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
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
4.
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 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.
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.
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.
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 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
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
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
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
13.
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
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 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
16.
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.
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 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
19.
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
21.
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 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 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 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
25.
CONTRA ROTATING ELECTRIC SUBMERSIBLE PUMPING SYSTEMS AND METHODS
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
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
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.
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
29.
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
30.
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
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
37.
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
49.
STATIC MIXER AS HEAT EXCHANGE ENHANCER FOR ENHANCED AND ADVANCED GEOTHERMAL APPLICATION
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
53.
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
Systems and techniques are provided for seismic acquisition operations. The displacements among activation positions of the seismic sources are random values or selected from a predefined list to accelerate progress to cover the area of interest. Regular or irregular perturbations (e.g., random values or selected from a predefined list) in a crossline direction are used for source line spacings and sail line move ups. The source line spacings are fixed or varied with respect to time during the seismic survey. The seismic sensors are spaced at regular or irregular intervals. Complete coverage are attained by performing interpolation techniques to the acquired seismic data. An image reconstruction from the collected seismic survey data, which are processed with compressive sensing techniques before the reconstruction, are generated based in part on an inversion technique or an imaging algorithm.
Systems and methods presented herein provide for well decommissioning in through-tubing applications. A carrier for well decommissioning in through-tubing applications, can comprise a perforating assembly that includes at least one of (1) gun charges, and (2) a mechanical cutting device. The carrier can also include a sensor package that determines geometry of tubulars installed in a wellbore, including eccentricity of the tubulars. The carrier can further include an orienting device that orients the carrier to control the perforating assembly. The carrier can also include a roller assembly that allows the carrier to move longitudinally and rotate around a central axis.
A method can include acquiring motion sensor data using a motion sensor at a motion sensor location of a tool string disposed in a borehole during a field operation; transmitting the motion sensor data to transfer function circuitry of the tool string; operating the transfer function circuitry to apply a transfer function to the motion sensor data to determine one or more of lateral displacement and velocity at a location of the tool string that is a distance from the motion sensor location; and characterizing sensor data acquired by a sensor at the location using at least one of the one or more of the lateral displacement and the velocity.
E21B 47/0228 - Détermination de l'inclinaison ou de la direction du trou de forage, p. ex. à l'aide de géomagnétisme utilisant l'énergie électromagnétique ou des détecteurs y étant adaptés
A safety valve of a well string may include a fluid conduit, disposed about an axis, for conveying a fluid through the safety valve and a valve closure member articulatable between a first state and a second state to selectively block a flow of the fluid through the fluid conduit. The safety valve may also include a power spring to bias the valve closure member toward the first state via a power spring force, a piston to operatively overcome the power spring force and articulate the valve closure member toward the second state, and an adjustable stop disposed at one of multiple different positions within the safety valve such that the power spring is compressed between the piston and the adjustable stop. Moreover, the power spring force may be different at the different positions of the adjustable stop.
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
58.
BORHOLE CORRECTION OF FORMATION PHOTOELECTRIC FACTORS
A method for correcting photoelectric logging measurements includes acquiring a photoelectric factor image including photoelectric factor measurements in at least first and second azimuthal sectors in a borehole. The photo electric factor image is processed using a system of equations to compute a photoelectric factor of a formation through which the borehole penetrates and photoelectric factor of the drilling fluid in the borehole.
G01V 5/12 - Prospection ou détection au moyen de rayonnement ionisant, p. ex. de la radioactivité naturelle ou provoquée spécialement adaptée au carottage en utilisant des sources de radiation nucléaire primaire ou des rayons X en utilisant des sources de rayons gamma ou de rayons X
E21B 47/024 - Détermination de l'inclinaison ou de la direction des dispositifs dans le trou 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 rotating control device (RCD) for a drilling system includes an outer housing, a seal element positioned within the outer housing and configured to form an annular seal about a tubular, and a damper assembly positioned with the outer housing and configured to dampen forces exerted on the seal element as the tubular rotates, moves axially, or both.
A technique facilitates cooling of a motor protector which may be used in an electric submersible pumping system having a submersible pump powered by a submersible motor. The motor protector may be constructed with a plurality of thrust bearing chambers which can be at least partially filled with an internal motor fluid. Each thrust bearing chamber has a thrust bearing positioned to absorb loads generated during operation of the submersible pump. Additionally, the motor protector comprises an enhanced cooling system to facilitate improved removal of heat created at the thrust bearings. The enhanced cooling system may comprise various components which help transfer heat away from the thrust bearing chambers.
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 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 43/12 - Procédés ou appareils pour commander l'écoulement du fluide extrait vers ou dans les puits
A technique facilitates handling of thrust loads in a pump, such as a submersible pump which may be used in an electric submersible pumping system. For example, the submersible pump may comprise a plurality of pump stages disposed within an outer pump housing. Individual pump stages of the plurality of pump stages each have an impeller and a diffuser with the impeller being rotatable relative to the diffuser via a shaft. Each individual pump stage also comprises a stage thrust bearing assembly to handle thrust loads generated during operation of the submersible pump via rotation of the 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
F04D 29/54 - Moyens de guidage du fluide, p. ex. diffuseurs
62.
AUTONOMOUS OILFIELD PRODUCTION INTEGRATED CONTROL SYSTEM
A method can include receiving workflow specifications for an operational workflow performed using equipment in a field to produce hydrocarbons; configuring a dynamic reservoir simulation system according to the workflow specifications; receiving, by the dynamic reservoir simulation system, field data from the equipment; responsive to receipt of the field data, updating a model representative of one or more hydrocarbon production related physical phenomena in the field to generate an updated model of the dynamic reservoir simulation system; generating model-based results using the updated model; assessing quality of the model-based results to generate one or more quality metrics; and outputting, based at least in part on the model-based results, a control action for the operational workflow and at least one of the one or more quality metrics.
A method can include receiving seismic data-based interpretations for discontinuities in a subsurface geologic region; automatically assessing the interpretations, with respect to a type of action for joining individual pairs of the discontinuities, to generate ranked individual pairs of the discontinuities; and performing the type of action for joining a number of the ranked individual pairs of the discontinuities to improve accuracy of a model of the subsurface geologic region.
A bit includes a matrix body including a matrix material that is a matrix material powder bound by an infiltrant. An integral metallic connection includes a matrix portion embedded in the matrix body and a connection portion extended from the matrix body. The connection portion and the matrix portion are integrally formed with each other. The integral metallic connection has a treated strength that is greater than or equal to 90 ksi. The integral metallic connection allows for a drill bit connection to a drill string without the usage of a joining methods (2-piece construction) typical for matrix body bit constructions.
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
The present disclosure relates to a shaped charge liner. The shaped charge liner includes a first liner portion formed a first material. The first liner portion has an apex and a skirt section that define an interior volume of the first liner portion. The shaped charge liner also includes a second liner portion formed of a second material. The second liner portion is coupled to the first liner portion such that the second liner portion is an edge of the interior volume.
The effectiveness of expansive cement systems may be diluted when, during a well cementing operation, commingling takes place between the cement slurry and a spacer fluid, a drilling fluid, or both. Incorporating expansive agents in the spacer fluid or drilling fluid may reduce or negate the loss of expansion at the cement slurry/spacer interface or the cement slurry/drilling fluid interface, thereby promoting zonal isolation throughout the cemented interval.
C09K 8/48 - Additifs pour l'augmentation de la densité ou du poids
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
67.
DEVICES, SYSTEMS, AND METHODS OF A CUTTING ELEMENT IN A BIT
A cutting element may include a substrate having a base. A cutting element may include an ultrahard layer bonded to the substrate, the ultrahard layer formed from an ultrahard material, the ultrahard layer including: a side surface adjacent to the base, the side surface including a plurality of cutting surfaces; and an upper surface extending into the ultrahard layer.
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 10/43 - 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
68.
SYSTEMS AND METHODS FOR ANALYSIS OF DRILLING FLUID
A method of operating a drilling fluid analysis system includes obtaining multiple samples of a drilling fluid at different times over a time period. The method also includes placing the multiple samples into a capillary electrophoresis device. The method further includes determining a respective concentration of a component in each of the multiple samples of the drilling fluid with the capillary electrophoresis device.
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.
A method for designing, monitoring, and updating a trajectory of a wellbore at a wellsite. The method includes receiving a plurality of inputs related to the trajectory for the wellbore. The inputs may include a starting point of the trajectory. A zone may be defined within a subsurface beneath the wellsite as safe. The method further includes defining a first set of control points within the zone of the subsurface, and generating a proposed path of the trajectory by connecting the starting point of the trajectory to a plurality of trajectory targets via the first set of control points. The method also includes validating that the proposed path of the trajectory is within the zone of the subsurface.
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 device may include an inner shell including an inner groove having an inner groove angle relative to the rotational axis. A device may include an intermediate shell circumferentially around the inner shell and having a slot therein, the slot being at least partially oriented in a longitudinal direction of the rotational axis. A device may include an outer shell circumferentially around the intermediate shell and including an outer groove having an outer groove angle relative to the rotational axis different from inner groove angle. A device may include a bearing positioned in the slot and contacting the inner groove and the outer groove.
E21B 4/00 - Moyens d'entraînement dans le trou de forage
F16H 13/08 - Transmissions pour transmettre un mouvement rotatif à rapport de vitesse constant par friction entre des organes rotatifs avec organes à mouvement orbital avec billes ou rouleaux agissant de manière analogue
72.
Identification and mitigation of whirl within a drilling system
Whirl in a drilling system may be identified and mitigated by monitoring signals from a plurality of sensors positioned at various axial locations along a drill string of the drilling system, determining a respective frequency component and a respective amplitude component for each of the signals, identifying whirl in the drill string based on at least two of the respective frequency components and their respective amplitude components, and mitigating the whirl by introducing noise into the drilling system to reduce or eliminate the whirl without removing the drill string from a bottom of a borehole and without terminating all rotation of the drill string.
A method may include receiving a selection of a command of a plurality of commands, where the command is part of the plurality of commands and is associated with controlling one or more operations of a downhole tool, and where the plurality of commands is organized according to a JavaScript Object Notation (JSON) schema. The method may also include generating a downlink signal based on the command and transmitting the downlink signal to the downhole tool when the downhole tool is disposed within a wellbore of a geological formation, where the downhole tool is configured to implement a change in the one or more operations in response to receiving downlink signal. The method may further include receiving feedback data from the downhole tool after the downhole tool implements the command, where the feedback data includes one or more measurements associated with the downhole tool implementing the command.
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
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
A system may position a first polymer-bearing aqueous phase in a vessel. A system may flow a second polymer-bearing aqueous phase in the vessel, wherein the second polymer-bearing aqueous phase is immiscible with the first polymer-bearing aqueous phase and has a lesser density, to form an aqueous biphasic system (ABS) with an interfacial zone therebetween. A system may position a polymerization initiator in the interfacial zone. A system may activate the polymerization initiator to cross-link polymers of at least one of the first polymer-bearing aqueous phase and the second polymer-bearing aqueous phase. A system may polymerize at least a portion of the interfacial zone to create a polymer film.
Methods and apparatus for treatment of hydrocarbon streams containing cuttings are described herein. The cuttings are treated in a treatment stage comprising a fluidized bed treater to reduce oil content of the cuttings to less than 1% by weight. The cuttings are provided to the treatment stage from a preparation stage that lowers oil content of the cuttings to a suitable range for the treatment stage and sizes the cuttings to a suitable dimension range for the treatment stage.
E21B 21/06 - Dispositions pour traiter les fluides de forage à l'extérieur du trou de forage
F26B 3/08 - Procédés de séchage d'un matériau solide ou d'objets impliquant l'utilisation de chaleur par convection, c.-à-d. la chaleur étant transférée d'une source de chaleur au matériau ou aux objets à sécher par un gaz ou par une vapeur, p. ex. l'air le gaz ou la vapeur s'écoulant à travers le matériau ou les objets à sécher de façon à les rendre lâches, p. ex. pour former un lit fluidisé
76.
LOGGING TOOLS THAT INCLUDE A DISTRIBUTED TENSOR RESISTIVITY LOGGING SYSTEM AND PROCESSES FOR ASSEMBLING AND USING SAME
Logging tools for through the drill string conveyance that include a distributed tensor resistivity logging tool and processes for assembling and using same. In some embodiments, the distributed tensor resistivity logging tool can include at least one transmitter module, at least one receiver module, and at least three additional modules connected to one another, wherein at least one of the three additional modules is located between the at least one transmitter module and the at least one receiver module.
E21B 47/002 - Relevés dans les trous de forage ou dans les puits par inspection visuelle
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
G01V 5/04 - Prospection ou détection au moyen de rayonnement ionisant, p. ex. de la radioactivité naturelle ou provoquée spécialement adaptée au carottage
77.
USE OF MACHINE LEARNING TECHNIQUES TO ENHANCE AND ACCELERATE INVERSION METHODS FOR THE INTERPRETATION OF DEEP DIRECTIONAL RESISTIVITY MEASUREMENTS
Systems and methods of the present disclosure include acquiring, via a resistivity logging tool of a wellsite system, deep directional resistivity measurement data relating to a subterranean formation, and processing, via a logging and control system, the deep directional resistivity measurement data using inversion algorithms to determine one or more properties of the subterranean formation, wherein processing the deep directional resistivity measurement data using the inversion algorithms includes utilizing machine learning algorithms.
G01V 3/38 - Traitement de données, p. ex. pour l'analyse, pour l'interprétation ou pour la correction
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
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
A system and method of centralizing a tool. The centralizer has a mandrel with a static housing and a dynamic housing positioned about the mandrel. A plurality of V segments, each V segment coupled to the static housing at a first end and the dynamic housing at a second end and shiftable from an undeployed position to a deployed position to centralize the tool. A piston assembly operable to shift the dynamic housing to shift the plurality of V segments from the undeployed position to the deployed position, a retention mechanism operable to prevent the plurality of V segments from shifting from the deployed position to the undeployed position. A flexible sleeve on the outer surface of the plurality of V segments that contacts the wellbore when the V segments are actuated.
Downhole tools and processes for using same to detect radiation via scintillation. In some embodiments, the downhole tool can be deployable in a wellbore that traverses a formation. The downhole tool can include a tool housing configured for movement within and along the wellbore. The downhole tool can include a radiation detector that includes a scintillator material disposed within the tool housing. The scintillator material can include a cerium-activated gadolinium pyrosilicate. In some embodiments, the cerium-activated gadolinium pyrosilicate can have a chemical formula of: (Gd1-x-yCexAy)2Si2O7, where: x can be equal to 0.001 to 0.08, y can be equal to 0 or can be a number from 0.0001 to 0.079, if y is >0, A can include at least one rare-earth element selected from the group consisting of: Sc, Y, La, Pr, Nd, Pm, Sm, Eu, Tb, Dy, Ho, Er, Tm, Yb, and Lu, and 1-x-y can be ≥0.92.
G01V 5/10 - Prospection ou détection au moyen de rayonnement ionisant, p. ex. de la radioactivité naturelle ou provoquée spécialement adaptée au carottage en utilisant des sources de radiation nucléaire primaire ou des rayons X en utilisant des sources de neutrons
G01T 1/202 - Mesure de l'intensité de radiation avec des détecteurs à scintillation le détecteur étant du cristal
80.
SUBMERSIBLE PUMPING SYSTEM HAVING STAGE ARCHITECTURE FOR LOWER FLOW RATE PUMPS
A technique facilitates pumping of fluid at a desired flow rate. A submersible pump may be used in, for example, an electric submersible pumping system to pump well fluids or other types of fluids. The submersible pump comprises at least one pump stage disposed within an outer pump housing. Each pump stage has an impeller and a diffuser, the impeller being rotatable relative to the diffuser to pump fluid through the submersible pump. Additionally, the submersible pump incorporates a space out mechanism between the outer pump housing and the at least one pump stage to reduce the pumping capacity of the submersible pump without reducing the external diameter of the outer pump housing.
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 system and method for using a toe valve assembly. The toe valve has a housing with fracturing ports. A fracturing sleeve can slide within the housing to open or close the fracturing ports. The fracturing sleeve can slide with a hydraulic system or a shifting tool. The hydraulic system has a hydraulic sleeve that will hydraulically actuate the fracturing sleeve. The shifting tool can manually shift the tool. The toe valve assembly has a seat within the housing that receives a ball to close the toe valve assembly.
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 34/06 - Aménagements des vannes pour les trous de forage ou pour les puits dans les puits
E21B 43/26 - Procédés pour activer la production par formation de crevasses ou de fractures
Systems and methods of the present disclosure provide controlled flowback of fluids for stress testing in wireline toolstrings. For example, a downhole toolstring may include a flow control device configured to receive a fluid from a subterranean formation. The flow control device includes a reciprocating pump having an upper drive unit flowline chamber and a drive unit piston. The flow control device also includes a hydraulic valve system configured to control a flow of a fluid into the upper drive unit flowline chamber. The flow control device further includes a control valve/relief valve (CV/RV) combination disposed between the hydraulic valve system and the upper drive unit flowline chamber. The flow control device also includes a mud valve system configured to control a flow of an injection fluid. The downhole toolstring also includes a control system configured to control flowback of the fluid.
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
83.
SOFTWARE EXPERTISE AND ASSOCIATED METADATA TRACKING
A method of logging software usage and tracking user subject matter expertise includes capturing a plurality of software logs from a plurality of extraction and production systems. The method also includes aggregating metadata from the plurality of software logs according to a plurality of categories. The method also includes receiving a search term at a user interface. The method also includes identifying a first user of the plurality of extraction and production systems based upon the search term. The method also includes determining that the first user has an expertise in a first of the categories in response to the metadata showing that the first user has spent more than a first predetermined amount of time working on files associated with the first category, or created or modified more than a first predetermined number of the files associated with the first category.
Embodiments presented provide for evaluating fracture characterization resulting from hydraulic fracturing. In embodiments, fiber-optic elements are placed in a wellbore and subjected to forces from a hydraulic fracture operation occurring within a geological stratum. Readings from the fiber-optic elements are taken and evaluated to form a fracture characterization of the geological stratum.
E21B 47/007 - Mesure des contraintes dans le cuvelage ou la tige de forage
E21B 43/26 - Procédés pour activer la production par formation de crevasses ou de fractures
E21B 47/002 - Relevés dans les trous de forage ou dans les puits par inspection visuelle
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
The present disclosure describes techniques including sampling a multidimensional physical space to determine representative combinations of pipeline segment parameters, and executing a flow simulator to estimate pressure drop values or pressure gradient values for pipeline segments having the representative combinations of pipeline segment parameters. The techniques also include training a ML model using the pressure drop values or the pressure gradient values estimated by the flow simulator. The ML model may output a predicted pressure drop value or pressure gradient value for a pipeline segment based on input values representing pipeline segment parameters of the pipeline segment. The techniques can also include upscaling a network model before executing a ML-based network solver to estimate a pressure drop value, a flow rate value, and node pressure values for the network model using the trained ML model.
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]
86.
CARBON DIOXIDE WELL INJECTION SIMULATION TECHNIQUES
Techniques for simulating carbon dioxide injection into a saline aquifer. The techniques include obtaining geological reference data that is correlated to a saline aquifer formation layer and establishing a set of carbon dioxide injection parameters to be tested. The simulation is computationally practical and efficient by mathematically partitioning the aquifer formation layer into a plurality of discrete partitions based on the geological reference data and utilizing fast analytical solutions to obtain relevant properties of interest within each partition. Thus, estimating carbon dioxide flow characteristics for each discrete partition of the plurality may take place based on the geological reference data and the carbon dioxide injection parameters.
Aspects of the disclosure relate to workflows and analytical methods for characterizing conventional and unconventional geological formation water saturation values through advanced laboratory measurements and correlation techniques of nuclear magnetic resonance value ratios.
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
G01N 1/04 - Dispositifs pour prélever des échantillons à l'état solide, p. ex. par coupe à l'outil
G01N 1/44 - Traitement d'échantillons mettant en œuvre un rayonnement, p. ex. de la chaleur
G01R 33/50 - Systèmes d'imagerie RMN basés sur la détermination des temps de relaxation
A method implements an informed feature extraction foundation model. The method involves processing a reference image and a target image using a feature encoder model to generate feature encoder output. The method further involves processing a reference mask using a prompt encoder model to generate a prompt encoder output. The method further involves processing the feature encoder output and the prompt encoder model output using a mask decoder model to generate a target mask.
G06V 10/26 - Segmentation de formes dans le champ d’imageDécoupage ou fusion d’éléments d’image visant à établir la région de motif, p. ex. techniques de regroupementDétection d’occlusion
G06V 10/25 - Détermination d’une région d’intérêt [ROI] ou d’un volume d’intérêt [VOI]
G06V 10/77 - Traitement 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
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
An embodiment of a method for unsupervised analysis of borehole image data is provided in which a borehole image is divided into a plurality of image patches, and missing or degraded measurements within at least a portion of the image patches are reconstructed. The method further provides for generating feature embeddings for the reconstructed image patches and processing to enable grouping of image patches that exhibit similar geological texture characteristics. The resulting group assignments are then mapped back to depth-indexed intervals of the borehole image, thereby producing an automated representation of recurring geological textures without requiring labeled training data.
A method can include receiving seismic data from a seismic survey of a subsurface environment, where the seismic data include indicia of primary reflections and multiple reflections; receiving a multiple model indicative of multiple reflections in the subsurface environment; generating difference values using an unsupervised machine learning model, where the difference values represent differences between the multiple reflections of the seismic data and the multiple reflections of the multiple model; and generating a refined multiple model using the difference values, where the refined multiple model provides for more accurate characterization of locations of structural features in the subsurface environment.
A system including computer-readable storage media and a processing system configured to execute instructions stored on the computer-readable storage media. Executing the one or more instructions causes the processing system to process a request to predict one or more parameters associated with a geological region; access a physics-based model associated with a downhole operation, the geological region, or both; and integrate the physics-based model with a neural network model to generate a physics-informed neural network (PINN) model associated with the downhole operation in the geological region.
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
E21B 47/12 - Moyens pour la transmission de signaux de mesure ou signaux de commande du puits vers la surface, ou de la surface vers le puits, p. ex. pour la diagraphie pendant le forage
A rotating control device (RCD) for use during a drilling operation includes a bearing assembly. The bearing assembly includes a bearing body. The bearing assembly also includes a bearing housing positioned around the bearing body. The bearing assembly also includes a load ring positioned around the bearing housing. The load ring includes a tapered surface. The bearing assembly also includes a seal positioned below the load ring. The RCD also includes a landing adapter positioned around the bearing housing, above he bearing housing, or both. The landing adapter is positioned above the seal and the load ring. The RCD also include an RCD housing positioned at least partially around the bearing assembly and the landing adapter. The bearing assembly and the landing adapter are configured to rotate with respect to the RCD housing.
The invention relates to an arrangement of at least one first solid oxide electrochemical system (100) inside a casing (10), the at least one first electrochemical system having a plurality of at least two stacks (111, 121) of single repeat units (SRU), and a fluid collection box (150), characterized in that: - the plurality of at least two stacks is divided into a first subsystem (110) of stacks (111), held against and connected to the upper face of the fluid collection box, and into a second subsystem (120) of stacks (121), held against and connected to the lower face of the fluid collection box; - the fluid collection box (150) is engaged with the two side walls (16) of the casing (10); such that the first electrochemical system (100) is suspended inside the casing (10).
The invention relates to a facility (1) for producing hydrocarbon compounds comprising a heating device (2), an electrochemical device (3) and a hydrocarbon compound production device (6) configured to produce hydrocarbon compounds from an internal fluid of the electrochemical device (3) comprising dihydrogen and an inlet fluid comprising carbon dioxide. The facility is also designed to recover at least a portion of the waste heat released by the hydrocarbon compound production device (6) and to transfer it to the heating device (3).
A method and system for designing a well casing for a target site includes receiving an information set for the target site and generating a plurality of well casing designs for the target site. Each well casing design includes a combination of a selected materials, casing sizes, casing grades, casing weights, and lengths for a set of well casing components. The method then generates a set of estimated loads for the well casing at the target site based on historical data. The set of estimated loads including a collapse load, a burst load, a tension load, a compression load, and a triaxial load. Each of the plurality of well casing designs are tested based on the estimated loads and a list of recommended well casing designs that withstood the set of estimated loads and a higher threshold of loads is generated and a recommended well design is output.
Techniques for training a global model for use at a host of oilfield application sites based on raw data obtained from the application sites without direct exposure of the data to the global model. The techniques include developing and distributing a global model with a predetermined set of parameter weights. The model is then locally employed at each application site by a local computer which maintains the integrity of the acquired data during performance of the oilfield application. The data is used to update the parameter weights based on real-time circumstances. Thus, the parameter weights may be transmitted to the centralized computer for updating of the global model. Further, the updated global model may continue to direct other applications and the process continued in a beneficial feedback loop manner.
Techniques for simulating carbon dioxide injection into a saline aquifer. The techniques include obtaining geological reference data that is correlated to a saline aquifer formation layer and establishing a set of carbon dioxide injection parameters to be tested. The simulation is computationally practical and efficient by mathematically partitioning the aquifer formation layer into a plurality of discrete partitions based on the geological reference data and utilizing fast analytical solutions to obtain relevant properties of interest within each partition. Thus, estimating carbon dioxide flow characteristics for each discrete partition of the plurality may take place based on the geological reference data and the carbon dioxide injection parameters.
E21B 43/16 - Procédés de récupération assistée pour l'extraction d'hydrocarbures
E21B 43/30 - Disposition particulière des puits, p. ex. disposition rendant optimum l'espacement des puits
G06Q 10/04 - Prévision ou optimisation spécialement adaptées à des fins administratives ou de gestion, p. ex. programmation linéaire ou "problème d’optimisation des stocks"
Techniques for simulating carbon dioxide injection into a saline aquifer. The techniques include obtaining geological reference data and establishing carbon dioxide injection parameters. With this data and parameters in mind, a node-based resistance grid may be established that is used to schematically generate flowlines across the saline aquifer. From the flowlines, tessellated partitions may be developed and potentially subdivided into manageable platonic shape portions. Thus, a mathematical manner of estimating flow characteristics for the proposed injection application may be simulated in a fast and reliable manner.
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
E21B 43/16 - Procédés de récupération assistée pour l'extraction d'hydrocarbures
A method including receiving input data, setting one or more static properties based on the input data, providing the one or more static properties to a model of one or more components of an energy system, generating a plurality of performance curves, transmitting the plurality of performance curves for display via a graphical user interface (GUI), receiving, via the GUI, an input indicative of a selection of a mathematical model, engaging the selected mathematical model, generating, using the selected mathematical model, an allocation of energy to the one or more components of the energy system, and transmitting the allocation for display via the GUI. The input data may include one or more fixed data variables, one or more temporal data variables, or any combination thereof. Each performance curve of the plurality of performance curves may also correspond to a respective component of the one or more components.
H02S 50/00 - Surveillance ou tests de systèmes PV, p. ex. équilibrage de charge ou identification des défauts
H02S 10/10 - Centrales électriques PVCombinaisons de systèmes d’énergie PV avec d’autres systèmes pour la production d’énergie électrique comprenant une source supplémentaire d’énergie électrique, p. ex. systèmes hybrides diesel-PV
H02S 10/20 - Systèmes caractérisés par leurs moyens de stockage de l’énergie
H02S 40/44 - Moyens pour utiliser l’énergie thermique, p. ex. systèmes hybrides produisant de l’eau chaude et de l’électricité en même temps
G06F 3/048 - Techniques d’interaction fondées sur les interfaces utilisateur graphiques [GUI]
A method may include executing a computational framework to render a graphical user interface to a display that includes graphical controls for specification of bit design optimization properties for one or more formation types; executing multi-objective optimization code according to the bit design optimization properties to generate bit design genotypes; executing genotype-to-phenotype code to generate bit design phenotypes from the bit design genotypes; executing one or more simulators to generate simulation results for the bit design phenotypes; executing fitness vector generation code to generate a fitness vector for the simulation results; and executing the multi-objective optimization code using the fitness vector to generate a set of bit design genotypes.
