse des matériaux par l'emploi de moyens électriques, électrochimiques ou magnétiques en recherchant l'impédance en recherchant la capacité
A gas separator includes a drive shaft, an inducer, an impeller, and a paddle wheel. The inducer is mounted along the drive shaft. The inducer has a first hub portion. The impeller is mounted along the drive shaft. The impeller has a second hub portion. The paddle wheel is mounted along the drive shaft. The paddle wheel has a third hub portion. The impeller is positioned between the inducer and the paddle wheel. The second hub portion has an outer diameter at a leading edge of an impeller vane that is greater than an outer diameter of the first hub portion at a leading edge of an inducer vane, and greater than an outer diameter of the third hub portion at a leading edge of a paddle vane.
A downhole tool for a drillstring that includes a mud motor and a drill bit can include sensor circuitry that acquires data characteristic of operation of the mud motor, wherein the mud motor is disposed on the drillstring between the downhole tool and the drill bit; and a telemetry interface for transmission of one or more of the data and data derived metrics.
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 forage commandés par ordinateurSystèmes spécialement adaptés à la surveillance de plusieurs variables ou conditions de forage
E21B 47/008 - Surveillance des systèmes de pompe de fond de trou, p. ex. pour la détection de conditions appelées "cognement sur le fluide"
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
56.
S-DAS BASED CCUS MONITORING SYSTEM USING AMBIENT NOISE INTERFEROMETRY
A method for monitoring subsurface changes in a subsurface domain is disclosed. The method may include receiving ambient noise occurring in a subsurface domain, generating a plurality of time-space virtual shots by processing the ambient noise, modeling subsurface changes based on at least a portion of the plurality of time-space virtual shots, transforming the plurality of time-space virtual shots to a space-time representation, determining at least one difference between the transformed time-space virtual shots, and detecting the subsurface changes based on the at least one difference.
G01V 1/22 - Transmission des signaux sismiques aux appareils d'enregistrement ou de traitement
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
57.
AUTO-GENERATED KINEMATICALLY EQUIVALENT RAY-TRACEABLE MODELS FOR SEISMIC MODELING
A first velocity model having a three-dimensional (3D) grid of voxels containing velocity values is processed with an eikonal solver to generate a reference travel-time model as a second 3D grid of voxels containing respective reference travel-time values. A candidate background model is initialized based on the first velocity model. A candidate travel-time model is generated from the candidate background model. The candidate travel-time model has a third 3D grid of voxels containing respective candidate travel-time values. The candidate background model is updated to minimize a measure of difference between respective candidate travel-time values of the candidate travel-time model and respective reference travel-time values of the reference travel-time model. The updated candidate model serves as a second velocity model of the subsurface region that is kinematically equivalent to the first velocity model.
A first velocity model of a subsurface region, having first velocity values, and having a first spatial resolution is used to generate a reference travel-time model of reference travel-time values. A second velocity model of the subsurface region, having second velocity values is received. The second velocity model has a second spatial resolution that is higher than the first spatial resolution. The second velocity model is corrected with a corrected term, and the corrected model is processed to generate a candidate travel-time model of candidate travel-time values. The correction term is updated to minimize a measure of difference between the reference travel-time values and the candidate travel-time values, to obtain an updated correction term. The updated correction term is added to the second velocity model to obtain an updated second velocity model of the subsurface region.
Systems and methods for direct arrival estimation for marine seismic data are provided. A computer-implemented method for estimating direct-arrival energy in seismic data acquired in a marine environment, the method including: executing, by one or more processors, operations on seismic data that contain up-going and down-going wavefields in which direct-arrival information is not properly or completely recorded, processing the seismic data using a computer-based wavefield-analysis technique to identify water-layer reverberation events within the up-going and down-going wavefields, leveraging, through computer-implemented analysis, stable relationships among water-layer reverberations, computing, by the processors, an estimated direct-arrival signal based on the identified relationships to compensate for missing or improperly recorded direct-arrival information, and producing, using the processors, a direct-arrival estimate configured for use in subsequent seismic-processing operations.
In a redox mediated battery system having a half-cell connected to a vessel containing an insoluble solid substance which is present as a bed of granules or other porous mass and which is converted between first and second states during charge and discharge, the electrolyte liquid includes a solute capable of causing elastic turbulence in the liquid, while the flow paths for electrolyte liquid through the porous mass of insoluble solid substance are configured to compel changes in direction of flow thereby inducing elastic turbulence in contact with the insoluble solid substance. Elastic turbulence may also be induced in the half-cell.
H01M 8/18 - Éléments à combustible à régénération, p. ex. batteries à flux REDOX ou éléments à combustible secondaires
H01M 8/0258 - CollecteursSéparateurs, p. ex. séparateurs bipolairesInterconnecteurs caractérisés par la configuration des canaux, p. ex. par le champ d’écoulement du réactif ou du réfrigérant
H01M 8/04082 - Dispositions pour la commande des paramètres des réactifs, p. ex. de la pression ou de la concentration
H01M 8/08 - Éléments à combustible avec électrolytes aqueux
In an electrochemical system, a liquid is circulated from a half-cell to a reaction vessel and then returned to the half-cell. A redox mediator in the liquid is converted from a first state to a second state in the half-cell and reacts with a gas in the reaction chamber while being returned to its first state. The circulating liquid also contains a high molecular weight linear polymer or a viscoelastic surfactant which forms wormlike micelles enabling it to be in a state of elastic turbulence and the reaction chamber is configured to compel changes of flow direction so that the liquid is in a state of elastic turbulence as it flows through the reaction chamber.
A method of analyzing flowback of a downhole system includes generating active flowback data by monitoring an active flowback from a wellbore. Historic flowback data for historic flowback from the wellbore is used to determine a flowback cluster. The flowback cluster is selected based on comparing the active flowback data to the historic flowback data and determining one or more data instances of the historic flowback data that have features that are similar to that of the active flowback data. Based on the flowback cluster, one or more thresholds may be determined in order to generate an alert when the active flowback data exceeds the thresholds.
A technique facilitates long-term operation of a submersible pump which may be used in an electric submersible pumping system. According to an embodiment, the submersible pump comprises at least one stage, e.g. a plurality of stages. Each stage uses an impeller which may be rotated within a diffuser to establish a fluid flow through the pump. Additionally, each stage comprises an erosion control system positioned between the impeller and the diffuser to reduce erosion and/or the effects of erosion so as to extend the life of the submersible pump.
F04D 13/08 - Ensembles comprenant les pompes et leurs moyens d'entraînement la pompe étant entraînée par l'électricité pour utilisation en position immergée
F04D 13/10 - Ensembles comprenant les pompes et leurs moyens d'entraînement la pompe étant entraînée par l'électricité pour utilisation en position immergée adaptés pour l'utilisation dans les forages de mine
Systems and methods presented herein facilitate automation of coiled tubing drilling (CTD) operations. For example, a computer-implemented method includes performing a drilling operation via a CTD system; detecting data relating to one or more operating parameters of the drilling operation via one or more sensors of the CTD system during the drilling operation; and automatically adjusting at least one adjustable operating parameter of the drilling operation based on the detected data during the drilling 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 forage commandés par ordinateurSystèmes spécialement adaptés à la surveillance de plusieurs variables ou conditions de forage
E21B 7/06 - Modification de la direction du trou de forage
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 19/22 - Manipulation de tubes ou de tiges enroulés, p. ex. de tubes de forage flexibles
65.
METHODS FOR REAL-TIME OPTIMIZATION OF COILED TUBING CLEANOUT OPERATIONS USING DOWNHOLE PRESSURE SENSORS
Systems and methods presented herein facilitate coiled tubing cleanout operations, and generally relate to estimating reservoir pressure prior to the coiled tubing cleanout operations (e.g., while the wellbore is shut-in). For example, a method includes acquiring, via one or more downhole sensors of a coiled tubing system at least partially disposed within a wellbore, downhole data of the coiled tubing system; identifying, via a processing and control system, a density profile of fluids disposed within the wellbore based at least in part on the acquired downhole data; interpreting, via the processing and control system, the density profile of the fluids disposed within the wellbore; and estimating, via the processing and control system, a reservoir pressure of a reservoir through which the wellbore extends based at least in part on the interpreted density profile of the fluids disposed within the wellbore.
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 7/00 - Procédés ou matériels particuliers pour le forage
E21B 19/22 - Manipulation de tubes ou de tiges enroulés, p. ex. de tubes de forage flexibles
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 forage commandés par ordinateurSystèmes spécialement adaptés à la surveillance de plusieurs variables ou conditions de forage
E21B 47/00 - Relevés dans les trous de forage ou dans les puits
E21B 47/06 - Mesure de la température ou de la pression
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
66.
ALIGNMENT SYSTEM AND METHODOLOGY UTILIZING ROTATING CONTROL DEVICE
A technique facilitates drilling of a borehole by simplifying alignment between a running tool and a seal rotating system. According to an embodiment, the running tool is connected into a drill string. The drill string is then used to move the running tool linearly within the seal rotating system until engagement of an alignment mechanism occurs. With continued linear movement, the alignment mechanism automatically causes relative rotation between the running tool and the seal rotating system until a desired alignment position is achieved. The seal rotating system may then be secured to the running tool via threaded fasteners or other suitable fastening mechanism.
A high density carrier fluid for use in placing a gravel pack within a wellbore includes a modified starch, a magnesium oxide, and a nano-crystalline-cellulose having a median diameter of about 20 nanometers or less. The carrier fluid includes an aqueous base fluid and dissolved salts. Related methods include methods of making and using the carrier fluids.
A method including receiving a three-dimensional scan of a coating that coats an object. The coating and the object, in combination, have a shape. The method also includes flattening the three-dimensional scan to generate flattened data. Flattening includes conforming scan data in the three-dimensional scan to zone data for zones of a layout. The zones represents sections of the shape cut along boundaries in the shape. Each of the zones represents a corresponding thickness of the coating in a corresponding section of the sections. The method also includes vectorizing the flattened data into a vector data structure. The method also includes generating a prediction whether one or more zones of the zones are out of an engineering tolerance for the coating. Generating the prediction is performed by a machine learning model that takes, as input, the vector data structure and produces, as output, the prediction.
G06T 19/00 - Transformation de modèles ou d'images tridimensionnels [3D] pour infographie
E21B 10/42 - Trépans rotatifs du type racleur comportant des dents, des lames ou des organes de coupe similaires, p. ex. du type à fourche, en queue de poisson
69.
SYSTEMS AND METHODS FOR CONTROLLING A DOWNHOLE TOOL IN A DOWNHOLE ENVIRONMENT
A method may include drilling a portion of a borehole with a bottomhole assembly (BHA) including the downhole tool in an automated drilling routine. A method may include receiving, at a control unit of the BHA, a disengagement downlink communication having a disengagement magnitude and disengagement duration. A method may include, based at least partially on the disengagement downlink communication, disengaging the automated drilling routine.
E21B 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 forage commandés par ordinateurSystèmes spécialement adaptés à la surveillance de plusieurs variables ou conditions de forage
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
70.
INTEGRATED MULTI MODAL EMISSION MEASUREMENTS LIFECYCLE
The disclosed methods and systems are directed to mitigating against one or more emissions events at a facility. The method comprises receiving first emissions data associated with the facility and formatting same based on a predefined data structure or a source type associated with the plurality of emissions sources of the facility. The method further comprises tracking using one or more sensors a plurality of emissions records generated using the emissions data. The data from the tracked emissions records may be used to generate an emissions inventory that may be used to generate one or more models which are used in one or more simulations to generate second emissions data. The second emissions data may enable tracking of one or more emissions sources associated with the facility. The second emissions data may enable execution of control operations that mitigate against one or more emissions sources associated with the facility.
G01M 3/04 - Examen de l'étanchéité des structures ou ouvrages vis-à-vis d'un fluide par utilisation d'un fluide ou en faisant le vide par détection de la présence du fluide à l'emplacement de la fuite
G06Q 30/018 - Certification d’entreprises ou de produits
71.
OPTIMIZING PIPELINE CAPACITY AND EMISSIONS THROUGH DRAG-REDUCING AGENT AND PUMP POWER MANAGEMENT
A method for modifying a capacity of a pipeline while reducing emissions includes receiving input data related to a pump that is configured to cause a fluid to move through a pipeline. The method also includes determining an operating point of the pump. The method also includes generating a system curve based upon the input data and the operating point. The method also includes generating a drag reduction efficiency curve based upon the input data. The method also includes updating the system curve based upon the drag reduction efficiency curve to produce an updated system curve. The method also includes updating the operating point based upon the input data and the updated system curve to produce an updated operating point.
The invention relates to a heat exchanger (100) for heat exchange between several fluids; - the heat exchanger (100) being manufactured by 3D printing; - the heat exchanger (100) comprising several groups of channels (102-120), each channel, through which one of the fluids passes, connecting an inlet for the fluid into the exchanger (100) to an outlet for the fluid out of the exchanger (100); - the groups of channels (102-120) being arranged such that one channel of one group (102-120) through which one fluid passes faces another channel of another group (102-120) through which another fluid passes in order to carry out a heat exchange between the fluids. It also relates to an electrochemical system comprising such a heat exchanger.
A method for modifying a capacity of a pipeline while reducing emissions includes receiving input data related to a pump that is configured to cause a fluid to move through a pipeline. The method also includes determining an operating point of the pump. The method also includes generating a system curve based upon the input data and the operating point. The method also includes generating a drag reduction efficiency curve based upon the input data. The method also includes updating the system curve based upon the drag reduction efficiency curve to produce an updated system curve. The method also includes updating the operating point based upon the input data and the updated system curve to produce an updated operating point.
A method can include receiving torque measurements with respect to time associated with a drillstring in a borehole; receiving rotational speed measurements with respect to time associated with a top drive operatively coupled to the drillstring in the borehole, where the top drive is operatively coupled to a stick-slip mitigation controller; performing an assessment of stick-slip mitigation performance of the stick-slip mitigation controller using the torque measurements and the rotational speed measurements; and adjusting operation of the stick-slip mitigation controller based at least in part on the assessment.
An in-situ extraction system may include a sorbent bed housing located in a flow path for a brine containing a target ion. An in-situ extraction system may include a sorbent located in the sorbent bed housing, the sorbent selected to selectively extract the target ion. An in-situ extraction system may include a target ion collection system configured to collect a concentrated stream of the target ion.
E21B 43/38 - Aménagements pour séparer les matériaux produits par le puits dans le puits
E21B 43/00 - Procédés ou dispositifs pour l'extraction de pétrole, de gaz, d'eau ou de matériaux solubles ou fusibles ou d'une suspension de matières minérales à partir de puits
A method for estimating depth of a survey tool during a wellbore survey, the method comprising dropping the survey tool inside a drill pipe placed in a wellbore, generating, by an accelerometer included in the survey tool, a measurement signal as the survey tool moves through the drill pipe, identifying a first group of spikes appearing in the measurement signal, identifying a second group of spikes appearing in the measurement signal, and determining a depth of the survey tool at a first time during movement of the survey tool through the drill pipe based in part on the first group of spikes, the second group of spikes, and a dimension of the drill pipe.
E21B 47/09 - Localisation ou détermination de la position d'objets dans les trous de forage ou dans les puitsIdentification des parties libres ou bloquées des tubes
E21B 17/10 - Protecteurs contre l'usureDispositifs de centrage
E21B 47/022 - Détermination de l'inclinaison ou de la direction du trou de forage, p. ex. à l'aide de géomagnétisme
E21B 47/04 - Mesure de la profondeur ou du niveau du liquide
77.
Extracting data from lab reports using generative artificial intelligence
A lab report data extraction system may identify a plurality of lab reports from a lab report repository, each of the plurality of lab reports including a plurality of data fields. A lab report data extraction system may identify a plurality of output data fields. A lab report data extraction system may generate a prompt for a generative artificial intelligence (AI) model, the prompt including a request for the generative AI model to identify the output data fields from the plurality of data fields. A lab report data extraction system may input the prompt to the generative AI model, the generative AI model preparing an output including data from the plurality of data fields output to the plurality of output data fields in a formatted database.
Methods and systems for drilling a wellbore that traverses a subterranean formation employ a computational model that relates input data representing at least one drilling performance parameter (or change therein) at one or more drilling conditions to output data representing at least one petrophysical formation property. Data representing at least one drilling performance parameter (or change therein) at one or more drilling conditions while drilling is determined by sweeping wellbore pressure over a range of pressures and measuring and analyzing wellbore pressures and associated drilling performance parameters, and such data is used as input data to the computational model, which generates output data representing at least one petrophysical formation property associated with the input data. The data output by the model can be added to well log of formation properties, which can be used to set or adjust the direction of drilling.
E21B 49/00 - Test pour déterminer la nature des parois des trous de forageEssais de couchesProcédés ou appareils pour prélever des échantillons du terrain ou de fluides en provenance des puits, spécialement adaptés au forage du sol ou aux puits
79.
SWELL PACKER WITH AXIALLY ACTIVATED DUAL EXTRUSION SUPPORT
A wellbore seal includes a support ring, an expandable seal element, an outer fold-back ring, and an inner fold-back ring. The outer fold-back ring includes an end engaging the support ring. The inner fold-back ring is positioned between the seal element and the outer fold-back ring. The inner fold-back ring is movable as the seal element expands, causing an end of the inner fold back ring to move outwardly relative to an end of the inner-fold-back ring.
An accurate and elegant model is provided to characterize HFTO. For Type 1 HFTO, the model can predict frequency of the HFTO based on the distance between a reference location on the bottomhole assembly (e.g., the end of the drill bit) and a point 40% up the motor. In short BHA strings there is the fundamental frequency while in longer BHA the first harmonic is used. For Type 2 HFTO, the model can predict frequency of the HFTO based on distance between a reference location on the bottomhole assembly (e.g., the end of the drill bit) and the first slick contact point, which is optionally in the middle of a long flex joint.
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 forage commandés par ordinateurSystèmes spécialement adaptés à la surveillance de plusieurs variables ou conditions de forage
A method for predicting reservoir properties includes receiving seismic input data and electrical input data. The electrical input data includes spatial correlations between resistivity measurements behind a drill bit and unknown resistivity measurements on sides of and/or in front of the drill bit. The method also includes determining reservoir properties behind, on the sides of, and/or in front of the drill bit based upon the seismic input data and the electrical input data. The method also includes generating a display that shows a trajectory of the drill bit as well as the reservoir properties behind, on the sides of, and/or in front of the drill bit.
E21B 47/0224 - Détermination de l'inclinaison ou de la direction du trou de forage, p. ex. à l'aide de géomagnétisme utilisant des moyens sismiques ou acoustiques
Systems and methods for geologic production workflow are provided. A method includes: generating a forecast for extracting materials from a geological formation, including: providing data inputs including: a production history, a list of relevant features, and a list of categorical features, preparing data for a machine-learning model, the preparing data including: normalizing, sorting, and splitting the data inputs into a training dataset and a testing dataset, and providing normalization parameters, training a model using the training dataset, generating loss value and weight values, testing the trained model using the testing dataset and the generated loss and weight values, applying a final weight to the tested data, combining the weighted tested data with the normalization parameters and a prediction input to form a prediction, and generating a prediction output for each material, and operating equipment to extract the one or more materials in accordance with the generated forecast.
A subterranean drill bit for drilling wellbores that is configured with at least one functional slot within the body of the drill bit. The functional slot is formed in-situ with the formation of the bit and has a transitional layer of material between the material forming the body and an internal or inner surface of the functional slot. The in-situ transitional layer is made of a material with a higher toughness than that of the body to help reduce the residual stresses on the body of the drill bit during drilling operations.
E21B 10/60 - Trépans caractérisés par des canaux ou des buses pour les fluides de forage
E21B 49/02 - Test pour déterminer la nature des parois des trous de forageEssais de couchesProcédés 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
E21B 10/48 - Trépans caractérisés par des parties résistant à l'usure, p. ex. des diamants rapportés le trépan étant du type carottier
E21B 49/00 - Test pour déterminer la nature des parois des trous de forageEssais de couchesProcédés ou appareils pour prélever des échantillons du terrain ou de fluides en provenance des puits, spécialement adaptés au forage du sol ou aux puits
Certain aspects of the disclosure provide systems and methods for generating anomaly detection (AD) models. A method includes obtaining data comprising at least one input and at least one output, the at least one input and the at least one output associated with a target system; performing triage to determine an AD algorithm framework (AD framework) from a set of AD frameworks, wherein the AD framework is based on the at least one input and the at least one output and wherein the AD framework comprises one or more AD training algorithms; training one or more AD models based on the one or more AD training algorithms of the AD framework; and rank ordering the one or more AD models based on a benchmark set of data associated with the target system.
G06N 20/20 - Techniques d’ensemble en apprentissage automatique
G06F 11/22 - Détection ou localisation du matériel d'ordinateur défectueux en effectuant des tests pendant les opérations d'attente ou pendant les temps morts, p. ex. essais de mise en route
85.
IMPURITY REMOVAL FROM BRINES PRE/POST DIRECT LITHIUM EXTRACTION
Certain aspects of the present disclosure provide a method of reducing impurities in a brine stream. The method includes exposing a brine stream including one or more impurities to a precipitation reagent to produce a precipitate including a first amount of the one or more impurities and an intermediate brine stream comprising a residual amount of the one or more impurities. The method further includes filtering a second amount of the one or more impurities from the intermediate brine stream or a derivative thereof in a membrane separation unit to produce a purified brine stream. The one or more impurities include one or more multivalent metal cations, silica, boron, or a combination thereof.
C02F 1/52 - Traitement de l'eau, des eaux résiduaires ou des eaux d'égout par floculation ou précipitation d'impuretés en suspension
C02F 1/44 - Traitement de l'eau, des eaux résiduaires ou des eaux d'égout par dialyse, osmose ou osmose inverse
C22B 3/22 - Traitement ou purification de solutions, p. ex. de solutions obtenues par lixiviation par des procédés physiques, p. ex. par filtration, par des moyens magnétiques
C22B 3/44 - Traitement ou purification de solutions, p. ex. de solutions obtenues par lixiviation par des procédés chimiques
The disclosed drill tools have metal matrix composite (MMC) or steel alloy bodies that are formed around one or more pre-fabricated components using either a casting or infiltration process. The pre-fabricated components are made of sintered, infiltrated, and/or cemented particles of an ultrahard material, and may form any suitable portion of the bit blades. The pre-fabricated components may be loaded into a machined mold, and the mold cavity is subsequently filled with powder, such as tungsten carbide powder, filler metal powder, binder metal powder, or combinations thereof. During a casting or infiltration process, the mold and pre-fabricated components are heated to a sufficient temperature to melt the binder metal and/or filler metal, wherein the molten metal superficially interacts with the inner surfaces of the pre-fabricated components to form a metallurgical bond to secure the pre-fabricated components to the bit body.
Systems and methods presented herein facilitate coiled tubing operations, and generally relate to reduction of shock and vibrations to portions of the coiled tubing string. A device includes a first end configured to be disposed downstream of a bottom hole assembly of a coiled tubing drilling string; a second end configured to be disposed downstream of the first end and upstream of a drive of the coiled tubing drilling string; and a moveable valve configured to move from a first position to a second position to divert at least a portion of drilling fluid flow away from the drive when the drilling fluid flow is greater than a preset flow value or a weight on bit is less than a preset weight value and thereby reduce a rotation rate of the drive.
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 17/20 - Tubes de forage flexibles ou articulés
A method may include acquiring NMR data and sonic data for a borehole in a subsurface geologic region; inverting the NMR data and the sonic data to determine volume fractions for a number of classes of pore types, where the classes include shape and size-based classes; and characterizing the subsurface geologic region based on the volume fractions for the number of classes.
E21B 47/003 - Détermination des volumes du puits ou trou de forage
E21B 47/01 - Dispositifs pour supporter des instruments de mesure sur des trépans, des tubes, des tiges ou des câbles de forageProtection des instruments de mesure dans les trous de forage contre la chaleur, les chocs, la pression ou similaire
89.
SYSTEM AND METHOD FOR PREVENTING COLLISIONS IN WELLBORES
A method of preventing a collision of a subject wellbore in a downhole environment includes receiving offset wellbore data corresponding with one or more offset wellbores and identifying, based on the offset wellbore data, one or more no-go zones for each of the one or more offset wellbores. The method further includes determining a plurality of safe points corresponding with a potential intersection of the subject wellbore with the one or more no-go zones and, defining an escape zone within the plurality of safe points. The method further includes determining a trajectory for the subject wellbore within the escape zone.
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 forage commandés par ordinateurSystèmes spécialement adaptés à la surveillance de plusieurs variables ou conditions de forage
Certain aspects of the disclosure provide systems and methods for generating anomaly detection (AD) models. A method includes obtaining data comprising at least one input and at least one output, the at least one input and the at least one output associated with a target system; performing triage to determine an AD algorithm framework (AD framework) from a set of AD frameworks, wherein the AD framework is based on the at least one input and the at least one output and wherein the AD framework comprises one or more AD training algorithms; training one or more AD models based on the one or more AD training algorithms of the AD framework; and rank ordering the one or more AD models based on a benchmark set of data associated with the target system.
A wellbore seal includes a support ring, an expandable seal element, an outer fold-back ring, and an inner fold-back ring. The outer fold-back ring includes an end engaging the support ring. The inner fold-back ring is positioned between the seal element and the outer fold-back ring. The inner fold-back ring is movable as the seal element expands, causing an end of the inner fold back ring to move outwardly relative to an end of the inner-fold-back ring.
E21B 33/128 - PackersBouchons avec un organe dilaté radialement par pression axiale
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
92.
METHODS OF MEASURING A CATION EXCHANGE CAPACITY OF A WELLBORE FLUID, AND RELATED METHODS AND SYSTEMS
A method of measuring a cation exchange capacity of a wellbore fluid includes mixing a test solution including a concentration of methylthioninium chloride with a sample of a wellbore fluid to form a test sample, filtering the test sample through a filter to remove solids from the test sample and form a filtrate, and measuring an absorbance of the filtrate at one or more wavelengths. Related methods of drilling a borehole and computer-implemented methods are also disclosed.
G01N 27/04 - Recherche ou analyse des matériaux par l'emploi de moyens électriques, électrochimiques ou magnétiques en recherchant l'impédance en recherchant la résistance
G01V 3/26 - Prospection ou détection électrique ou magnétiqueMesure des caractéristiques du champ magnétique de la terre, p. ex. de la déclinaison ou de la déviation spécialement adaptée au carottage fonctionnant au moyen de champs magnétiques ou électriques produits ou modifiés par la formation terrestre environnante ou par les dispositifs de détection
G01V 3/38 - Traitement de données, p. ex. pour l'analyse, pour l'interprétation ou pour la correction
G01V 3/30 - Prospection ou détection électrique ou magnétiqueMesure des caractéristiques du champ magnétique de la terre, p. ex. de la déclinaison ou de la déviation spécialement adaptée au carottage fonctionnant au moyen d'ondes électromagnétiques
E21B 49/08 - Prélèvement d'échantillons de fluides ou test des fluides dans les trous de forage ou dans les puits
93.
SYSTEMS AND METHODS FOR OPERATING A DRILLING SYSTEM
A method for determining a feedback gain to operate a drilling system including a top drive, a drillstring, and a bottom hole assembly (BHA) includes obtaining input data. The input data includes drillstring data, BHA data, and top drive data. The method also includes determining a state of the drilling system based on the input data. The method further includes generating a drilling dynamic model of the drilling system based on the state of the drilling system. The method also includes determining a feedback gain based on the drilling dynamic model.
Aspects describe methods and apparatus to evaluate nuclear magnetic resonance data maps to identify structures and fluids within a geological stratum or series of geological stratum in an automatic fashion.
G06F 18/2133 - Extraction de caractéristiques, p. ex. en transformant l'espace des caractéristiquesSynthétisationsMappages, p. ex. procédés de sous-espace basée sur des critères de naturalité, p. ex. avec une factorisation non négative ou une corrélation négative
G06V 10/74 - Appariement de motifs d’image ou de vidéoMesures de proximité dans les espaces de caractéristiques
G06V 10/762 - Dispositions pour la reconnaissance ou la compréhension d’images ou de vidéos utilisant la reconnaissance de formes ou l’apprentissage automatique utilisant le regroupement, p. ex. de visages similaires sur les réseaux sociaux
G06V 10/766 - Dispositions pour la reconnaissance ou la compréhension d’images ou de vidéos utilisant la reconnaissance de formes ou l’apprentissage automatique utilisant la régression, p. ex. en projetant les caractéristiques sur des hyperplans
95.
GENERATIVE AI WORKFLOW FOR FLOW ASSURANCE ANALYSIS IN NATURAL GAS TRANSPORT OPERATIONS
A method for performing a flow assurance analysis in a pipeline includes receiving first input data related to a gas in the pipeline. The method also includes building or updating a model based upon the first input data. The method also includes receiving second input data including a query from a user. The method also includes identifying one or more topics to which the second input data is most closely related. The method also includes generating an answer to the query using the model based upon the one or more topics.
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
G06F 16/9038 - Présentation des résultats des requêtes
A method for monitoring seismic and microseismic activity in a subsurface includes positioning one or more seismic sensors at a wellsite. The method also includes positioning a plurality of non-seismic sensors at the wellsite. The method also includes measuring seismic data using the one or more seismic sensors. The method also includes measuring non-seismic data using the non-seismic sensors. The method also includes synchronizing the seismic data and the non-seismic data to produce synchronized data. The method also includes mapping seismic hypocenters in the subsurface based on the synchronized data.
A method for processing sonic waveforms may include an improved beamforming stacking method, wherein the improved beamforming stacking method comprises using different combinations of receivers by normalizing amplitudes of the waveforms given by subtraction of waveforms of a pair of receivers by receiver distance. An azimuth computation method is further disclosed for use in combination with the improved beamforming stacking.
Luminescent diamond is made by subjecting a volume of diamond grains to high-pressure/high-temperature conditions with or without a catalyst or pressure transfer media to cause the grains to undergo plastic deformation to produce nitrogen vacancy defects, increasing the luminescent activity/intensity of the resulting diamond material. The consolidated diamond material may be further treated to further increase luminescent activity/intensity including reducing the consolidated diamond material to diamond particles, heat treatment in vacuum, and/or air heat treatment. The resulting luminescent diamond particles display a level of luminescence intensity greater than that of conventional luminescent nanodiamond, and may be functionalized for use in biological applications.
A method including preparing a surface of a substrate, wherein the surface of the substrate includes a carbonous material, controlling, via a control system, a LIG subsystem to generate a LIG modified area of the substrate, modifying, via an electrochemical subsystem, the LIG modified area of the substrate to generate a sensing area comprising one or more types of nanoparticles, and performing, via a SERS subsystem, detection of a spectral signature of one or more PFAS compounds on the sensing area.
A model may identify a scale type for the target water-bearing fluid using a physics-based model. A model may input one or more known properties of the target water-bearing fluid and the scale type into a machine learning model. A model may extrapolate unknown properties of a historical data set using the machine learning model. A model may predict a scale inhibitor applicability index based on the historical data set and extrapolated unknown properties for the plurality of scale inhibitors. A model may output one or more of a list of scale inhibitors for use with the target water-bearing fluid or a list of scale inhibitor properties.
