A computer-implemented method includes identifying a repository of equipment documents in an unstructured format for oil and gas equipment, generating text-based equipment documents in a computer-readable text format, and generating a vector index of vector embeddings from the text-based equipment documents. The method includes, in response to receiving an equipment content request, providing the vector index and an equipment content prompt to a generative AI model for instructing the generative AI model to generate an equipment content response using the vector embeddings from the vector index. Based on receiving the equipment content response from the generative AI model, the method includes providing the equipment content response to a client device.
A method for identifying, ordering, and dull-grading a plurality of cutters on a drill bit includes capturing a plurality of frames of a plurality of blades on a drill bit. The method also includes capturing a plurality of frames of a plurality of blades on a drill bit and identifying a plurality of cutters on each of the blades in the frames. The method also includes identifying a first subset of the cutters that are primary cutters and arranging the primary cutters in a first order, and identifying a second subset of the cutters that are secondary cutters and arranging the secondary cutters in a second order. The method also includes extracting a thumbnail image of each of the cutters from the frames in the first order and/or the second order. The method also includes identifying cracks and/or erosion damage on the cutters based upon the extracted thumbnail image.
A method for processing well log data includes obtaining input data including the well log data. The well log data may include a plurality of datasets. Each dataset of the plurality of datasets includes one or more log curves and is associated with a respective well of one or more wells. The method also includes harmonizing the plurality of datasets using a curated dictionary to produce harmonized datasets. The method further includes reconstructing the one or more log curves of each harmonized dataset of the harmonized datasets to produce reconstructed logs using a supervised machine-learning (ML) model. The method also includes generating normalized datasets based on the harmonized datasets and using log normalization. The method also includes generating an output based on the reconstructed logs and the normalized datasets.
An aqueous composition includes an acid, or an ammonium or salt thereof; a hydrogen fluoride (HF) source; and a fluoride scale inhibitor. Various methods include providing the aqueous composition and performing a treatment operation using the aqueous composition.
C09K 8/528 - Compositions pour éviter, limiter ou éliminer les dépôts, p. ex. pour le nettoyage les dépôts inorganiques, p. ex. sulfates ou carbonates
E21B 37/06 - Procédés ou appareils pour nettoyer les trous de forage ou les puits utilisant des moyens chimiques pour empêcher ou limiter le dépôt de paraffine ou de substances analogues
E21B 43/27 - Procédés pour activer la production par formation de crevasses ou de fractures par emploi de produits chimiques érosifs, p. ex. d'acides
5.
WELLBORE BALANCED PRESSURE COMPENSATION FOR ROTATING CONTROL DEVICE (RCD) ROTARY SEALS
A seal assembly of a rotating control device (RCD) includes an interior chamber isolated from an external portion of the RCD and configured to store compensation fluid. The seal assembly also includes a piston that is configured to isolate the compensation fluid in the interior chamber from a wellbore fluid. The seal assembly also includes a path coupled to the interior chamber, a seal chamber coupled to the path, and a seal element disposed in the seal chamber and configured to form an annular seal about a tubular as the tubular rotates, moves axially, or both. The seal element is configured to receive the compensation fluid from the interior chamber at a first pressure via the path, the first pressure matching a second pressure of the wellbore fluid so that a pressure differential across the seal element during operation is zero.
A method includes receiving image data including a plurality of cells corresponding to a plurality of measured fluid properties of a subterranean region. The method also includes generating a plurality of nodes based on the plurality of cells, wherein each node of the plurality of nodes comprises relational information related to at least a portion of an arrangement of the plurality of cells. Further, the method includes generating a graph-based representation of the plurality of cells based on the plurality of nodes. Further still, the method includes generating a predicted graph-based representation of one or more fluid properties of the subterranean region over time based on a model of fluid properties in the subterranean region and the graph-based representation. Even further, the method includes adjusting one or more operation of one or more fluid systems associated with the subterranean region based on the predicted graph-based representation.
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 formation identification system may receive input data, the input data including sensor data for a wellbore along a wellbore length of the wellbore. A formation identification system may apply a machine learning model to the input data to generate an output including a formation type for at least one location along the wellbore length of the wellbore, wherein the machine learning model is trained to generate a predicted formation type based on a dataset.
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
8.
SYSTEMS AND METHODS FOR DETERMINING DEFORMATION OF A TOOL STRING
A method of predicting loading of a tool string implemented in a wellbore includes, for a formation testing operation of the wellbore, receiving temperature data for the wellbore and receiving pressure data for a fluid flowing through the tool string. The method includes, for the formation testing operation of the wellbore, estimating a deformation of the tool string based on the temperature data and the pressure data and based on physical properties of the tool string including determining thermal deformation of the tool string. The method further includes, for the formation testing operation of the wellbore, predicting one or more internal force of the tool string based on the deformation.
E21B 49/08 - Prélèvement d'échantillons de fluides ou test des fluides dans les trous de forage ou dans les puits
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
A method can include receiving cone penetrometer test data of measurements referenced with respect to depth in stratified material for a location at a site; processing the cone penetrometer test data using a machine learning model-based computational framework to identify one or more quality issues and to generate synthetic cone penetrometer test data at one or more depths; and outputting improved quality cone penetrometer data based at least in part on the generated synthetic cone penetrometer test data.
The present disclosure describes a method may include receiving input data comprising geological data, an indication of a set of components to be placed in a layout for the site, and an emission cost estimate for each of the set of components. The method may also include defining uncertainty parameters and generating a plurality of planning scenarios to implement based on the components and uncertainty parameters. Additionally, the method may include determining facility placements, well trajectories, pipeline placements, and a net present value for each of the planning scenarios. Further, the method may include calculating a tax credit for each of the planning scenarios, ranking each of the planning scenarios based on a respective net present value and a respective tax credit to generate a ranked list of the plurality of planning scenarios, and generating a visualization comprising the ranked list of the planning scenarios.
A method can include accessing a seismic data file for a seismic survey defined in part by a bin grid, where seismic data in the seismic data file are organized according to a data structure that includes headers and seismic trace data; performing an assessment of orthogonality of the bin grid of the seismic data file; responsive to detection of an orthogonality issue by the assessment, determining an orthogonal bin grid; extracting a trace header template using at least one of one or more introductory headers, where the trace header template specifies at least trace locations; performing a validation operation for validation of the trace header template; and, responsive to validation of the trace header template, outputting metadata that comports with the orthogonal bin grid and the validated trace header template for loading of the seismic data file to a data storage system.
A canned motor for a submersible pump system and a method of manufacturing a canned motor are provided. The canned motor includes a plurality of rotor bearings keyed to the can of the canned motor.
H02K 5/128 - Enveloppes ou enceintes caractérisées par leur configuration, leur forme ou leur construction spécialement adaptées à un fonctionnement dans un liquide ou dans un gaz utilisant des manchons d'entrefer ou des disques à film d'air
13.
SYSTEMS AND METHODS FOR FIELD SETUP OF GAS LEAK MONITORING TOOLS
A tangible and non-transitory machine readable medium including instructions to operate a monitoring tool in a setup mode and a normal operational mode. The monitoring tool includes one or more sensors, a power supply, and a controller coupled to the one or more sensors and the power supply, wherein the controller has a processor, a memory, and instructions stored on the memory and executable by the processor. The setup mode is configured to collect sensor data during a first rotational movement of the monitoring tool about a central axis of a mount, obtain calibration data based on the sensor data, calibrate the monitoring tool based on the calibration data, and identify a true North orientation of the monitoring tool during a second rotational movement of the monitoring tool about the central axis of the mount.
Certain aspects of the present disclosure provide a radio frequency identifier (RFID) telemetry system. The RFID telemetry system includes a first radio frequency identified (RFID) antenna at a surface of a wellbore; a second RFID antenna downhole in the wellbore; and a plurality of RFID devices. The plurality of RFID devices are configured to travel inside a pipe within the wellbore to the second RFID antenna while drilling fluid is being circulated inside the wellbore; receive downhole data from the second RFID antenna; travel inside an annulus outside the pipe in the wellbore to the first RFID antenna; and provide the downhole data to the first RFID antenna.
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 34/10 - Aménagements des vannes pour les trous de forage ou pour les puits dans les puits actionnés par un fluide de commande provenant de l'extérieur du trou de forage
E21B 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 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
G06K 19/04 - Supports d'enregistrement pour utilisation avec des machines et avec au moins une partie prévue pour supporter des marques numériques caractérisés par la forme
G06K 19/07 - Supports d'enregistrement avec des marques conductrices, des circuits imprimés ou des éléments de circuit à semi-conducteurs, p. ex. cartes d'identité ou cartes de crédit avec des puces à circuit intégré
Treatment of hydrocarbon formations using acid blends that contain water soluble polymers having chemical affinity for acid-susceptible rock species in the hydrocarbon formation is described herein. The polymers retard the activity of acid on acid-susceptible species of rock formations.
Computing systems, computer-readable media, and methods for providing an integrated platform. The method includes obtaining data from at least one source, wherein the data is in multiple formats and is related to one of an energy exploration stage, an energy development stage, and an operations stage. At least one data item from the at least one source is specified for visulization. The data is processed, wherein the processing includes parsing, extracting, and ingesting the data, the data including the at least one specified data item. Mahine learning is leveraged to obtain an optimum forecasting model, the leveraging including using at least one of autoregressive integrated moving average modelling and temporal fusion transformers. The specified at least one data item is visualized. A forecasting summary is provided based on theoptimum forecasting model.
A method can include initializing a visualization of volumetric seismic data using a computational framework, where the visualization includes a cuboid in a three-dimensional space for rendering as pixels in two-dimension to a display dimensions to a display according to a viewpoint, and where the visualization includes an opacity map; determining a front face of the cuboid and a back face of the cuboid from a perspective of the viewpoint; identifying bricks in a hierarchy of bricks of the volumetric seismic data for generation of a sparse texture for the visualization; and rendering the visualization to the display based on extending rays between the front face and the back face, sampling points on the rays, and associating the points with the sparse texture to provide values for the pixels of the visualization thresholded by the opacity map.
A method can include rendering a graphical user interface to a display that includes graphical controls for reservoir boundary picking, where the graphical controls for reservoir boundary picking include a quality control actuator for quality control of reservoir boundary picking via user interaction with respect to a rendering of one or more reservoir boundaries; graphical controls for reservoir boundary extrapolation, where the graphical controls for reservoir boundary extrapolation include a quality control actuator for quality control of reservoir boundary extrapolation of the reservoir boundaries via user interaction with respect to a rendering of at least one or more of the reservoir boundaries; and graphical controls for target selection, where the graphical controls for target selection include a quality control actuator for quality control of target selection via user interaction with respect to a rendering of at least one or more extrapolated reservoir boundaries.
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
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
19.
PHYSICS-ENFORCED DEEP LEARNING CALIBRATION AND DATA-MIXING TRANSFER LEARNING METHODS
Techniques and systems for training and deploying a machine learning model. This includes receiving first data, receiving second data, training a machine learning (ML) model of a neural network utilizing training data based upon the first data to generate a first trained ML model, isolating a first set of layers of the neural network from a second set of layers of the neural network, training a portion of the first trained ML model of the second set of layers of the neural network utilizing the second data to generate a fully trained ML model, and deploying the fully trained ML model on a data processing system to interpret received measurements collected in conjunction with a natural resource operation.
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
G01V 3/18 - 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
E02D 1/02 - Étude des sols de fondation sur place avant les travaux de construction
20.
IDENTIFYING LANDING OF DOWNHOLE EQUIPMENT AT A WELLHEAD
A wellhead landing, locking and sealing detection system may receive an acoustic signal from at least one acoustic sensor located on an outer surface of a wellhead. A wellhead landing, locking and sealing detection system may process the acoustic signal resulting in a processed acoustic signal. Processing the acoustic signal may include normalizing the acoustic signal, smoothing the acoustic signal, and differentiating a background signal from the acoustic signal. A wellhead landing, locking and sealing detection system may select a portion of the processed acoustic signal. A wellhead landing, locking and sealing detection system may identify a reflection characterization, frequency or profile from the portion. A wellhead landing, locking and sealing detection system may, based on the reflection characterization, frequency or profile, identifying a landing, locking and sealing configuration of the equipment with the wellhead.
A tangible and non-transitory machine readable medium including instructions to operate a monitoring tool in a setup mode and a normal operational mode. The monitoring tool includes one or more sensors, a power supply, and a controller coupled to the one or more sensors and the power supply, wherein the controller has a processor, a memory, and instructions stored on the memory and executable by the processor. The setup mode is configured to collect sensor data during a first rotational movement of the monitoring tool about a central axis of a mount, obtain calibration data based on the sensor data, calibrate the monitoring tool based on the calibration data, and identify a true North orientation of the monitoring tool during a second rotational movement of the monitoring tool about the central axis of the mount.
A device may include a body having a rotational axis. A device may include a steering pad, the steering pad being movable radially outward relative to the body at a hinge. A device may include a bore formed in the body, the bore having a bore longitudinal axis that is at least partially radially relative to the rotational axis of the body. A device may include a piston in the bore and movable in the bore to apply a radially outward force to the steering pad.
A decision management system may store a first version of a document in a knowledge database. A decision management system may receive an updated version of the document. A decision management system may store the updated version of the document in the knowledge database. A decision management system may receive a business decision associated with one of the first version or the updated version. A decision management system may link the one of the first version or the updated version to the business decision.
A tangible, non-transitory, computer-readable medium comprising instructions that, when executed by processing circuitry, are configured to cause the processing circuitry to retrieve one or more sets of data, transmit the one or more sets of data to an artificial intelligence (AI) model, transmit at least one instruction to the AI model to elicit summarization of one or more sets of data into a summarized one or more subsets of data, selectively extract portions of the one or more subsets of data based on a pre-determined criteria, and generate a report of one or more extracted subsets of data and/or action by the AI model based on at least one instruction of one or more sets of data.
G06F 16/387 - Recherche caractérisée par l’utilisation de métadonnées, p. ex. de métadonnées ne provenant pas du contenu ou de métadonnées générées manuellement utilisant des informations géographiques ou spatiales, p. ex. la localisation
A device may include a body having a rotational axis. A device may include a steering pad, the steering pad being movable radially outward relative to the body at a hinge. A device may include a bore formed in the body, the bore having a bore longitudinal axis that is at least partially radially relative to the rotational axis of the body. A device may include a piston in the bore and movable in the bore to apply a radially outward force to the steering pad.
An apparatus for a rotating packed bed reactor (RPB) that may be used to increase the mass-transfer rate between materials, such as a gas and a liquid, through the RPB. The rotor of the RPB may be rotatably driven within a housing at least in part by the direction of a gas in a tangential direction relative to an outer circumferential surface of the rotor. An RPB may include a housing having a gas inlet, a liquid inlet, a gas outlet, and a liquid outlet. The rotor includes a permeable packing configured to facilitate contact between the liquid and the gas passing through the permeable packing while the rotor rotates with respect to the housing. The gas inlet is configured to direct the gas tangentially with respect to the outer circumferential surface of the rotor to thereby cause the rotor to rotate with respect to the housing.
B01D 53/18 - Unités d'absorptionDistributeurs de liquides
B01D 53/14 - 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 absorption
B01D 53/34 - Épuration chimique ou biologique des gaz résiduaires
A downhole tool configured to be located in a wellbore traversing a formation to obtain a formation fluid sample. In some embodiments, the downhole tool can include one or more fluid intake ports configured to receive a formation fluid and a fluid monitor that can be configured to measure one or more formation fluid properties of the received formation fluid. The at least one of the one or more fluid intake ports can be in an open position. The one or more fluid intake ports can be in the open position for a first period of time (t) such that the one or more fluid intake ports are configured to obtain formation fluid located at a first distance from the sidewall of the wellbore within the formation.
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
A system and method that includes the use, over both space and time domains, of a single pair source-receiver to map in a focused manner at a very low operational and processing cost, the change in ‘fluid’ content at a specific location. The source-receiver may include multiple embodiments including a single source with multiple receivers, multiple sources with multiple receivers, or multiple sources with a single receiver.
A method may include acquiring raw seismic data, computing event location and corresponding P and S wave arrivals, automatically obtaining polarity of the corresponding P and S waves arrivals, measuring fit of P and S wave polarity to a model to obtain a group of accepted solutions, analyzing distribution of the accepted solutions in the model, and identifying a best solution as a focal mechanism.
G01H 9/00 - Mesure des vibrations mécaniques ou des ondes ultrasonores, sonores ou infrasonores en utilisant des moyens sensibles aux radiations, p. ex. des moyens optiques
G01V 1/00 - SéismologieProspection ou détection sismique ou acoustique
G01V 1/20 - Aménagements d'éléments récepteurs, p. ex. oscillogrammes géophoniques
G01V 1/28 - Traitement des données sismiques, p. ex. pour l’interprétation ou pour la détection d’événements
30.
COMMUNICATION METHOD FOR UNTETHERED DOWNHOLE SYSTEMS
The disclosure provides methods of communication for untethered systems. The method includes defining a window for sampling a torque-related current and a modulator rotor relative position-related parameter; using the defined window, recording local maximum and local minimum values of the torque-related current versus a modulator rotor relative position-related parameter of a rotor of a rotary pulser system in the untethered system; identifying at least one of consecutive torque-related current minimum values and consecutive torque-related current maximum values based on a periodicity; computing an absolute modulator rotor position based on the periodic maxima and minima of the torque-related current; and controlling the modulator rotor using the absolute modulator rotor position to modulate uplink signals to a surface environment.
E21B 47/18 - 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
31.
SYSTEMS AND METHODS FOR DETERMINIG DEPTH-DEPENDENT DRILLING PARAEMTER LIMITS
A parameter roadmap system receiving reference wellbore data including drilling parameter data for one or more reference wellbores and selects a segmentation parameter set and associated segmentation parameter data from the reference wellbore data. Based on the segmentation parameter data, the parameter roadmap system segments the reference wellbore data into a plurality of depth segments using a statistical segmentation model. The parameter roadmap system identifies a segment threshold for each drilling parameter of the reference wellbore data at each of the plurality of depth segments to generate a drilling parameter roadmap and provides the roadmap for forming a target wellbore.
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
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
32.
METHOD AND APPARATUS TO PERFORM A WIRELINE CABLE INSPECTION
A method and apparatus to quickly identify defects in a cable used in hydrocarbon recovery wireline operations. A series of high-speed cameras take pictures along a length of the wireline cable, while artificial intelligence data processing algorithms process the camera data.
A method includes receiving input data from external data sources. The input data is received by a data product pipeline. The method also includes extracting a portion of the input data using the data product pipeline to produce extracted data. The method also includes transferring the extracted data from the data product pipeline to a data product raw storage. The method also includes receiving the input data directly from the external data sources. The method also includes transferring the extracted data and the input data from the data product raw storage back to the data product pipeline. The method also includes receiving data products. The method also includes transforming the input data, the extracted data, and the data products into transformed data using the data product pipeline. The method also includes transferring the transformed data to a data product artifact storage.
Embodiments presented provide for stress testing of downhole wireline formation testing equipment. Certain embodiments provide for stress testing of geological stratum which exhibit high permeability.
E21B 49/08 - Prélèvement d'échantillons de fluides ou test des fluides dans les trous de forage ou dans les puits
E21B 33/124 - Unités à bouchons espacés longitudinalement pour isoler les espaces intermédiaires
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
35.
SYSTEMS AND METHODS FOR NON-CONTACT MEASUREMENT FOR CENTRIFUGE SOLIDS DISCHARGE
A method for analyzing solids discharged from a drilling process is provided. The method includes detecting a velocity and depth of discharged solids. The method determines a detected flow rate of the discharged solids based on the velocity and the depth of the discharged solids. A system for analyzing discharge from a drilling process, is provided. The system includes a centrifuge system for separating fines from a discharge, an imaging system for providing images of the discharge provided by the centrifuge system, and a processor configured to determine a volume of the discharge based on the images of the discharge.
A fluid displacement pump can include a rotor; and a stator, where the stator includes an elastomeric material with a non-uniform thickness, and where the rotor and the stator have a one-to-two lobe ratio.
F04C 13/00 - Adaptations des "machines" ou pompes pour utilisation particulière, p. ex. pour très hautes compressions
F04C 2/08 - Machines ou pompes à piston rotatif du type à engrènement extérieur, c.-à-d. avec un engagement des organes coopérants semblable à celui d'engrenages dentés
F04C 2/107 - Machines ou pompes à piston rotatif du type à engrènement extérieur, c.-à-d. avec un engagement des organes coopérants semblable à celui d'engrenages dentés du type à axe interne, l'organe externe ayant plus de dents ou de parties équivalentes de prise, p. ex. de rouleaux, que l'organe interne avec des dents hélicoïdales
37.
CUTTINGS TREATMENT USING CHEMICALLY ENHANCED CAVITATION
Methods and apparatus for treatment of solids containing hydrocarbon are described herein. The solids are treated by adding a cavitation cleaner to the stream; introducing the stream, with the cavitation cleaner, to a cavitation unit; and separating oil from the solids using a cavitation process within the cavitation unit.
E21B 21/06 - Dispositions pour traiter les fluides de forage à l'extérieur du trou de forage
B08B 3/08 - Nettoyage impliquant le contact avec un liquide le liquide ayant un effet chimique ou dissolvant
B08B 7/02 - Nettoyage par des procédés non prévus dans une seule autre sous-classe ou un seul groupe de la présente sous-classe par distorsion, battage ou vibration de la surface à nettoyer
38.
SETTABLE SCAVENGER SPACER FLUID FOR DISPLACING DRILLING MUD
Described herein are settable spacer fluids and methods of making and using such fluids. The settable spacer fluids generally contain a polymerizable raw material and activator in aqueous medium, where the spacer fluid is configured to have density sufficient to displace fluids within a well and to solidify after a duration sufficient to allow use of the spacer fluid to aid in well development and placement of the spacer fluid at a target location prior to significant transformation. The spacer fluid solidifies over time, but can be used with final compressive strength as low as 50 psi.
C09K 8/40 - Compositions d'espacement dites "spacers", p. ex. compositions utilisées pour séparer les masses de forage et de cimentation
C09K 8/42 - Compositions de cimentation, p. ex. pour la cimentation des tubes dans les trous de forageCompositions de bouchage, p. ex. pour tuer des puits
C09K 8/44 - Compositions de cimentation, p. ex. pour la cimentation des tubes dans les trous de forageCompositions de bouchage, p. ex. pour tuer des puits contenant uniquement des liants organiques
E21B 21/00 - Procédés ou appareils pour nettoyer les trous de forage par jet de fluide, p. ex. en utilisant l'air d'échappement du moteur
E21B 33/138 - Plâtrage de la paroi du trou de forageInjections dans la formation
39.
CO2 BLEED-OFF PROCESS WITH EQUIPMENT PRESERVATION DURING TEMPORARY CO2 INJECTION PROCESS
A method of depressurizing a volume of trapped CO2. The method including injecting displacement fluid in a closed system to displace the volume of trapped CO2 and releasing the trapped CO2 out of the trapped system through a depressurization line while maintaining pressure in the closed system above a CO2 saturation pressure.
A system for, and method of, drill deviation handling within a stand while drilling a wellbore are presented. The techniques include: receiving, by an electronic processor and during a stand, drill state data; comparing, by the electronic processor and during the stand, the drill state data to an active drill plan; detecting, by the electronic processor and based on the comparing, an out-of-tolerance deviation of a drill parameter; and providing, by the electronic processor, an alert of the out-of-tolerance deviation.
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 extracting data from a database for use in a well construction process includes receiving a question from a user. The question is in a well construction language. The method also includes determining context based upon the question. Determining the context includes retrieving key performance indicators (KPIs) based upon the question, and retrieving a plurality of tables from the database. The tables are retrieved based upon the question. The method also includes generating a prompt based upon the question and the context. The method also includes generating a structured query language (SQL) query based upon the prompt using a large language model (LLM). The method also includes running the SQL query against the tables in the database in an attempt to produce a new table. The method also includes performing a wellsite action in response to the new table.
A system and method for determining the location of a droppable object in a wellbore. The droppable object includes an integrated locating system that detects completion components as the object moves through a casing string. The locating system includes an actuation device that is activated based on detection of the components. When activated, the actuation device exerts a radially directed frictional pressure against the inner wall of the casing string, thereby generating pressure pulse telemetry signals that are detected and analyzed by surface equipment to determine the object's downhole location.
E21B 47/09 - 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 33/13 - Procédés ou dispositifs de cimentation, de bouchage des trous, des fissures ou analogues
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
43.
SYSTEMS AND METHODS FOR NON-CONTACT MEASUREMENT FOR SOLIDS DISCHARGE
A method for analyzing solids discharged from a drilling process is provided. The method includes detecting a velocity and depth of discharged solids. The method determines a detected flow rate of the discharged solids based on the velocity and the depth of the discharged solids. A system for analyzing discharge from a drilling process, is provided. The system includes a centrifuge system for separating fines from a discharge, an imaging system for providing images of the discharge provided by the centrifuge system, and a processor configured to determine a volume of the discharge based on the images of the discharge.
E21B 21/06 - Dispositions pour traiter les fluides de forage à l'extérieur du trou de forage
E21B 47/002 - Relevés dans les trous de forage ou dans les puits par inspection visuelle
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
A downhole heating tool for activating a polymeric sand screen includes an outer pipe and an inner pipe disposed within the outer pipe. A reacting media is disposed within the inner pipe, the reacting media is configured to undergo an exothermic chemical reaction. A pressure activated trigger isolates the reacting media from a fluid pressure outside the inner pipe, the pressure activated trigger being activatable by a pressure signal to initiate the exothermic chemical reaction of the reacting media. A sand screen is disposed about the outer pipe. The pressure activated trigger may include a rupture disc or an electrical switch. A one-way flow mechanism may be in communication with an end of the inner pipe. A heat moderation fluid may be disposed in a space defined between the outer pipe and the inner pipe.
E21B 36/00 - Aménagements pour le chauffage, le refroidissement ou l'isolation dans les trous de forage ou dans les puits, p. ex. pour être utilisés dans les zones de permagel
E21B 33/13 - Procédés ou dispositifs de cimentation, de bouchage des trous, des fissures ou analogues
A swage element includes a sleeve having a first outer arm, a second outer arm, and an intermediate support disposed between them. The first outer arm and intermediate support define a first channel, and the second outer arm and intermediate support define a second channel. An elastomeric element is disposed in both channels. The elastomeric element includes a first portion in the first channel having an internal surface bonded to the sleeve and an outer surface defining a first groove, and a second portion in the second channel having an internal surface bonded to the sleeve and an outer surface defining a second groove. The intermediate support includes a tapered face configured to direct deformation of the elastomeric element toward a sealing surface under fluid pressure, enabling self-energization.
A method may include receiving input during execution of a field operations framework, where the field operations framework includes components for one or more of planning field operations and controlling field operations, and where the input corresponds to a workflow that includes a series of tasks; responsive to receipt of the input, automatically accessing one or more large language models to generate output based at least in part on a portion of the input; automatically transmitting the output to a task-oriented reasoning component to generate one or more agent instructions; automatically transmitting at least one of the one or more agent instructions to a corresponding agent; and, responsive to the transmitting, automatically issuing at least one rendering instruction for rendering information to a display, where the information facilitates performance of one or more of the tasks of the workflow.
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
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
G06N 5/022 - Ingénierie de la connaissanceAcquisition de la connaissance
47.
REAL-TIME MONITORING, ANOMALIES DETECTION, AND AUTOMATIC CORRECTION OF TOTAL GAS MEASUREMENTS
Aspects of the present disclosure provide a method for modifying a mud-logging operation based on a total gas baseline. The method includes determining an offset between a total gas sensor and one or more gas chromatographs, supplying an operating gas containing hydrocarbons to the total gas sensor and the one or more gas chromatographs during a mud-logging operation, supplying a carrier gas to the total gas sensor and the one or more gas chromatographers from a first carrier gas source during the mud-logging operation; calculating a theoretical total gas baseline based on the offset and a measured gas chromatograph baseline; determining a drift of theoretical total gas baseline; and switching from the first carrier gas source to a second carrier gas source.
A method for reconditioning a gas chromatography apparatus at a rig site includes providing a gas chromatography (GC) apparatus including at least a trapping column, a main column, and a detector. The main column is configured to separate at least methane, ethane, propane, butane, and pentane compounds in a gas stream. The trapping column is configured to remove interfering alkene or alcohol compounds from the gas stream. A plurality of GC measurements is made at the rig site by flowing the gas stream in a forward direction through the trapping column and the main column to the detector. A reconditioning gas is flowed in a reverse direction through the trapping column on the rig site after completing the plurality of GC measurements while heating the trapping column to a temperature of at least 120 degrees C. to recondition the trapping column.
A method for estimating a cuttings lag time or lag time distribution during a drilling operation includes circulating drilling fluid in a wellbore while drilling. Colored magnetic markers are introduced into the circulating drilling fluid while drilling. A magnetic or electromagnetic trap is used to remove colored magnetic markers from the circulating drilling fluid. The removed colored magnetic markers are detected based upon their color using an optical sensor. Surface arrival times of the detected colored magnetic markers are evaluated to estimate the lag time or the distribution of lag times.
E21B 47/11 - Localisation des fuites, intrusions ou mouvements du fluide utilisant des traceursLocalisation des fuites, intrusions ou mouvements du fluide utilisant la radioactivité
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 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
A method for estimating a drill cuttings lag time during a drilling operation includes circulating drilling fluid in a wellbore to drill. A plurality of radio frequency identification device (RFID) tags and/or a colored dye are introduced into the circulating drilling fluid while drilling. Arrival times of the RFID tags or the colored dye at the surface are evaluated to estimate the drill cuttings lag time.
E21B 21/08 - Commande ou surveillance de la pression ou de l'écoulement du fluide de forage, p. ex. remplissage automatique des trous de forage, commande automatique de la pression au fond
E21B 21/06 - Dispositions pour traiter les fluides de forage à l'extérieur du trou de forage
51.
LEAK EMISSIONS SENSOR SYSTEMS AND PROCESSES FOR INSTALLING AND USING SAME
A leak emissions sensor system for a facility. In some embodiments, the leak emissions sensor system can include one or more detector assemblies. Each detector assembly can include a sensor assembly for obtaining and sending emission information and a displacement apparatus. The sensor assembly can include a leak emission detection sensor, a sensor processor, a GPS, a real-time clock, a wind sensor, and a sensor communicator. The sensor assembly can be disposed on the displacement apparatus. The displacement apparatus can be configured to relocate the sensor assembly within the facility.
G01M 3/16 - 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 en utilisant des moyens de détection électrique
G01D 3/10 - Dispositions pour la mesure prévues pour les objets particuliers indiqués dans les sous-groupes du présent groupe avec dispositions pour intercaler des organes indicateurs ou enregistreurs supplémentaires ou auxiliaires
G01D 11/30 - Supports spécialement adaptés à un instrumentSupports spécialement adaptés à un ensemble d'instruments
G01D 21/02 - Mesure de plusieurs variables par des moyens non couverts par une seule autre sous-classe
G01S 19/14 - Récepteurs spécialement adaptés pour des applications spécifiques
52.
SYSTEMS AND METHODS FOR DETERMINING REAL-TIME PERFORMANCE OF COILED TUBING CLEANOUT OPERATIONS
Systems and methods presented herein facilitate improvement of coiled tubing cleanout operations (CTCOs), and generally relate to systems and methods for providing real-time diagnostics of the CTCOs. For example, an example method includes acquiring, via one or more sensors of a coiled tubing system, data relating to a CTCO performed at least partially within a wellbore of the coiled tubing system; analyzing, via a processing and control system, the acquired data to provide real-time diagnostics of downhole conditions within the wellbore during performance of the CTCO; providing, via the processing and control system, one or more outputs relating to the real-time diagnostics of the downhole conditions within the wellbore during performance of the CTCO; and adjusting, via the processing and control system, one or more operational parameters of the CTCO based at least in part on the one or more outputs.
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
A method can include receiving log data for different types of logs; identifying a portion of the log data that corresponds to a type of formation; defining combinations of the portion of the log data that correspond to the type of formation; implementing a machine learning model that generates scores for the combinations, where each of the scores indicates an ability of each of the combinations to predict one or more target logs therein as selected from the different types of logs; and outputting, based on a ranking of the scores, at least a top ranked one of the combinations that corresponds to the type of formation.
A method of bonding a cutting element to a downhole drilling tool includes orienting an induction coil with respect to a cutting element pocket and applying an energy input to the induction coil to heat the cutting element pocket to a brazing temperature. The method further includes determining a pocket temperature of the cutting element pocket and, based on the pocket temperature, controlling the energy input to the induction coil to maintain the pocket temperature at the brazing temperature for a brazing period.
Systems and methods presented herein relate to a stator lining. A mud motor system includes a stator housing with an inner surface and an anisotropic elastomer reinforcement lining disposed on the inner surface. The anisotropic reinforcement lining has a plurality of lobes arranged helically. The anisotropic elastomer reinforcement lining includes one or more elastomer materials and a plurality of reinforcement fibers. A major axis of the plurality of reinforcement fibers is substantially perpendicular to a helical direction of the plurality of lobes.
E21B 4/02 - Moyens d'entraînement de type rotatif par fluide
B29C 70/22 - Façonnage de matières composites, c.-à-d. de matières plastiques comprenant des renforcements, des matières de remplissage ou des parties préformées, p. ex. des inserts comprenant uniquement des renforcements, p. ex. matières plastiques auto-renforçantes des renforcements fibreux uniquement caractérisées par la structure des renforcements fibreux utilisant des fibres de grande longueur, ou des fibres continues orientées dans au moins deux directions formant une structure bidimensionnelle
B29C 70/42 - Façonnage ou imprégnation par compression pour la fabrication d'objets de longueur définie, c.-à-d. d'objets distincts
F04C 2/10 - Machines ou pompes à piston rotatif du type à engrènement extérieur, c.-à-d. avec un engagement des organes coopérants semblable à celui d'engrenages dentés du type à axe interne, l'organe externe ayant plus de dents ou de parties équivalentes de prise, p. ex. de rouleaux, que l'organe interne
56.
SOLIDS SEPARATION SCREEN WITH PATTERNED ENCAPSULATION
Solids separation screens are described herein that have a primary separation layer comprising a wire mesh and a patterned fusible encapsulant structure encapsulating a portion of the wire mesh in a pattern.
Methods for determining a compressibility factor are disclosed. A method may include disposing a downhole fluid analysis tool within a wellbore, extracting a formation fluid from the wellbore, pumping the formation fluid through the downhole fluid analysis tool, measuring at least one of a flowline temperature, a flowline pressure, a formation fluid mass density, and a pumped volume, measuring compositions (wt %) of CO2, C1, C2, C3, C4, C5 and C6+ (wj, where j=CO2, C1, C2, C3, C4, C5 and C6+) in the formation fluid, estimating pluralities of molecular weight of C6+ in the formation fluid, estimating pluralities of molecular weight of the formation fluid, calculating the compressibility factor of the formation fluid based upon the flowline temperature, the flowline pressure, the formation fluid mass density, and the molecular weight of the formation fluid, and outputting the compressibility factor of the formation fluid.
Methods of cementing a subterranean well using a geopolymer composition are provided herein. In one aspect, the geopolymer composition can be a pumpable mixture comprising an aluminosilicate source, an activator, a carrier fluid, and a fluid loss composition comprising at least two materials selected from the group consisting of a water soluble polymer, a polymer particle dispersion, a particulate additive, and a dispersant. The geopolymer composition is placed in the subterranean well and allowed to harden into a solid geopolymer. Other methods herein include preparing a dry geopolymer slurry precursor comprising an aluminosilicate source, a metal silicate, an activator, a fluid loss control agent, and a fluid loss control agent enhancer; mixing the dry geopolymer slurry precursor with water to form a pumpable geopolymer precursor; pumping the geopolymer precursor into a subterranean well; and hardening the geopolymer precursor into a solid geopolymer within the subterranean well.
C04B 28/00 - Compositions pour mortiers, béton ou pierre artificielle, contenant des liants inorganiques ou contenant le produit de réaction d'un liant inorganique et d'un liant organique, p. ex. contenant des ciments de polycarboxylates
C04B 40/00 - Procédés, en général, pour influencer ou modifier les propriétés des compositions pour mortiers, béton ou pierre artificielle, p. ex. leur aptitude à prendre ou à durcir
C04B 103/00 - Fonctions ou propriétés de l'ingrédient actif
This disclosure is directed to methods and systems for generating ontological datasets using cloud data for energy development operations. According to one embodiment, a data processing engine stored in a memory device may receive cloud data from a plurality of sources and generate an ontology dataset based on parsing the cloud data. The data processing engine may initiate provisioning of an electronic dashboard on a display device based on a first user input. The electronic dashboard may include one or more display elements associated with the ontology dataset. Moreover, the one or more display elements of the electronic dashboard are activatable to load a computing resource associated with the cloud data. Furthermore, the one or more display elements of the electronic dashboard: are electronically linked to the computing resource; and may comprise picture data, video data, audio data, or textual data.
A method implements automation of product carbon footprint computations. A process map view is displayed, including multiple process nodes and product nodes. A process view is displayed for a process model associated with one of the process nodes. The process map view is updated with a footprint node that is connected to one or more process nodes. A set of process models, including the selected process model, is processed using footprint data from the footprint node to calculate process emissions. The process map view is updated to display the calculated emissions for the connected process nodes. The process emissions are further processed to determine an overall emission value. A dashboard view is displayed showing the emission value for a product represented by a product node.
A method for monitoring valve health. The method may include receiving valve data from a source, pre-processing the received valve data, and detecting at least one event based on the pre-processed valve data to provide event signature data. The method may also include determining that the detected event is an anomaly based on the event signature data, classifying the anomaly based on the event signature data, and performing an action based on the classified anomaly. The method may also include training an event classification model to classify the anomaly according to the event signature data. Training the event classification model to classify the anomaly may include reviewing and labeling a plurality of plots of the event signature data by a subject matter expert and then providing the labeled event signature data to the event classification model, and validating the classification model by the subject matter expert.
F16K 37/00 - Moyens particuliers portés par ou sur les soupapes ou autres dispositifs d'obturation pour repérer ou enregistrer leur fonctionnement ou pour permettre de donner l'alarme
F16K 3/02 - 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 planesGarnitures d'étanchéité à cet effet
A system for consolidating particles in a subterranean formation includes a treatment fluid (e.g., a consolidation fluid) having a viscosity lower than 5 cP. The treatment fluid includes a resin system, a surfactant, and a curing agent. A method for consolidating particles in a subterranean formation includes preparing the treatment fluid, introducing the treatment fluid into the subterranean formation, and allowing the treatment fluid to cure to consolidate the particles in the subterranean formation.
A method for steering a downhole tool to drill a wellbore in a subterranean formation includes receiving an initial wellbore plan for the downhole tool to drill through the subterranean formation. The method also includes receiving drilling data while the downhole tool is drilling through the subterranean formation using the initial wellbore plan. The method also includes comparing the initial wellbore plan to the drilling data. The method also includes determining a downlink command to transmit to the downhole tool based upon or in response to the comparison. The method also includes determining an importance of the downlink command based upon the comparison. The method also includes determining a time to transmit the downlink command to the downhole tool. The time is determined based upon the importance of the downlink command. The method also includes transmitting the downlink command to the downhole tool at the determined time.
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 47/024 - Détermination de l'inclinaison ou de la direction des dispositifs dans le trou de forage
E21B 47/04 - Mesure de la profondeur ou du niveau du liquide
A backpressure relieving system for an open hole high expansion packer includes a first unidirectional sealing element and a second unidirectional sealing element spaced apart from the first unidirectional sealing element. A trapped volume zone is defined between the first unidirectional sealing element and the second unidirectional sealing element. A relief valve is in fluid communication with the trapped volume zone. The relief valve is configured to permit fluid flow from the trapped volume zone in a single direction. A filter is positioned upstream of the relief valve. The filter is configured to prevent debris from entering the relief valve.
E21B 21/10 - Aménagements des vannes dans les systèmes de circulation des fluides de forage
E21B 34/10 - Aménagements des vannes pour les trous de forage ou pour les puits dans les puits actionnés par un fluide de commande provenant de l'extérieur du trou de forage
65.
GENERATIVE ARTIFICIAL INTELLIGENCE SYSTEM TO IMPORT SEMI-UNSTRUCTURED DOCUMENTS INTO A STANDARD FORMAT
The present disclosure relates to systems and methods for using a generative artificial intelligence system to automatically import data from documents in a standard format. The systems and methods use the generative artificial intelligence system to assist with writing a parsing template to use in converting the data from the documents into the standard format.
A method including receiving cutter lab test data associated with cutter types; generating a first model based on the cutter lab test data, wherein the first model is representative of effects to one or more rock types provided by using the cutter types; receiving bit lab test data associated with drill bits; generating a second model based on the first model and the bit lab test data, wherein the second model is representative of additional effects to the one or more rock types provided by the drill bits; receiving drilling log data associated with additional drill bits; simulating drilling dynamics for the drill bits and additional drill bits based on the second model and the drilling log data; receiving borehole data associated with a borehole; and determining a bit design for use in the borehole based on the simulated drilling dynamics and the borehole data.
E21B 10/43 - 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 caractérisés par la disposition des dents ou des autres éléments coupants
G06F 30/20 - Optimisation, vérification ou simulation de l’objet conçu
67.
SEQUENTIAL SENSOR PLACEMENT FOR GAS EMISSION DETECTION USING RECORD COUNT
Aspects of the disclosure provide for sensor placement for gas emission detection using record count. A method for sensor placement includes obtaining wind rose distribution data associated with a site for gas emission detection and generating a plurality of wind realizations from the wind rose distribution data. The method includes generating a plurality of records associated with predicted sensor measurements at each candidate sensor location for each of a plurality of potential gas emission locations at the site and subject to each of the plurality of wind realizations and ranking the candidate sensor location based on a record count. The method includes iteratively selecting for gas emission detection sensor placement a candidate sensor location, from the plurality of candidate sensor locations, having a highest ranking and removing at least the selected candidate sensor location from the plurality of candidate sensor locations.
G01N 33/00 - Recherche ou analyse des matériaux par des méthodes spécifiques non couvertes par les groupes
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
68.
DRILL BIT DESIGN AND DRILLING OPERATION CONTROL WORKFLOW FOR MITIGATING TORQUE OSCILLATIONS
A method including receiving cutter lab test data associated with cutter types; generating a first model based on the cutter lab test data, wherein the first model is representative of effects to one or more rock types provided by using the cutter types; receiving bit lab test data associated with drill bits; generating a second model based on the first model and the bit lab test data, wherein the second model is representative of additional effects to the one or more rock types provided by the drill bits; receiving drilling log data associated with additional drill bits; simulating drilling dynamics for the drill bits and additional drill bits based on the second model and the drilling log data; receiving borehole data associated with a borehole; and determining a bit design for use in the borehole based on the simulated drilling dynamics and the borehole data.
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
The present disclosure relates to systems and methods for using a generative artificial intelligence system to automatically import data from documents in a standard format. The systems and methods use the generative artificial intelligence system to assist with writing a parsing template to use in converting the data from the documents into the standard format.
A displacement unit. The displacement unit may include a body, a head shaft, a base shaft, a middle shaft, and radial bearings. The body may include a head and a base. The head shaft may extend through the head of the body. The base shaft may extend through the base of the body. The middle shaft may be coupled to the head shaft via a first flexible coupling and coupled to the base shaft via a second flexible coupling. The radial bearings may be disposed within body to support at least one of the head shaft, the middle shaft, or the base shaft.
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
E21B 43/12 - Procédés ou appareils pour commander l'écoulement du fluide extrait vers ou dans les puits
A technique facilitates utilization of an electric submersible pumping system able to provide a desired production output with a reduced length. The electric submersible pumping system is sized for deployment in a borehole, e.g. within a borehole casing, and utilizes contra rotating impellers mounted on contra rotating shafts. To enable the contra rotation, the shafts may comprise a first shaft rotatably disposed within a hollow interior of a second shaft. This type of construction allows operation of the contra rotating impellers so as to enhance production without the length of sequential, traditional impellers.
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
E21B 43/12 - Procédés ou appareils pour commander l'écoulement du fluide extrait vers ou dans les puits
Systems and methods presented herein facilitate operation of well-related tools. In certain embodiments, a priori data may be obtained to enable optimization of operations related to the well-related tools. In certain embodiments, the a priori data may be provided as advisory data in one or more visualizations, used to facilitate automatic detection of one or more milling events, and/or used to automate one or more milling processes.
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 29/00 - Découpage ou destruction de tubes, packers, bouchons ou câbles, situés dans les trous de forage ou dans les puits, p. ex. découpage de tubes endommagés, de fenêtresDéformation des tubes dans les trous de forageRemise en état des tubages de puits sans les retirer du sol
E21B 47/002 - Relevés dans les trous de forage ou dans les puits par inspection visuelle
73.
CASCADED DEEP-LEARNING TECHNIQUES FOR GENERATING HIGH RESOLUTION HORIZON DATA
The present disclosure describes techniques including receiving seismic data corresponding to a subsurface region. The techniques also include filtering the seismic data. The filtered seismic data corresponds to one or more depth ranges within the subsurface region. Further, the techniques include applying a first horizon model to the filtered seismic data. The first horizon model outputs a first set of horizon data having a first resolution indicating an expected location of a horizon within the one or more depth ranges. Even further, the techniques include applying a second horizon model to a portion of the seismic data centered based on the first set of horizon data. Further still, the techniques include generating a second set of horizon data based on the portion of seismic data, the first set of horizon data, and the second horizon model. The second set of horizon data has a higher resolution than the first resolution.
A method may include generating results for one or more layers of a computational framework; combining the results to generate an optimal operating window (OOW) for drilling operations; and controlling equipment to perform one or more of the drilling operations based on the optimal operating window.
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 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
75.
SYSTEMS AND METHODS FOR DETERMINING DOWNLINKS FOR TRANSMITTING TO A DOWNHOLE TOOL
In some embodiments, a method of implementing an operation of a downhole tool within a wellbore includes identifying a tool command for a downhole tool to change a current state of the downhole tool to a target state. The method further includes determining, from a set of candidate downlink commands, a set of one or more downlink commands associated with executing the tool command. The method further includes generating a downlink sequence of one or more downlinks for communicating the set of one or more downlink commands to the downhole tool. The method further includes. providing the downlink sequence for transmitting to the downhole tool
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
76.
Methods for Determining Positions of Fluid Interfaces and Detecting Cement Setting in a Subterranean Wellbore
Methods for locating fluid interfaces in a cased wellbore include generating vibrations in the casing, thereby forming oscillations in the wellbore fluids and the casing. The oscillations are detected by a vibration detector. The oscillations are recorded by a data acquisition system. Mathematical processing of the oscillations by cepstrum analysis is performed to determine the depths of interfaces between fluids in the annulus. The methods may also be employed to determine the time at which a cement slurry begins to set and harden. The methods may be performed in real time.
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 47/005 - Surveillance ou contrôle de la qualité ou du niveau de cimentation
A downhole tool includes a base pipe defining a base pipe passageway, a centralizer coupled to the base pipe, a seal coupled to the base pipe, and a two-stage deployment system configured to deploy the centralizer and the seal. The two-stage deployment system includes a centralizer piston disposed about the base pipe and coupled to the base pipe via a first shear mechanism having a first shear limit. The two-stage deployment system includes a seal piston coupled to the centralizer piston via a second shear mechanism having a second shear limit greater than the first shear limit. The base pipe defines a first port through which pressure from the base pipe passageway is configured to activate the centralizer piston. The base pipe defines a second port through which the pressure is configured to activate the seal piston separately from the activation of the centralizer piston.
E21B 23/01 - Appareils pour déplacer, mettre en place, verrouiller, libérer ou retirer, les outils, les packers ou autres éléments dans les trous de forage pour ancrer les outils ou similaires
E21B 21/10 - Aménagements des vannes dans les systèmes de circulation des fluides de forage
E21B 43/12 - Procédés ou appareils pour commander l'écoulement du fluide extrait vers ou dans les puits
E21B 34/08 - Aménagements des vannes pour les trous de forage ou pour les puits dans les puits sensibles à l'écoulement ou à la pression du fluide obtenu
A method may include generating results for one or more layers of a computational framework; combining the results to generate an optimal operating window (OOW) for drilling operations; and controlling equipment to perform one or more of the drilling operations based on the optimal operating window.
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
G06F 18/2321 - Techniques non hiérarchiques en utilisant les statistiques ou l'optimisation des fonctions, p. ex. modélisation des fonctions de densité de probabilité
G06F 18/22 - Critères d'appariement, p. ex. mesures de proximité
A cutting element may include a polycrystalline diamond (PCD) table including an apexed working surface. A cutting element may include a body including a non-diamond body material bonded to the PCD table, wherein a PCD height of the PCD table is no less than 40% of a cutting element height including the PCD table and body.
E21B 10/55 - Trépans caractérisés par des parties résistant à l'usure, p. ex. des diamants rapportés le trépan étant du type racleur, p. ex. trépan du type à fourche comportant des éléments de coupe préformés
E21B 10/567 - Parties rapportées du type bouton comportant des éléments de coupe préformés montés sur un support distinct, p. ex. parties rapportées polycristallines
E21B 10/52 - Trépans caractérisés par des parties résistant à l'usure, p. ex. des diamants rapportés le trépan étant du type à organes coupants roulants avec des parties rapportées du type ciseau ou bouton
B24D 3/10 - Propriétés physiques des corps ou feuilles abrasives, p. ex. surfaces abrasives de nature particulièreCorps ou feuilles abrasives caractérisés par leurs constituants les constituants étant utilisés comme agglomérants et étant essentiellement inorganiques métalliques à structure poreuse ou alvéolaire, p. ex. pour utiliser avec des diamants en tant qu'abrasifs
B24D 99/00 - Matière non prévue dans les autres groupes de la présente sous-classe
A spring shoulder kit includes an expanding shoulder and a retaining sleeve. The expanding shoulder includes a wedge outwardly radially extending from a radially flexible finger. The retaining sleeve is slidably insertable into the expanding shoulder to block inward radial movement of the wedge.
F16L 37/098 - Accouplements du type à action rapide dans lesquels l'assemblage entre les extrémités s'aboutant ou se chevauchant est maintenu par des organes de blocage combinés à un verrouillage automatique au moyen de crochets flexibles
F16L 37/091 - Accouplements du type à action rapide dans lesquels l'assemblage entre les extrémités s'aboutant ou se chevauchant est maintenu par des organes de blocage combinés à un verrouillage automatique au moyen d'une bague pourvue de dents ou de doigts
A device may include a body having a longitudinal axis. A device may include a deployable steering pad radially movable relative to the body, wherein the deployable steering pad has a retracted state defining a retracted radius from the longitudinal axis and a deployed state defining a deployed radius from the longitudinal axis. A device may include a kicker plate connected to the body longitudinally adjacent to the deployable steering pad, wherein the kicker plate has a kicker radius from the longitudinal axis greater than the retracted radius. A device may include a cutting element positioned on the kicker plate and defining a cutting radius between the retracted radius and the deployed radius.
A wellbore seal includes a eutectic plug and a gauge assembly. The eutectic plug is configured to sealably engage a casing or a formation. The gauge assembly is connected to a lower side of the eutectic plug. The gauge assembly includes a pressure gauge configured to measure a pressure of a fluid, and an acoustic transceiver in communication with the pressure gauge and configured to transmit an acoustic signal based on the pressure through the eutectic plug.
E21B 47/14 - Moyens pour la transmission de signaux de mesure ou signaux de commande du puits vers la surface, ou de la surface vers le puits, p. ex. pour la diagraphie pendant le forage utilisant des ondes acoustiques
83.
FORMATION CHARACTERIZATION USING IMAGES OF WET AND DRY CUTTINGS PARTICLES
A method for estimating a characteristic of cuttings particles obtained from a subterranean formation during a drilling operation includes measuring at least first and second bidirectional reflectance distribution functions (BRDFs) of cuttings particles acquired during a drilling operation, the first BRDF measured when the cuttings particles are wet and the second BRDF measured when the cuttings particles are dry and estimating the characteristic of the cuttings particles from the first and second BRDFs.
E21B 47/002 - Relevés dans les trous de forage ou dans les puits par inspection visuelle
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
G01B 11/30 - Dispositions pour la mesure caractérisées par l'utilisation de techniques optiques pour mesurer la rugosité ou l'irrégularité des surfaces
A method can include receiving seismic data from a seismic survey of a subsurface geologic environment that includes one or more reflectors; performing a model-based iterative least squares inversion of the seismic data; for at least one iteration of the model-based iterative least squares inversion, determining a value of a regularization parameter by approximating a first function representative of a residuals norm and a second function representative of a solution norm, where the first function and the second function depend on the regularization parameter; and performing a subsequent model-based iterative least squares inversion of the seismic data using the regularization parameter to determine a position of at least one of the one or more reflectors.
The disclosed methods and systems are directed to water flooding optimizations at a resource site for increased production of hydrocarbons. According to some implementations, the methods include receiving at least one of: fluid production rate data and fluid injection rate data using one or more sensors at a resource site. The methods may also include generating a forecasting model based on one or more of the fluid production rate data and the fluid injection rate data. The disclosed methods further comprise executing, using the forecasting model, one or more sensitivity tests to generate a production forecast report.
E21B 47/08 - Mesure du diamètre ou des dimensions correspondantes des trous de forage
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
A method can include applying a carbon nanotubule coating to one or more components of a fiber optics cable assembly; deploying the fiber optics cable assembly in a downhole environment; and utilizing the fiber optics cable assembly in the downhole environment and a fiber optics cable assembly can include components, where the components include at least one optical fiber; and one or more carbon nanotubule coatings disposed on at least one of the components.
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
E21B 47/007 - Mesure des contraintes dans le cuvelage ou la tige de forage
A method can include receiving a seismic model for a geologic region, where the seismic model includes an acoustic portion that accounts for wavefield kinematics using one or more acoustic velocity parameters and an elastic portion that accounts for wavefield elastic plane-wave reflectivity using one or more elastic vector reflectivity parameters; performing a wavefield simulation using the seismic model; during the wavefield simulation, determining angle dependent wavefield amplitude correction terms, subject to one or more structural dip-based angle criteria, using the elastic portion of the model; during the wavefield simulation, applying the angle dependent wavefield amplitude correction terms to wavefield amplitudes of the wavefield simulation to enhance seismic energy-based accuracy of the wavefield simulation; and generating a simulated wavefield as an output of the wavefield simulation.
A quick disconnect system. The quick disconnect system may include a head, a base, and a seal positioned between the head and the base. The head may include a receptacle and a channel having a locking portion. The base may include a sealing portion sized to be positioned within the receptacle of the head, a pin extending radially from the sealing portion of the base, and a locking nut. The pin may be sized to be positioned within the channel of the head such that relative rotation of the head and the base positions the pin within the locking portion. The locking nut may be positioned on a threaded portion of the base such that, when the pin is positioned within the locking portion of the channel, tightening the locking nut compresses the pin against a wall of the channel to prevent separation of the base and the head.
E21B 17/046 - AccouplementsJoints entre tige et trépan, ou entre tiges avec nervures, goupilles ou mâchoires et rainures complémentaires ou similaires, p. ex. accrochage à baïonnette
E21B 43/12 - Procédés ou appareils pour commander l'écoulement du fluide extrait vers ou dans les puits
A boost system for a hoisting system includes a track configured to couple to a mast. The boost system also includes a boost assembly with an upper climb unit with a respective hook configured to selectively engage openings in the track, a lower climb unit with a respective hook configured to selectively engage the openings in the track, and a boost actuator configured to drive the upper climb unit along the track and relative to the lower climb unit to provide a supplemental force to a yoke of the hoisting system.
A method may include generating an optimal operational window (OOW) that specifies operational parameter values for drilling operations using equipment at a rig site, based on data indicative of rig state and formation characteristics, and based on mutation-based optimization of the operational parameter values; and instructing a control system to perform the drilling operations according to the OOW using the equipment at the rig site.
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
The present disclosure relates to systems and methods for using an application programming interface to connect with a data engine. The application programming interface uses a messaging software development kit that receives a request for the data engine and converts the request into a message in a format compatible with the data engine. The messaging software development kit facilitates communication with the data engine from the application programming interface.
Systems and methods presented herein are configured to optimize the design and validation of coiled tubing strings. For example, a processing workflow may include generating a mission profile for a coiled tubing (CT) string for deployment in a well based on CT analytics. The processing workflow may also include creating a CT string design for the CT string based at least in part on a plurality of operational parameters of the well. The CT string design of the CT string defines a plurality of physical characteristics of the CT string. The processing workflow may further include adjusting one or more of the plurality of physical characteristics of the CT string design of the CT string based at least in part on the generated mission profile for the CT string and a predicted life cycle of the CT string.
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 19/22 - Manipulation de tubes ou de tiges enroulés, p. ex. de tubes de forage flexibles
A system for creating a tortuous flow path is disclosed. The system includes a production zone, and a man-made impermeable barrier disposed along a fluid flow path to the production zone to create tortuous flow path for a fluid flowing between the injection zone and the production zone.
E21B 21/14 - Procédés ou appareils pour nettoyer les trous de forage par jet de fluide, p. ex. en utilisant l'air d'échappement du moteur utilisant des liquides et des gaz, p. ex. des mousses
A geopolymer slurry includes comprising at least one aluminosilicate source including an amorphous aluminosilicate material, an activator, a fluid loss control material including a crosslinked polymer, and an aqueous base fluid. The crosslinked polymer includes a reaction product of one or more monomers including one or more of acrylamide, 2-acrylamido-2-methyl propane sulfonic acid, N,N‑dimethylacrylamide, N,N‑diethylacrylamide, vinyl acetate, or another monomer, and a crosslinker including one or more of methylene bisacrylamide, triallyl amine, pentaerythritol allyl ether, triallyl-triazine-trione, or another material. Related geopolymer compositions and methods of cementing a subterranean borehole are also disclosed.
C04B 28/00 - Compositions pour mortiers, béton ou pierre artificielle, contenant des liants inorganiques ou contenant le produit de réaction d'un liant inorganique et d'un liant organique, p. ex. contenant des ciments de polycarboxylates
C09K 8/487 - Additifs régulant les pertes de fluideAdditifs pour réduire ou empêcher la perte de circulation
A system for creating a tortuous flow path is disclosed. The system includes a production zone, and a man-made impermeable barrier disposed along a fluid flow path to the production zone to create tortuous flow path for a fluid flowing between the injection zone and the production zone.
Embodiments presented provide for an arrangement and method of using a static mixer in heat exchanging wellbores. In embodiments, a high-efficiency geothermal system is created that allows a static mixer to be used in conjunction with a power production system that creates an efficient power production cycle with reduced maintenance and efficiency greater than conventional systems.
F24T 10/20 - Collecteurs géothermiques utilisant l’eau souterraine comme fluide vecteurCollecteurs géothermiques utilisant un fluide vecteur injecté directement dans le sol, p. ex. utilisant des puits d’injection et des puits de récupération
Systems and methods disclosed herein are generally directed to an interpretation system that may receive measurements from multi-finger caliper tools and output various properties of a wellbore based on the measurements and/or models (e.g., computer models having algorithms) associated with the multi-finger caliper tools. For example, the interpretation system may generate and output defect maps (e.g., maps of defects according to axial position and circumferential position) based on an interpretation of the measurements. In another example, the interpretation system may determine a state of the wellbore based on the interpretation. If the state is clear, then the interpretation system may instruct one or more components of the hydrocarbon well site to initiate production operations. If the state is not clear (e.g., corrosion), then the interpretation system may identify an interval of interest within the wellbore and/or perform a corrective action at the interval of interest.
E21B 47/08 - Mesure du diamètre ou des dimensions correspondantes des trous de forage
G01B 3/38 - Calibres à mâchoire ouverte et faces opposées, c.-à-d. compas à calibrer, où la distance interne entre les faces est fixe, mais peut être réglée à l'avance
G01B 5/12 - Dispositions pour la mesure caractérisées par l'utilisation de techniques mécaniques pour mesurer des diamètres des diamètres intérieurs
A method for determining a recalibration trigger for a downhole survey sensor includes obtaining historical calibration and recalibration data for a plurality of downhole survey sensors. The historical calibration data is evaluated to determine calibration changes for selected ones of the survey sensors. A probabilistic model is constructed from the determined calibration changes over a predetermined range of temperatures and benchmarked against at least one industry standard to estimate the recalibration trigger.
A method for generating a segmented image of cuttings particles includes acquiring and preparing the cuttings particles for imaging and placing the prepared cuttings particles in front of a digital camera. At least three digital images of the cuttings particles are acquired at corresponding non-coplanar illumination angles and then combined to generate a photometric stereo image of the cuttings particles. The segmented image may be generated from the photometric stereo image.
G01N 1/08 - Dispositifs pour prélever des échantillons à l'état solide, p. ex. par coupe à l'outil impliquant un outil d'extraction, p. ex. mèche cylindrique creuse ou trépan
G06T 7/174 - DécoupageDétection de bords impliquant l'utilisation de plusieurs images
G06T 7/187 - DécoupageDétection de bords impliquant des croissances de zonesDécoupageDétection de bords impliquant des fusions de zonesDécoupageDétection de bords impliquant un étiquetage de composantes connexes
100.
MULTI-CHANNEL ACOUSTIC RECEIVER FOR ACOUSTIC COMMUNICATION NETWORK
A wireless communications system includes a network of acoustic modems for communicating messages between downhole equipment and a surface control and telemetry system. The acoustic modems include multi-channel acoustic receivers that are uniquely deployed along an acoustic transmission medium to provide spatial diversity. Acoustic signals received on the multiple receiver channels are combined and filtered using a Bayesian-type filter to reduce noise.
E21B 47/16 - 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 le long du train de tiges ou du tubage
G01V 1/22 - Transmission des signaux sismiques aux appareils d'enregistrement ou de traitement
