A downhole well tool includes a tubing including a circulation fluid pathway, a first packer, and a second packer positioned longitudinally apart from the first packer. The well tool includes a circulation sub connected to the tubing on a first longitudinal side of the second packer, the circulation sub including a first circulation port to fluidly couple the circulation fluid pathway to an annulus of the wellbore, and a plug seat positioned in the fluid circulation pathway. A second circulation port in the tubing is positioned longitudinally between the first packer and the second packer, and fluidly couples the circulation fluid pathway to the annulus of the wellbore between the first packer and the second packer. The second circulation port includes a frangible cover that plugs the second circulation port and ruptures in response to a burst pressure in the circulation fluid pathway.
E21B 33/138 - Plâtrage de la paroi du trou de forageInjections dans la formation
E21B 23/06 - Appareils pour déplacer, mettre en place, verrouiller, libérer ou retirer, les outils, les packers ou autres éléments dans les trous de forage pour le montage des packers
E21B 34/06 - Aménagements des vannes pour les trous de forage ou pour les puits dans les puits
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 47/117 - Détection de fuites, p. ex. du tubage, par test de pression
2.
FIRE RESISTANT COMPOSITE REBAR FOR CONCRETE STRUCTURES
A composition for producing a glass fiber reinforced cement rebar, the composition comprising glass fiber; and a binder, the binder impregnates the glass fibers to hold the glass fibers together, where the binder comprises a cementitious component and a non-cement component, where the non-cement component comprises graphene oxide.
C04B 20/00 - Emploi de matières comme charges pour mortiers, béton ou pierre artificielle prévu dans plus d'un groupe et caractérisées par la forme ou la répartition des grainsTraitement de matières spécialement adapté pour renforcer leur propriétés de charge dans les mortiers, béton ou pierre artificielle prévu dans plus d'un groupe de Matières expansées ou défibrillées
C04B 22/00 - Emploi de matières inorganiques comme ingrédients actifs pour mortiers, béton ou pierre artificielle, p. ex. emploi d'accélérateurs
C04B 24/26 - Composés macromoléculaires obtenus par des réactions faisant intervenir uniquement des liaisons non saturées carbone-carbone
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 40/02 - Choix de l'environnement pour le durcissement
C04B 111/00 - Fonction, propriétés ou utilisation des mortiers, du béton ou de la pierre artificielle
C04B 111/10 - Compositions caractérisées par l'absence d'un matériau spécifié
A ceiling system configured such that when a runner of a first panel assembly and a runner of a second panel assembly are each slidably disposed within a channel of a rail and the rail is attached to the support member, the first panel assembly and the second panel assembly are independently suspended by respective wires from the rail. Sliding the runner of the first panel assembly towards the runner of the second panel assembly translates the respective panels of the panel assemblies towards each other, thereby positioning an edge of the panel of the first panel assembly adjacent an edge of the panel of the second panel assembly for attachment, such that the second planar surface of the panel of the first planar assembly and the second planar surface of the panel of the second planar assembly at least partially define an interior surface of the ceiling.
E04B 9/22 - Fixation des dalles, feuilles ou similaires à la structure de support
E04B 9/04 - PlafondsStructure des plafonds, p. ex. faux plafondsStructure des plafonds en ce qui concerne l'isolation comprenant des dalles, des feuilles ou similaires
E04B 9/06 - PlafondsStructure des plafonds, p. ex. faux plafondsStructure des plafonds en ce qui concerne l'isolation caractérisés par les particularités de construction de la structure de support
E04B 9/30 - PlafondsStructure des plafonds, p. ex. faux plafondsStructure des plafonds en ce qui concerne l'isolation caractérisés par des détails de la bordure du plafond, p. ex. par la fixation à un mur adjacent
Systems and methods include obtaining well log data and core sample data of a subsurface formation; generating, based on the well log data and the core sample data, an unconfined compressive strength log for the subsurface formation; using an unsupervised machine learning model to form rock type clusters based on the unconfined compressive strength log and the well log data; forming a training dataset including the well log data, the training dataset labeled based on the rock type clusters; training a supervised machine learning model using the training dataset. While drilling a well in the subsurface formation, logging-while-drilling data is obtained from drilling equipment used to drill the well; and rock types in the subsurface formation are determined using the supervised machine learning model and the logging-while-drilling data.
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 44/00 - Systèmes de commande automatique spécialement adaptés aux opérations de forage, c.-à-d. systèmes à fonctionnement autonome ayant pour rôle d'exécuter ou de modifier une opération de forage sans l'intervention d'un opérateur humain, p. ex. systèmes de forage commandés par ordinateurSystèmes spécialement adaptés à la surveillance de plusieurs variables ou conditions de forage
E21B 45/00 - Mesure du temps de forage ou de la vitesse de pénétration
A method for determining an anomaly in a gas-lift system. The method includes obtaining gas-lift data from a gas-lift system and associated well, where the gas-lift system injects a gas into a fluid mixture of the well. The method further includes obtaining a set of operation parameters including an injected gas rate and an injected gas pressure. The method further includes determining, with a first machine learned model and a second machine learned model, a first and second anomaly metric each indicative of an anomaly in the gas-lift system or a flow of a production fluid from the well, respectively, based on the gas-lift data. The method further includes forming an aggregate anomaly prediction from the first anomaly metric and the second anomaly metric and adjusting, with a controller, the set of operation parameters based on, at least, the aggregate anomaly prediction.
A system includes an automatic computer-controlled management system and a compressed air system. The system includes a first standby compression generator pneumatically coupled to the compressed air system and coupled to the automatic computer-controlled management system. The system includes a second standby compression generator of a set of standby compression generators pneumatically coupled to the compressed air system and coupled to the automatic computer-controlled management system. The first standby compression generator is configured to transmit first standby compression generator data to the automatic computer-controlled management system and the second standby compression generator is configured to transmit second standby compression generator data to the automatic computer-controlled management system.
G05B 19/416 - Commande numérique [CN], c.-à-d. machines fonctionnant automatiquement, en particulier machines-outils, p. ex. dans un milieu de fabrication industriel, afin d'effectuer un positionnement, un mouvement ou des actions coordonnées au moyen de données d'un programme sous forme numérique caractérisée par la commande de vitesse, d'accélération ou de décélération
A system for conditioning a feed stream that may include a feed inlet, a cycloid pipe, a tangential inlet pipe, and a main pipe, wherein the main pipe and the cycloid pipe may be fluidly connected. The feed inlet may be configured to receive a feed stream including multiphase fluids.
A fluid velocity sensor can include a thermally conductive body comprising a first temperature sensor, a second temperature sensor, and a third temperature sensor. A heating element is secured within the fluid velocity sensor to heat the thermally conductive body. The first temperature sensor, the second temperature sensor, and the third temperature sensor each reside within the thermally conductive body at different radial distances from the heating element. A flowrate of a fluid in contact with the fluid velocity sensor is determined based on a comparison between the internal temperatures measured by each of the first, second, and third temperature sensors.
A method for determining and performing an optimum well intervention sequence on a well operation described by an operating condition. The method includes obtaining a first well data for the well operation and determining, using an artificial intelligence (AI) model with the first well data as input, a first operating condition for the well operation. The method further includes obtaining a plurality of well interventions that can be performed on the well operation, determining, using a reinforcement learning (RL) policy, an optimum well intervention sequence that optimizes a performance of the well operation and performing the optimum well intervention sequence on the well operation.
A pump cleaning assembly includes a ring assembly configured to be mounted at a seal nose coaxial with a shaft center-line of a pump shaft of a pump; a plurality of spring-loaded nozzles positioned in the ring assembly and configured to spray a pressurized liquid along the pump shaft within a pump housing of the pump; and a liquid pump fluidly coupled to the plurality of spring-loaded nozzles through a tubing assembly.
A method of recovering oil from a formation includes providing carbonated water in a lower zone of the formation, releasing carbon dioxide gas from the carbonated water to produce released carbon dioxide gas, causing the released carbon dioxide gas to contact oil in an upper zone of the formation to increase a mobility of the oil, and recovering the oil from the formation.
A system includes an inflow control device (ICD) that modulates an inflow of hydrocarbons within the wellbore and a sleeve. The sleeve is slidably disposed adjacent to the ICD and connected to an elastic material with a thermal memory. The elastic material changes its shape based on a change in temperature. Based on (i) the elastic material being in a compressed state below a temperature threshold and (ii) the sleeve being at a first position relative to the ICD, the elastic material allows a fluid communication between the ICD and outside the wellbore. Based on (i) the elastic material being in a stretched state at or above the temperature threshold and (ii) the sleeve being at a second position relative to the ICD, the elastic material blocks the fluid communication between the ICD and outside the wellbore.
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
13.
DETERMINING HYDRAULIC FRACTURING TREATMENT METHODS FOR WELLS IN CARBONATE RESERVOIRS
Techniques for stimulating a formation surrounding a wellbore include determining a rock type of the formation along the well trajectory in landing zone in terms of measured depth. A depth-specific acid fracture conductivity parameter of the formation and a depth-specific fracture conductivity declining parameter of the formation are determined. One or more depth intervals requiring fracturing are determined based on the rock type of the formation, the acid fracture conductivity parameter of the formation, and the fracture conductivity declining parameter of the formation. A fracturing method is determined for each depth interval of the one or more depth intervals based on the acid fracture conductivity parameter of the formation and the fracture conductivity declining parameter of the formation. A corresponding pump schedule of the fracturing method is determined, and a fluid of the pump schedule is pumped into the wellbore to fracture or stimulate the formation.
E21B 49/02 - Test pour déterminer la nature des parois des trous de forageEssais de couchesProcédés ou appareils pour prélever des échantillons du terrain ou de fluides en provenance des puits, spécialement adaptés au forage du sol ou aux puits par prélèvements mécaniques d'échantillons du terrain
E21B 43/26 - Procédés pour activer la production par formation de crevasses ou de fractures
A method, system, and non-transitory computer readable media for landcover map generation of an environment. The operations include receiving an image captured at an aerial position above the environment, obtaining coordinate information of the environment corresponding to pixels of the image, and determining coordinate measures. The operations include generating image patches, each image patch representing a portion of the pixels and applying image processing techniques to adjust pixel values of a respective image patch. The operations include providing the adjusted image patches to a generative adversarial network (GAN) and generating landcover map patches from the adjusted image patches. The GAN includes a generator network trained to generate training landcover map patches from an image patch and a discriminator network trained to classify training landcover map patches from the generator network. The operations include generating a landcover map from the landcover map patches and providing the landcover map for output.
G06T 7/579 - Récupération de la profondeur ou de la forme à partir de plusieurs images à partir du mouvement
G06T 7/593 - Récupération de la profondeur ou de la forme à partir de plusieurs images à partir d’images stéréo
G06T 17/20 - Description filaire, p. ex. polygonalisation ou tessellation
G06V 10/764 - Dispositions pour la reconnaissance ou la compréhension d’images ou de vidéos utilisant la reconnaissance de formes ou l’apprentissage automatique utilisant la classification, p. ex. des objets vidéo
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
G06V 10/98 - Détection ou correction d’erreurs, p. ex. en effectuant une deuxième exploration du motif ou par intervention humaineÉvaluation de la qualité des motifs acquis
G06V 20/70 - Étiquetage du contenu de scène, p. ex. en tirant des représentations syntaxiques ou sémantiques
15.
MODIFIED ZSM-5 FOR STEAM ENHANCED CATALYTIC CRACKING OF CRUDE OIL TO LIGHT OLEFINS AND AROMATICS
King Fahd University of Petroleum and Minerals (Arabie saoudite)
Inventeur(s)
Akah, Aaron Chi
Al-Ghrami, Musaed Salem
Aitani, Abdullah Mohammed
Qureshi, Ziyauddin
Siddiqui, Mohammed Abdul Bari
Abrégé
A process for upgrading a hydrocarbon feed comprises contacting the hydrocarbon feed with steam in the presence of a cracking catalyst composition at reaction conditions sufficient to cause at least a portion of hydrocarbons in the hydrocarbon feed to undergo one or more cracking reactions to produce a steam catalytic cracking effluent comprising light olefins, light aromatic compounds, or both, where the cracking catalyst composition comprises a cracking additive comprising metal species impregnated on a ZSM-5 zeolite, where the metal species comprises a metal selected from the group consisting of chromium, vanadium, iron, platinum, molybdenum, cerium, and nickel.
B01J 29/48 - Zéolites aluminosilicates cristallinesLeurs composés isomorphes du type pentasil, p. ex. types ZSM-5, ZSM-8 ou ZSM-11 contenant de l'arsenic, de l'antimoine, du bismuth, du vanadium, du niobium, du tantale, du polonium, du chrome, du molybdène, du tungstène, du manganèse, du technétium ou du rhénium
B01J 35/40 - Catalyseurs caractérisés par leur forme ou leurs propriétés physiques, en général caractérisés par leurs dimensions, p. ex. granulométrie
A process for a low-carbon footprint hydrogen production includes producing natural gas from a reservoir. The natural gas is sweetened to produce a sweet natural gas and an acid gas stream. The sweet natural gas is fed to a methane purification unit (31) and purified to remove residual hydrogen sulfide. The acid gas stream is fed to a carbon dioxide feed purification unit (32) and the carbon dioxide in the acid gas stream is purified. The purified methane (13), the purified carbon dioxide (15) and steam (16) are fed as reactants to a tri-reforming reactor (33), containing a tri-reforming catalyst, to produce a reaction effluent comprising hydrogen and carbon monoxide. An effluent is recovered from the tri-reforming reactor (33), which is then separated to recover a raw hydrogen stream and a raw carbon monoxide stream. The raw hydrogen stream is purified to recover a purified hydrogen stream, which is liquified to recover a liquid hydrogen product.
C01B 3/38 - Production d'hydrogène ou de mélanges gazeux contenant de l'hydrogène par réaction de composés organiques gazeux ou liquides avec des agents gazéifiants, p. ex. de l'eau, du gaz carbonique, de l'air par réaction d'hydrocarbures avec des agents gazéifiants avec des catalyseurs
C01B 3/06 - Production d'hydrogène ou de mélanges gazeux contenant de l'hydrogène par réaction de composés inorganiques comportant un hydrogène lié électropositivement, p. ex. de l'eau, des acides, des bases, de l'ammoniac, avec des agents réducteurs inorganiques
17.
SYNTHESIS OF POLYMERIC SURFACTANT AND ITS USE FOR ENHANCED OIL RECOVERY
ARAMCO FAR EAST (BEIJING) BUSINESS SERVICES CO., LTD. (Chine)
Inventeur(s)
Da, Chang
Zhang, Xuan
Han, Ming
Abrégé
A method of preparing a polymeric surfactant includes dissolving a sulfonic acid monomer in an aqueous fluid to form a sulfonic acid solution, adding an acrylic monomer and a surfactant monomer to the sulfonic acid solution to form a reactive mixture, adding one or more initiators to the reactive mixture to initiate a reaction in the reactive mixture, and allowing the reactive mixture to react, thereby forming the polymeric surfactant. A method of enhancing oil recovery in a reservoir includes preparing a polymeric surfactant formulation that comprises a polymeric surfactant and a treatment fluid, injecting the polymeric surfactant formulation into an injection well of the reservoir, contacting one or more hydrocarbons present in the reservoir with the polymeric surfactant formulation, thereby forming a hydrocarbon mixture, and extracting the hydrocarbon mixture from a production well of the reservoir.
C09K 8/588 - Compositions pour les méthodes de récupération assistée pour l'extraction d'hydrocarbures, c.-à-d. pour améliorer la mobilité de l'huile, p. ex. fluides de déplacement caractérisées par l'utilisation de polymères spécifiques
C09K 8/584 - Compositions pour les méthodes de récupération assistée pour l'extraction d'hydrocarbures, c.-à-d. pour améliorer la mobilité de l'huile, p. ex. fluides de déplacement caractérisées par l'utilisation de tensio-actifs spécifiques
E21B 43/16 - Procédés de récupération assistée pour l'extraction d'hydrocarbures
C08F 220/58 - Amides contenant de l'oxygène en plus de l'oxygène de la fonction carbonamide
An engine includes a first crankshaft and a second crankshaft, pistons, piston rods, cylinders, combustion chambers, and fuel injectors. The crankshafts each extend in a horizontal plane and form a first and second rotating power output shaft of the engine. The combustion chambers form containment boundaries for combustion reactions of an air-fuel mixture formed in the cylinders with fuel provided by the fuel injectors. The piston rods connect the pistons to the first or the second crankshaft. The pistons are disposed in the cylinders, and the planar surface of the piston head of each piston distributes forces from an associated combustion reaction to a corresponding piston rod. The piston heads are disposed at an angle between 7 and 15 degrees in the first bank of cylinders and −7 and −15 degrees in the second bank of cylinders relative to a vertical plane.
F01B 1/04 - "Machines" ou machines motrices à piston alternatif caractérisées par le nombre ou par la disposition relative des cylindres ou par le fait qu'elles sont construites à partir d'éléments cylindres-carter séparés avec cylindres disposés en V
F01B 9/02 - "Machines" ou machines motrices à piston alternatif caractérisées par des liaisons entre pistons et arbres principaux, non spécifiques aux groupes avec vilebrequin
F02B 75/22 - Moteurs polycylindriques avec les cylindres disposés en V, en éventail ou en étoile
19.
Methods and systems to stimulate rock surrounding a wellbore using ultrasound at a preferred frequency
Methods and systems are disclosed. The method may include obtaining, using a rock characterization system, a plurality of characteristics for a rock penetrated by a wellbore, and determining, using a model of poroelasticity and the plurality of characteristics, a preferred ultrasonic frequency at which to insonify the rock. The method may further include deploying an ultrasonic stimulation tool in the wellbore, where the ultrasonic stimulation tool comprises at least one ultrasonic transducer, and activating the ultrasonic stimulation tool at the preferred ultrasonic frequency.
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 28/00 - Dispositions pour la génération de vibrations pour les trous de forage ou les puits, p. ex. pour activer la production
A pump shaft stand for supporting a pump shaft while a pump is being serviced. The pump shaft stand includes a frame, a receptacle coupled with the frame, and an elevator for positioning the receptacle. The elevator is adjustable to place the receptacle in a designated position, so that when an end of the pump shaft is supported by the receptacle, the pump shaft does not move by an amount that can damage the shaft or associated components of the pump.
An arrangement of cancellation electromagnets control magnetic adhesion of a wheel to a surface. The wheel has an inner annular disc composed of a non-magnetic material with apertures which retain electromagnets and permanent magnets, and an outer annular disc composed of a ferromagnetic material which is disposed on a side of the inner annular disc, with a non-magnetic isolator ring having curves extending in a serpentine manner. In one embodiment, the curves isolate the electromagnets from the permanent magnets. In another embodiment, the outer annular disc is rotated relative to the inner annular disc to dispose the curves of the serpentine isolator ring in a second position to allow magnetic interaction between the electromagnets and the permanent magnets to generate a second magnetic flux between the permanent magnets and the ferromagnetic surface which decreases adhesion of the wheel to the ferromagnetic surface. A method implements the system.
B60B 19/00 - Roues non prévues ailleurs ou ayant des caractéristiques précisées dans l'un des sous-groupes du présent groupe
B60B 3/08 - Roues pleines, c.-à-d. roues avec corps en forme de disque supportant la charge avec un corps formé de plusieurs disques axialement espacés
B60B 27/02 - Moyeux adaptés pour tourner sur l'essieu
Systems, methods, and apparatus for characterizing reservoirs are discussed. As an example, a method for characterizing a reservoir is discussed that includes determining a ki parameter, a αE parameter, and a αP parameter based at least in part on the at least four pairs of effective stress and permeability; and predicting a hydrocarbon production rate from reservoir represented by the sample rock based at least in part on the ki parameter, the αE parameter, and the αP parameter.
Data processing systems and processing methods are configured to process geoscience data for a set of different data domains. The data processing systems described herein are configured to unify data sources from the set of different domains to process data in the context of each of the different domains of the set. The data processing system can use data, such as training data or trained model weightings, that are generated when performing a processing workflow in a first domain for updating how a second processing workflow is performed for a second, different domain, and vice versa. The data processing system can improve both processing workflows based on the contexts of the other workflow being performed.
Various systems and methods are discussed for characterizing well properties. As one of many non-limiting examples, a well property system is discussed that includes a sensor set, a logging system, an archive conversion system, and a well property prediction system. Each of the aforementioned components and systems may be configured to sense and/or operate on pressure, volume, and temperature data from at least one location at a well site.
G06V 30/416 - Extraction de la structure logique, p. ex. chapitres, sections ou numéros de pageIdentification des éléments de document, p. ex. des auteurs
25.
POLYVALENT METAL ION-CONTAINING ELECTROLYTE FOR RECHARGEABLE BATTERY
King Abdullah University of Science and Technology (Arabie saoudite)
Inventeur(s)
Alshareef, Husam Niman
Zhao, Zhiming
El-Demellawi, Jehad Khaled
Abrégé
An electrochemical cell for a rechargeable battery, where the electrochemical cell includes: an anode including lithium (Li); an anode current collector connected to the anode; a cathode; a cathode current collector connected to the cathode; a separator between the anode and the cathode; and a liquid electrolyte including: a solvent, a Li salt dissolved in the solvent, and a polyvalent metal salt dissolved in the solvent.
H01M 10/0568 - Matériaux liquides caracterisés par les solutés
H01M 4/131 - Électrodes à base d'oxydes ou d'hydroxydes mixtes, ou de mélanges d'oxydes ou d'hydroxydes, p. ex. LiCoOx
H01M 4/505 - Emploi de substances spécifiées comme matériaux actifs, masses actives, liquides actifs d'oxydes ou d'hydroxydes inorganiques de manganèse d'oxydes ou d'hydroxydes mixtes contenant du manganèse pour insérer ou intercaler des métaux légers, p. ex. LiMn2O4 ou LiMn2OxFy
H01M 4/525 - Emploi de substances spécifiées comme matériaux actifs, masses actives, liquides actifs d'oxydes ou d'hydroxydes inorganiques de nickel, de cobalt ou de fer d'oxydes ou d'hydroxydes mixtes contenant du fer, du cobalt ou du nickel pour insérer ou intercaler des métaux légers, p. ex. LiNiO2, LiCoO2 ou LiCoOxFy
H01M 10/0569 - Matériaux liquides caracterisés par les solvants
26.
CATALYST PELLETS THAT INCLUDE POLYGONAL PRISMATIC BODIES, PACKED BED REACTORS INCLUDING THE SAME, AND METHODS FOR HYDROPROCESSING UTILIZING THE SAME
Embodiments herein are directed to a catalyst pellet including a substantially regular polygonal prismatic body including a first polygonal surface, a second polygonal surface opposite the first polygonal surface, and n faces each extending in a length dimension from the first polygonal surface to the second polygonal surface, where n is equal to an integer from 5 to 20. The catalyst pellet includes n apertures extending from the first polygonal surface to the second polygonal surface. Each aperture has a substantially cylindrical shape and is positioned such that it is oriented towards a corner of the first polygonal surface and the second polygonal surface. Further embodiments are directed to a packed bed reactor including a reactor vessel and a packed catalyst bed including at least one catalyst pellet described herein. Further embodiments are directed to a method for hydroprocessing a hydrocarbon feed including passing the hydrocarbon feed into a reactor vessel, such that the hydrocarbon feed contacts a packed catalyst bed including at least one catalyst pellet described herein to form a product composition and passing the product composition out of the reactor vessel.
B01J 35/50 - Catalyseurs caractérisés par leur forme ou leurs propriétés physiques, en général caractérisés par leur forme ou leur configuration
B01J 8/02 - Procédés chimiques ou physiques en général, conduits en présence de fluides et de particules solidesAppareillage pour de tels procédés avec des particules immobiles, p. ex. dans des lits fixes
B01J 29/04 - Catalyseurs contenant des tamis moléculaires ayant des propriétés d'échangeurs de base, p. ex. zéolites cristallines, argiles pontées
B01J 35/40 - Catalyseurs caractérisés par leur forme ou leurs propriétés physiques, en général caractérisés par leurs dimensions, p. ex. granulométrie
C10G 49/04 - Traitement des huiles d'hydrocarbures, en présence d'hydrogène ou de composés donneurs d'hydrogène, non prévu dans un seul des groupes , , , ou caractérisé par le catalyseur utilisé contenant du nickel, du cobalt, du chrome, du molybdène ou du tungstène, ou leurs composés
27.
SYSTEM AND METHOD CONFIGURED TO PERFORM POWERSHELL MONITORING OF COMMUNICATIONS TO A COMPUTER-BASED SYSTEM USING KEYWORDS
A system and method monitor a communication directed to a computer-based system. A memory stores predetermined keywords and predetermined scores each corresponding to a predetermined keyword. A communications monitoring module monitors data string corresponding to the communications and detects a first keyword in the data string. An event code generating module generates an event code corresponding to the data string. A management module detects the generated event code. A keyword matching module searches the predetermined keywords for the detected first keyword and matches the detected first keyword with the generated event code. A score generating module generates a determined score from the detected first keyword and from the predetermined scores. A message generating module compares the determined score with a predetermined threshold and generates a message based on the comparison. The output device outputs the message corresponding to the communication. The method implements the system.
Korea Advanced Institute of Science and Technology (KAIST) (République de Corée)
Inventeur(s)
Imran, Hasan
Aldawsari, Yasmeen
Al Hunaidy, Ali Shakir
Roh, Kosan
Lee, Jay H.
Chung, Wonsuk
Abrégé
A system and method for producing ethanol, including dry reforming of methane with carbon dioxide to produce syngas, cryogenically separating carbon monoxide from syngas giving a first stream including primarily carbon monoxide and hydrogen. The method includes synthesizing methanol from the second stream via hydrogenation of carbon monoxide in the second stream and finally synthesizing ethanol via methanol homologation including the first stream of cryogenically separated carbon monoxide and a hydrogen stream.
C07C 29/32 - Préparation de composés comportant des groupes hydroxyle ou O-métal liés à un atome de carbone ne faisant pas partie d'un cycle aromatique à six chaînons par des réactions augmentant le nombre d'atomes de carbone sans formation de groupes hydroxyle
B01D 53/00 - 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
C01B 3/34 - Production d'hydrogène ou de mélanges gazeux contenant de l'hydrogène par réaction de composés organiques gazeux ou liquides avec des agents gazéifiants, p. ex. de l'eau, du gaz carbonique, de l'air par réaction d'hydrocarbures avec des agents gazéifiants
29.
LASER DESCALING SYSTEM WITH MAGNETIC ROBOTIC CONTROLS
A laser descaling tool includes a laser head formed of a magnetic or ferromagnetic material, a flexible laser arm defining first and second ends, the flexible laser arm coupled to the laser head at the first end and responsive to modification of a magnetic field to reorient the laser head, a support arm coupled to the flexible laser arm at the second end, a fiber optic cable extending through the flexible laser arm and the support arm to a control location, a laser source disposed at the control location and optically coupled to the laser head through the fiber optic cable, and a vacuum mounted at the second end of the laser arm and operable to collect debris from a scale deposit within an interior of a pipe.
B08B 7/00 - Nettoyage par des procédés non prévus dans une seule autre sous-classe ou un seul groupe de la présente sous-classe
B08B 5/02 - Nettoyage par la force de jets, p. ex. le soufflage de cavités
B08B 5/04 - Nettoyage par aspiration, avec ou sans action auxiliaire
B08B 9/043 - Nettoyage des surfaces intérieuresÉlimination des bouchons utilisant des dispositifs de nettoyage introduits dans et déplacés le long des tubes déplacés par liaison mécanique actionnée de l'extérieur, p. ex. poussés ou tirés dans les tubes
30.
COMPACT VENTURI WITH EMBEDDED DUAL MUTUALLY ORTHOGONAL RESONATOR (DMOR) SENSORS TO MEASURE MULTIPHASE FLOW RATES
KING ABDULLAH UNIVERSITY OF SCIENCE AND TECHNOLOGY (Arabie saoudite)
Inventeur(s)
Arsalan, Muhammad
Karimi, Muhammad Akram
Akhter, Zubair
Shamim, Atif
Abrégé
A Waventuri flowmeter includes a Venturi flowmeter with a multiphase fraction measurement device incorporated therein. The Waventuri flowmeter includes an inlet for receiving a wellbore fluid into the flowmeter, the inlet defining an inlet diameter and an outlet for discharging the wellbore fluid from the flowmeter, the outlet defining an outlet diameter. A flow path extends between the inlet and the outlet and includes a converging section downstream of the inlet and a diverging section downstream of the converging section. At least one sensor is operable to detect a parameter indicative of pressures of the wellbore fluid at the inlet and a throat between the converging and diverging sections. First and second permittivity sensors extend axially along the diverging and converging sections, respectively. The first and second permittivity sensors are operable to measure parameters indicative of multiphase volume fractions of the wellbore fluid within the diverging and converging sections.
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
G01F 1/74 - Dispositifs pour la mesure du débit d'un matériau fluide ou du débit d'un matériau solide fluent en suspension dans un autre fluide
31.
METHOD TO DETERMINE PORE THROAT SIZE DISTRIBUTION OF ROCKS BY NUCLEAR MAGNETIC RESONANCE
A method for determining a pore throat size distribution in a rock sample includes saturating the rock sample with a fluid to a maximum saturation, acquiring a first set of nuclear magnetic resonance (NMR) measurements of the rock sample, generating based on a first T2 distribution of the first set of NMR measurements a first saturation profile and a first set of slice measurements, obtaining a peak T2 measurement and an average pore throat size measurement by conducting a subsequent NMR measurement procedure, repeating obtaining a peak T2 measurement until the rock sample has a minimum saturation, obtaining a fit function by fitting the average pore throat size measurements to the peak T2 measurements, and generating a pore throat size distribution from the first T2 distribution. A computer system for determining a pore size distribution in a rock sample includes a processor and a memory coupled to the processor.
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 15/08 - Recherche de la perméabilité, du volume des pores ou de l'aire superficielle des matériaux poreux
G01R 33/30 - Dispositions pour le traitement des échantillons, p. ex. cellules d'essai, mécanismes rotationnels
G01R 33/50 - Systèmes d'imagerie RMN basés sur la détermination des temps de relaxation
32.
METHOD AND SYSTEM TO ACCELERATE THE NONLINEAR SOLUTION IN NUMERICAL RESERVOIR SIMULATION
Systems and methods are disclosed. The method includes obtaining a reservoir model and a production scenario. The method also includes determining a first set of parameters for a first time from the reservoir model and the production scenario, predicting, using the first set of parameters, a second set of parameters at a second, later, time, including primary variables used to determine values for a mass, a flux and a well term. Predicting includes, iteratively until a stopping criterion is satisfied, for each computational cells in the reservoir model, using the first set of parameters to determine a primary variable update and a residual, determining an updated flux and well term, predicting the second set of parameters from the updated flux and well term, assigning the second set of parameters to the first set of parameters, and determining a predicted location of unproduced hydrocarbons from the second set of parameters.
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
33.
Evaluating Biological Materials at Reservoir Conditions
Systems and methods for evaluating biological materials at reservoir conditions include a reactor housing and a plurality of test columns having source rock sample holders. The plurality of test columns is disposed within the reactor housing. A pump is fluidly coupled to the reactor housing. A heating element is coupled to the reactor housing; and one or more sensors are coupled to the test columns configured to measure properties of biomaterials or biochemical interactions in the rock samples.
Embodiments herein are directed to a catalyst pellet including a substantially regular polygonal prismatic body including a first polygonal surface, a second polygonal surface opposite the first polygonal surface, and n faces each extending in a length dimension from the first polygonal surface to the second polygonal surface, where n is equal to an integer from 5 to 20. The catalyst pellet includes n apertures extending from the first polygonal surface to the second polygonal surface. Each aperture has a substantially cylindrical shape and is positioned such that it is oriented towards a corner of the first polygonal surface and the second polygonal surface. Further embodiments are directed to a packed bed reactor including a reactor vessel and a packed catalyst bed including at least one catalyst pellet described herein. Further embodiments are directed to a method for hydroprocessing a hydrocarbon feed including passing the hydrocarbon feed into a reactor vessel, such that the hydrocarbon feed contacts a packed catalyst bed including at least one catalyst pellet described herein to form a product composition and passing the product composition out of the reactor vessel.
B01J 8/00 - Procédés chimiques ou physiques en général, conduits en présence de fluides et de particules solidesAppareillage pour de tels procédés
B01J 19/30 - Éléments de remplissage non agglomérés ou en forme, p. ex. anneaux de Raschig ou éléments de Berl en forme de selle, destinés à être versés dans l'appareil de transfert de chaleur ou de matière
B01J 35/50 - Catalyseurs caractérisés par leur forme ou leurs propriétés physiques, en général caractérisés par leur forme ou leur configuration
B01J 35/56 - Structures foraminées ayant des passages ou des canaux traversants, p. ex. monolithes tridimensionnels ou grilles
Disclosed are methods, systems, and computer-readable medium to perform operations including: obtaining sensor data from at least one sensor attached to a surface of a drill bit; providing the sensor data from the at least one sensor to one or more machine learning models, wherein the one or more machine learning models are trained using a library of (i) sensor signatures and (ii) geological formations to output one or more drilling parameters; and adjusting one or more parameters of an operation performed by a drill controlling the drill bit based on the one or more drilling parameters output by one or more machine learning models.
E21B 44/00 - Systèmes de commande automatique spécialement adaptés aux opérations de forage, c.-à-d. systèmes à fonctionnement autonome ayant pour rôle d'exécuter ou de modifier une opération de forage sans l'intervention d'un opérateur humain, p. ex. systèmes de forage commandés par ordinateurSystèmes spécialement adaptés à la surveillance de plusieurs variables ou conditions de forage
E21B 47/013 - Dispositifs spécialement adaptés pour supporter des instruments de mesure sur des trépans de forage
36.
COMPACT VENTURI WITH EMBEDDED DUAL MUTUALLY ORTHOGONAL RESONATOR (DMOR) SENSORS TO MEASURE MULTIPHASE FLOW RATES
KING ABDULLAH UNIVERSITY OF SCIENCE AND TECHNOLOGY (Arabie saoudite)
SAUDIA ARABIAN OIL COMPANY (Arabie saoudite)
Inventeur(s)
Arsalan, Muhammad
Karimi, Muhammad Akram
Akhter, Zubair
Shamim, Atif
Abrégé
A Waventuri flowmeter includes a Venturi flowmeter with a multiphase fraction measurement device incorporated therein. The Waventuri flowmeter includes an inlet for receiving a wellbore fluid into the flowmeter, the inlet defining an inlet diameter and an outlet for discharging the wellbore fluid from the flowmeter, the outlet defining an outlet diameter. A flow path extends between the inlet and the outlet and includes a converging section downstream of the inlet and a diverging section downstream of the converging section. At least one sensor is operable to detect a parameter indicative of pressures of the wellbore fluid at the inlet and a throat between the converging and diverging sections. First and second permittivity sensors extend axially along the diverging and converging sections, respectively. The first and second permittivity sensors are operable to measure parameters indicative of multiphase volume fractions of the wellbore fluid within the diverging and converging sections.
33-containing gas such that the carbon microparticles have a hydrophilic surface (205), and grinding the carbon microparticles to provide carbon nanoparticles (106). The carbon nanoparticles (106) have a hydrophilic surface (205) and a hydrophobic surface (207). A method of enhanced oil recovery is also described.
C09K 8/03 - Additifs spécifiques à usage général dans les compositions pour le forage des puits
C09K 8/584 - Compositions pour les méthodes de récupération assistée pour l'extraction d'hydrocarbures, c.-à-d. pour améliorer la mobilité de l'huile, p. ex. fluides de déplacement caractérisées par l'utilisation de tensio-actifs spécifiques
38.
EFFICIENT SURFACE FUNCTIONALIZATION FOR SCALE-UP SYNTHESIS OF JANUS CARBON NANOFLUIDS
A method of preparing an enhanced oil recovery composition is provided. The method includes carbonizing (200) a waste carbon material (202) to provide carbon microparticles (208) having a hydrophobic surface (404), functionalizing (300) the carbon microparticles (208) with an alkaline solution (302) such that the carbon microparticles (208) have a hydrophilic surface (306), and grinding (400) the carbon microparticles (208) to provide carbon nanoparticles (406). The carbon nanoparticles (406) have a hydrophilic surface (306) and a hydrophobic surface (404). The method may further include mixing the carbon nanoparticles with an aqueous based fluid to provide an enhanced oil recovery fluid.
C09K 8/03 - Additifs spécifiques à usage général dans les compositions pour le forage des puits
C01B 32/05 - Préparation ou purification du carbone non couvertes par les groupes , , ,
C09K 8/584 - Compositions pour les méthodes de récupération assistée pour l'extraction d'hydrocarbures, c.-à-d. pour améliorer la mobilité de l'huile, p. ex. fluides de déplacement caractérisées par l'utilisation de tensio-actifs spécifiques
39.
SULFONATION METHOD FOR EFFICIENT SCALE-UP SYNTHESIS OF JANUS CARBON NANOMATERIALS FROM BIOMASS WASTE
333- containing gas and including a hydrophilic and hydrophobic surface into a hydrocarbon-bearing formation. The method includes displacing hydrocarbons from the hydrocarbon-bearing formation and recovering the hydrocarbons.
C09K 8/03 - Additifs spécifiques à usage général dans les compositions pour le forage des puits
C09K 8/584 - Compositions pour les méthodes de récupération assistée pour l'extraction d'hydrocarbures, c.-à-d. pour améliorer la mobilité de l'huile, p. ex. fluides de déplacement caractérisées par l'utilisation de tensio-actifs spécifiques
40.
CONDITIONING A TUBING HEAD BACK PRESSURE VALVE RECEPTACLE
A tool is used for installing and/or operating a back pressure valve mounted in a profile formed in an upper end of a tubing hanger. The tool is also used to remove deposits from the profile by attaching a conditioning module to the tool, and engaging the profile with the module. The module includes a body having a cylindrical mid-portion and frusto-conical upper and lower portions. Brush assemblies circumscribe the body at different elevations along the mid-portion, which remove the deposits on the profile when the module is simultaneously rotated and pressed against the profile. The brush assemblies are made up of sections that each have a base secured to the body and brush elements projecting radially outward from the body. After the deposits are removed, the back pressure valve is installed using the tool.
A method includes providing an electrical submersible pump assembly (ESP) with a pump, an intake, a gel canister, a protector, and a motor disposed in a casing. The method includes providing fluid communication between a production tubing and the ESP, the production tubing delivering well fluid containing solid particles and liquids from the ESP into a wellhead assembly through an inner bore of the production tubing. The method includes locating a pressure release conduit configured in a closed state, between a canister exterior in a hydraulic communication with a canister inner chamber of the gel canister and the inner bore. The closed state prevents the hydraulic communication between the canister inner chamber and the inner bore. The method includes delivering a canister contents to the well fluid.
Systems and methods are disclosed relating to geological model upscaling. Training data representative of previously captured, generated, and/or recorded detailed geological data for one or more subsurfaces of a planet can be received. A diffusion model can be trained based on the training data to optimize parameters of the diffusion model. Detailed geological data for a respective subsurface of the planet can be received, and the detailed geological data can be upscaled using the trained diffusion model. Upscaled geological data can be generated based on the upscaling. In some examples, an upscaled geological model representative of the respective subsurface can be generated based on the upscaled geological data. The upscaled geological model can be simulated to model a behavior of the respective subsurface.
Disclosed are methods, systems, and computer-readable medium to perform operations including: obtaining sensor data from at least one sensor attached to a surface of a drill bit; providing the sensor data from the at least one sensor to one or more machine learning models, wherein the one or more machine learning models are trained using a library of (i) sensor signatures and (ii) geological formations to output one or more drilling parameters; and adjusting one or more parameters of an operation performed by a drill controlling the drill bit based on the one or more drilling parameters output by one or more machine learning models.
E21B 44/00 - Systèmes de commande automatique spécialement adaptés aux opérations de forage, c.-à-d. systèmes à fonctionnement autonome ayant pour rôle d'exécuter ou de modifier une opération de forage sans l'intervention d'un opérateur humain, p. ex. systèmes de forage commandés par ordinateurSystèmes spécialement adaptés à la surveillance de plusieurs variables ou conditions de forage
E21B 47/06 - Mesure de la température ou de la pression
44.
WATERFLOODING SYSTEM AND PROCESS TO PREVENT SCALE PRECIPITATION IN OIL FIELDS
Described is a system for targeted waterflooding in an oil field. The system includes a mobile reverse osmosis unit connected with source water. The mobile reverse osmosis unit generates low salinity fresh water from the source water. An injection manifold is connected with the mobile reverse osmosis unit. The injection manifold distributes the low salinity fresh water into injection wells within the oil field. The low salinity fresh water is stored underground prior to its use in production wells.
KING ABDULLAH UNIVERSITY OF SCIENCE AND TECHNOLOGY (Arabie saoudite)
Inventeur(s)
Alshareef, Husam Niman
Zhao, Zhiming
El-Demellawi, Jehad Khaled
Abrégé
An electrochemical cell for a rechargeable battery, where the electrochemical cell includes: an anode including lithium (Li); an anode current collector connected to the anode; a cathode; a cathode current collector connected to the cathode; a separator between the anode and the cathode; and a liquid electrolyte including: a solvent, a Li salt dissolved in the solvent, and a polyvalent metal salt dissolved in the solvent.
H01M 4/525 - Emploi de substances spécifiées comme matériaux actifs, masses actives, liquides actifs d'oxydes ou d'hydroxydes inorganiques de nickel, de cobalt ou de fer d'oxydes ou d'hydroxydes mixtes contenant du fer, du cobalt ou du nickel pour insérer ou intercaler des métaux légers, p. ex. LiNiO2, LiCoO2 ou LiCoOxFy
H01M 4/38 - Emploi de substances spécifiées comme matériaux actifs, masses actives, liquides actifs d'éléments simples ou d'alliages
H01M 4/131 - Électrodes à base d'oxydes ou d'hydroxydes mixtes, ou de mélanges d'oxydes ou d'hydroxydes, p. ex. LiCoOx
H01M 4/134 - Électrodes à base de métaux, de Si ou d'alliages
H01M 10/0561 - Accumulateurs à électrolyte non aqueux caractérisés par les matériaux utilisés comme électrolytes, p. ex. électrolytes mixtes inorganiques/organiques l'électrolyte étant constitué uniquement de matériaux inorganiques
H01M 10/056 - Accumulateurs à électrolyte non aqueux caractérisés par les matériaux utilisés comme électrolytes, p. ex. électrolytes mixtes inorganiques/organiques
A laser descaling tool (100) includes a laser head (102) formed of a magnetic or ferromagnetic material, a flexible laser arm (110) defining first and second ends, the flexible laser arm coupled to the laser head at the first end and responsive to modification of a magnetic field to reorient the laser head, a support arm (118) coupled to the flexible laser arm at the second end, a fiber optic cable (120) extending through the flexible laser arm and the support arm to a control location (308), a laser source (310) disposed at the control location and optically coupled to the laser head through the fiber optic cable, and a vacuum (114) mounted at the second end of the laser arm and operable to collect debris from a scale deposit within an interior of a pipe (300). Also disclosed is a system comprising a laser descaling tool and one or more crawlers (200) movable on the outer circumferential surface of the pipe and one or more magnetic field generators (210) carried by the crawlers operable to produce said magnetic field for reorienting the laser head.
B08B 7/00 - Nettoyage par des procédés non prévus dans une seule autre sous-classe ou un seul groupe de la présente sous-classe
B08B 9/04 - Nettoyage des surfaces intérieuresÉlimination des bouchons utilisant des dispositifs de nettoyage introduits dans et déplacés le long des tubes
47.
SYSTEM AND METHOD TO PREVENT SOLIDS FALLBACK IN ESP-LIFTED WELLS USING GEL
A method (700) includes providing (710) an electrical submersible pump assembly, ESP (310) with a pump, an intake, a gel canister (314), a protector, and a motor disposed in a casing. The method includes providing (720) fluid communication between a production tubing and the ESP, the production tubing delivering well fluid containing solid particles and liquids from the ESP into a wellhead assembly through an inner bore of the production tubing. The method includes locating (730) a pressure release conduit configured in a closed state, between a canister exterior in a hydraulic communication with a canister inner chamber of the gel canister and the inner bore. The closed state prevents the hydraulic communication between the canister inner chamber and the inner bore. The method includes delivering (740) a canister contents to the well fluid.
A cuttings collection system (200) includes a drill bit (112) at the end of a toolstring (104), a stabilizer (202) connected to the drill bit (112), a cuttings catcher (206) arranged around the stabilizer (202) with apertures having a size less than an average size of cuttings generated by the drill bit (112) and retractability, and sensors (204) installed in a body of the stabilizer (202). A cuttings catcher (206) includes a housing (302) with recesses (306) and a retractable mesh (308) installed in each of the recesses (306). A method of operating an at-bit cuttings catcher system (200) includes providing a toolstring (104) with a drill bit (112), a stabilizer (202), a cuttings catcher (206), and a measurement-while-drilling tool (208), where the cuttings catcher (206) includes a housing (302) with recesses (306) and a mesh (308) installed in the recesses (306), drilling a formation (116) using the drill bit (112), producing cuttings of the formation (116), extending the mesh (308) from the housing (302) of the cuttings catcher (206), catching cuttings in the cuttings catcher (206), and analyzing the cuttings using sensors (204).
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 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
49.
METHOD AND SYSTEM TO ACCELERATE THE NONLINEAR SOLUTION IN NUMERICAL RESERVOIR SIMULATION
Systems and methods are disclosed. The method includes obtaining a reservoir model (216) and a production scenario. The method also includes determining a first set of parameters for a first time from the reservoir model (216) and the production scenario, predicting, using the first set of parameters, a second set of parameters at a second, later, time, including primary variables used to determine values for a mass, a flux and a well term. Predicting includes, iteratively until a stopping criterion is satisfied, for each computational cells (218) in the reservoir model (216), using the first set of parameters to determine a primary variable update and a residual, determining an updated flux and well term, predicting the second set of parameters from the updated flux and well term, assigning the second set of parameters to the first set of parameters, and determining a predicted location of unproduced hydrocarbons from the second set of parameters.
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
42 - Services scientifiques, technologiques et industriels, recherche et conception
Produits et services
Software as a service (SAAS) services featuring software using artificial intelligence (AI) for reservoir modeling and subsurface analysis; Providing on-line non-downloadable software using artificial intelligence (AI) for reservoir modeling and subsurface analysis
51.
Real-time detection of gas kicks during drilling and gas cap gas intrusion during oil production
A method of detecting an increase in gas content in a pipe. The method includes flowing fluid through the pipe. The method includes generating, by a network analyzer, microwaves data representing a complex scattering coefficient over a first spectrum of microwave frequencies that are emitted through a waveguide and a fluid within the pipe and determining a statistical profile of a complex scattering magnitude over a second spectrum of microwave frequencies. The method includes determining that an amount of gas within the pipe satisfies a threshold amount and causing a flow of fluids within the pipe to slow or stop until the amount of gas falls below a predetermined threshold value.
E21B 47/113 - Localisation des fuites, intrusions ou mouvements du fluide utilisant des signaux électriquesLocalisation des fuites, intrusions ou mouvements du fluide utilisant un rayonnement lumineux
G01N 22/00 - Recherche ou analyse des matériaux par l'utilisation de micro-ondes ou d'ondes radio, c.-à-d. d'ondes électromagnétiques d'une longueur d'onde d'un millimètre ou plus
52.
Cuttings trap for “at bit” measurement of drilled cuttings
A cuttings collection system includes a drill bit at the end of a toolstring, a stabilizer connected to the drill bit, a cuttings catcher arranged around the stabilizer with apertures having a size less than an average size of cuttings generated by the drill bit and retractability, and sensors installed in a body of the stabilizer. A cuttings catcher includes a housing with recesses and a retractable mesh installed in each of the recesses. A method of operating an at-bit cuttings catcher system includes providing a toolstring with a drill bit, a stabilizer, a cuttings catcher, and a measurement-while-drilling tool, where the cuttings catcher includes a housing with recesses and a mesh installed in the recesses, drilling a formation using the drill bit, producing cuttings of the formation, extending the mesh from the housing of the cuttings catcher, catching cuttings in the cuttings catcher, and analyzing the cuttings using sensors.
E21B 27/00 - Récipients pour ramasser ou déposer des substances dans les trous de forage ou les puits, p. ex. cuillers pour ramasser de la boue ou du sableTrépans comportant des moyens pour ramasser des substances, p. ex. trépans à clapet
E21B 17/10 - Protecteurs contre l'usureDispositifs de centrage
E21B 47/005 - Surveillance ou contrôle de la qualité ou du niveau de cimentation
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
42 - Services scientifiques, technologiques et industriels, recherche et conception
Produits et services
Software as a service (SAAS) for reservoir modeling and subsurface analysis; software as a service (SAAS) services featuring software using artificial intelligence (AI) for reservoir modeling and subsurface analysis; providing online non-downloadable software for reservoir modeling and subsurface analysis; providing online non-downloadable software using artificial intelligence (AI) for reservoir modeling and subsurface analysis.
Apparatus, systems and methods for soil gas sampling are disclosed. The apparatus may include a first outer surface formed from a rigid liquid-impermeable and gas-impermeable material, and a second outer surface formed from an aquaphobic and gas-permeable membrane, where an edge of the second outer surface is attached to the first edge of the first surface, the first outer surface and the second outer surface entirely enclose an inner volume, and the second outer surface comprises a high specific surface area surface. The apparatus may further include a quantity of porous absorbing material, at least partially filling the inner volume, configured to preferentially absorb gaseous analytes.
Methods and systems are disclosed herein. A system may include a reconnaissance group comprising a first reconnaissance robot configured to perform reconnaissance for an acquisition area within the region of interest. The system may also include an acquisition group comprising a first acquisition robot configured to perform at least one of deploying, operating, and retrieving acquisition equipment within the acquisition area. The system may further include a central management system comprising a control processor configured to generate reconnaissance instructions for and receive reconnaissance information from the reconnaissance group and generate acquisition instructions for and receive acquisition information from the acquisition group. The system may include a communication system configured to communicate between the central management system and the reconnaissance group and the acquisition group.
Carbon dioxide may be stored in a subterranean formation. For example, methods of subterranean carbon dioxide storage may include: introducing, through an injection wellbore to a subterranean formation includes a basaltic formation, a carbonated aqueous fluid; reacting the carbon dioxide or an ion thereof with the basaltic formation to form mineralized carbon and a produced aqueous fluid; flowing a mixture of the carbonated aqueous fluid and/or the produced aqueous fluid through one or more formation fractures; depositing the mineralized carbon dioxide within the subterranean formation; and flowing the produced aqueous fluid from the subterranean formation through a first production wellbore, wherein a portion of the first production wellbore is substantially parallel to a portion of the injection wellbore, and wherein the one or more formation fractures are substantially perpendicular to a portion of the injection wellbore and a portion of the first production wellbore.
Various measurement devices, systems including measurement devices, and methods for using measurement devices are discussed. As one of many examples, a measurement device (201) is discussed that includes: a mesh (210) configured to allow a ground material in contact with the measurement device (201) pass through the mesh (210), a motion sensor (240, 240a-240f) coupled to the mesh (210), a drive system (250) coupled to the mesh (210), and an operational sensor coupled to the mesh (210).
A cement swell packer (100) includes a base tubular that includes at least one end connection; a cement swell assembly (101) configured to mount on the base tubular and including a portion of a dry cementitious material configured to form a hardenable or curable cement when exposed to a fluid in a wellbore, and a mesh (102) configured to hold the portion of the dry cementitious material; and a liquid barrier formed over the dry cementitious material.
E21B 33/13 - Procédés ou dispositifs de cimentation, de bouchage des trous, des fissures ou analogues
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
A downhole tool includes a tool body including an uphole joint and a downhole joint configured to couple within a wellbore tubing string that extends in a wellbore. One or more flow directing paths are formed on an outer surface of the tool body and configured to rotate a portion of the tool body in response to a fluid flow within the wellbore tubing string. One or more ports are disposed around a circumference of the tool body; and a piston is configured to adjust between an open position such that the one or more ports are open to enable injection of a lost circulation material circulated through the tool body and into the wellbore and a closed position such that the one or more ports are closed to block injection of the lost circulation material into the wellbore from the tool body.
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 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 47/10 - Localisation des fuites, intrusions ou mouvements du fluide
A heater cable is disposed through a wellhead assembly into a production tubing string and is lowered such that it is at least partially immersed within a volume of a well kill fluid. Prior to the immersion, a density of the well kill fluid relative to the produced fluids at the downhole end is such that the volume of well kill fluid prevents the flow of the produced fluids from the subterranean zone into the production tubing string. An electric current is flowed though the heater cable, and the heater cable converts the electric current to heat energy. The heat energy is transferred by conduction to the kill fluid thereby reducing the density of the well kill fluid relative to the produced fluids such that the well kill fluid rises in an uphole direction through the production tubing string.
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
E21B 36/04 - 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 utilisant des réchauffeurs électriques
A composition and methods are provided for stimulating a well with nanobubbles. An exemplary method includes obtaining a stimulation fluid and generating a nanobubbles solution, wherein the nanobubbles solution includes nano-sized bubbles in the stimulation fluid. The nanobubbles solution is injected into the oil well.
A rig-less wellbore system includes a blowout preventer (BOP) central body fluidly coupled to a wellbore and a plurality of hydraulic cylinders extending radially from the central body. A plurality of pistons operable to move radially within a respective hydraulic cylinder between an open position wherein flow through the central passageway is permitted and a closed position wherein the pistons extend into the central passageway to prohibit fluid flow through the central passageway. At least one sensor is operable to monitor at least one parameter indicative of activity within a hydraulic circuit operably associated with an individual one of the pistons. A data acquisition system (DAS) is communicatively coupled to the at least one sensor to collect and record data provided by the at least one sensor.
Methods of subterranean carbon dioxide storage may include: introducing, through an injection wellbore to a subterranean formation includes a basaltic formation, a carbonated aqueous fluid; reacting the carbon dioxide or an ion thereof with the basaltic formation to form mineralized carbon and a produced aqueous fluid; flowing a mixture of the carbonated aqueous fluid and/or the produced aqueous fluid through one or more formation fractures; depositing the mineralized carbon dioxide within the subterranean formation; and flowing the produced aqueous fluid from the subterranean formation through a first production wellbore, wherein a portion of the first production wellbore is substantially parallel to a portion of the injection wellbore, and wherein the one or more formation fractures are substantially perpendicular to a portion of the injection wellbore and a portion of the first production wellbore.
A fire extinguishing system includes a storage tank defining a vertical wall and a floating roof floating on a flammable liquid stored within the storage tank. The floating roof is vertically movable along the vertical wall in response to a level of the flammable liquid within the storage tank and a rim seal is defined circumferentially between the floating roof and the vertical wall. A foam supply conduit extends to the storage tank from a remote location and a foam diffuser is fluidly coupled to the foam supply conduit. The foam diffuser is affixed to an underside of the floating roof and submerged in the flammable liquid. The foam diffuser includes at least one outlet for discharging a foam into the flammable liquid adjacent the underside of the floating roof and an upper surface of the flammable liquid.
A system for pumping a fluid into a sub-surface formation to pressurize the sub-surface formation using a pump having a shaft. The system includes a mechanical seal removably installed in the pump and a mechanical seal integrity testing rig configured to be pressed against the mechanical seal and to test an integrity of the mechanical seal. The mechanical seal removably installed in the pump comprises a mechanical seal sleeve delineating a conduit configured to receive the shaft of the pump and a bottom end and a mechanical seal flange. The system further includes a mechanical seal integrity testing rig configured to be pressed against the mechanical seal and to test an integrity of the mechanical seal. The mechanical seal integrity testing rig comprises a testing rig sleeve having a top end of testing rig sleeve and a bottom end of testing rig sleeve and a mechanical seal sleeve blind.
G01M 3/28 - 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 mesure du taux de perte ou de gain d'un fluide, p. ex. avec des dispositifs réagissant à la pression, avec des indicateurs de débit pour tuyaux, câbles ou tubesExamen de l'étanchéité des structures ou ouvrages vis-à-vis d'un fluide par utilisation d'un fluide ou en faisant le vide par mesure du taux de perte ou de gain d'un fluide, p. ex. avec des dispositifs réagissant à la pression, avec des indicateurs de débit pour raccords ou joints d'étanchéité de tuyauxExamen de l'étanchéité des structures ou ouvrages vis-à-vis d'un fluide par utilisation d'un fluide ou en faisant le vide par mesure du taux de perte ou de gain d'un fluide, p. ex. avec des dispositifs réagissant à la pression, avec des indicateurs de débit pour soupapes
F04B 47/04 - Pompes ou installations de pompage spécialement adaptées pour élever un fluide à partir d'une grande profondeur, p. ex. pompes de puits les mécanismes d'entraînement étant placés au niveau du sol les moyens d'entraînement comportant des moyens fluides
F04B 51/00 - Tests des "machines", pompes ou installations de pompage
66.
SYSTEMS AND METHODS FOR PREPARING AND QUANTIFYING SOLUTIONS
Systems and methods for the preparation and quantification of chemical solutions. The system includes a working solution preparation section, a standard solution preparation section, and a titration section.
G01N 35/10 - Dispositifs pour transférer les échantillons vers, dans ou à partir de l'appareil d'analyse, p. ex. dispositifs d'aspiration, dispositifs d'injection
A circular economy polygeneration system includes an electrolyzer operable to provide hydrogen and oxygen based on water. The system includes a hydrogen firing furnace operable to burn hydrogen and produce a first flue gas including water and nitrogen. The system also includes an oxy-firing furnace operable to burn hydrocarbon fuel with oxygen provided by the electrolyzer to produce a second flue gas comprising water and carbon dioxide. Moreover, the system includes a first condenser configured to produce nitrogen and a first stream of water based on the first flue gas. The system further includes a second condenser configured to produce carbon dioxide and a second stream of water based on the second flue gas. The first and second stream of water are used by the electrolyzer to provide the hydrogen and oxygen. Additionally, the system includes a carbon capture system operable to capture carbon dioxide produced by the second condenser.
F23C 9/00 - Appareils à combustion caractérisés par des dispositions pour renvoyer les produits de combustion ou les gaz de fumée dans la chambre de combustion
B01D 53/00 - 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
A computer implemented method that enables dynamic digital analysis of chemical inhibitors utilizing machine learning is described. The method includes determining a concentration output using a machine learning model trained using data associated with thermodynamic chemical inhibitors; determining temperatures associated with a chemical inhibitor regeneration cycle using a machine learning model trained using temporal data; determining a liquid inventory using a machine learning model trained using data associated with flow rates; generating a model of a chemical inhibitor regeneration cycle based on the concentration output, the temperatures, and the liquid inventory; and executing the model by inputting real-time operating conditions associated with the chemical inhibitor regeneration cycle, wherein the model outputs chemical inhibitor concentrations associated with a production system.
G05B 13/02 - Systèmes de commande adaptatifs, c.-à-d. systèmes se réglant eux-mêmes automatiquement pour obtenir un rendement optimal suivant un critère prédéterminé électriques
Systems and methods for measuring rock permeability include positioning a core sample in a core sample assembly that is enclosed in a pressurized container with a flow inlet, a flow outlet, and a pressurized fluid inlet fluidly coupled to a pressurized fluid reservoir that includes a pressurized fluid pump; performing a low pore pressure test operation on the core sample; sequentially performing at least three high pore pressure test operations on the core sample measuring an inlet pressure at the flow inlet, measuring an outlet pressure at the flow outlet, and measuring a confining pressure within the pressurized container; and determining a permeability of the core sample based at least in part on at least one of the measured inlet pressures, at least one of the measured outlet pressures, and at least one of the measured confining pressures.
A heater cable is disposed through a wellhead assembly into a production tubing string and is lowered such that it is at least partially immersed within a volume of a well kill fluid. Prior to the immersion, a density of the well kill fluid relative to the produced fluids at the downhole end is such that the volume of well kill fluid prevents the flow of the produced fluids from the subterranean zone into the production tubing string. An electric current is flowed though the heater cable, and the heater cable converts the electric current to heat energy. The heat energy is transferred by conduction to the kill fluid thereby reducing the density of the well kill fluid relative to the produced fluids such that the well kill fluid rises in an uphole direction through the production tubing string.
An autonomous machine includes a body; a mobile base coupled to the body and configured to move the body between a plurality of locations; and at least one extendable appendage coupled to, and configured to extend from, the body. The at least one extendable appendage includes at least one laser sensor plate. The at least one laser sensor plate includes at least one laser emitter configured to move on the at least one laser sensor plate and emit a laser signal along a tubular member; and at least one laser receiver coupled to the at least one laser sensor plate and configured to receive a reflected laser signal along the tubular member. The emitted laser signal and the reflected laser signal is indicative of a quality of the tubular member.
G01B 11/06 - Dispositions pour la mesure caractérisées par l'utilisation de techniques optiques pour mesurer la longueur, la largeur ou l'épaisseur pour mesurer l'épaisseur
G01N 35/00 - Analyse automatique non limitée à des procédés ou à des matériaux spécifiés dans un seul des groupes Manipulation de matériaux à cet effet
A computer implemented method that enables integrated seismic data augmentation is described. The method includes generating a three-dimensional (3D) seismic velocity model using sequential gaussian simulation. The method includes executing forward modeling simulations on the seismic velocity model to generate primaries and multiples of wavelets associated with the seismic velocity model. Additionally, the method includes combining the primaries and the multiples of wavelets with noise to generate augmented seismic data.
A method of consuming an acidic fluid in a wellbore comprises injecting a multilayer metallic ball into the wellbore, wherein the multilayer metallic ball comprises a core layer, a metallic layer encapsulating the core layer, and a ball density greater than the acidic fluid; contacting the multilayer metallic ball with the acidic fluid, thereby reacting at least a portion of the metallic layer with the acidic fluid at a first reaction rate and at least a portion of the core layer with the acidic fluid at a second reaction rate; and converting at least a portion of the acidic fluid to a spent acidic fluid.
A system and method are disclosed relating to electrical coalescence separation. In some examples, a first electric field can be established in a first vessel that includes a first oil-water mixture received from an oil stream based on a first voltage. A second electric field can be established in a second vessel that includes a second oil-water mixture received from the oil stream based on a second voltage. The first electric field can be controlled based on the second voltage to control separation of water from oil in the first oil-water mixture in the first vessel.
The disclosure provides systems and methods to monitor the degradation of polymer layers in polymer based photovoltaic modules using an optical sensor. The optical sensor is embedded in a polymer layer of the polymer based photovoltaic module.
H02S 50/15 - Tests de dispositifs PV, p. ex. de modules PV ou de cellules PV individuelles utilisant des moyens optiques, e.g. utilisant l'électroluminescence
H10F 19/80 - Encapsulations ou conteneurs pour des dispositifs intégrés, ou des ensembles de plusieurs dispositifs, comportant des cellules photovoltaïques
76.
NATURAL GAS LIQUIDS QUALITY DIGITALIZED ANALYTICS AND PREDICTIVE SOLUTION
A Natural Gas Liquids (NGL) quality digitalized analytics and predictive solution computer-implemented method includes extracting, automatically and in real-time as measured data from elements of a natural gas liquids (NGL) network, values for operating parameters and quality parameters. The measured data is compared against maximum limits. If the comparison indicates the measured data is within limit: 1) normal operations continue and 2) performance is reported. If the comparison is not within limit: 1) an alert notification is issued; 2) an investigation is conducted via trending and root-cause analysis; and 3) corrective and mitigation actions are performed.
The apparatus includes a pyrolysis chamber configured to receive and hold within an interior space a volume of an aqueous fluid and to maintain a pressure within the interior space for a duration of an experimental period when a removable head is in a closed position. The apparatus includes a sample basket assembly comprising a plurality of baskets attached to the removable head by one or more rods. Each basket is configured to receive one or more source rock samples. The sample basket assembly is configured such that, when the removable head is in the closed position and the one or more source samples are disposed within each basket, the samples suspended in a substantially stationary position above the floor.
G01N 25/14 - Recherche ou analyse des matériaux par l'utilisation de moyens thermiques en utilisant la distillation, l'extraction, la sublimation, la condensation, la congélation ou la cristallisation
G01N 1/28 - Préparation d'échantillons pour l'analyse
G01N 23/2251 - Recherche ou analyse des matériaux par l'utilisation de rayonnement [ondes ou particules], p. ex. rayons X ou neutrons, non couvertes par les groupes , ou en mesurant l'émission secondaire de matériaux en utilisant des microsondes électroniques ou ioniques en utilisant des faisceaux d’électrons incidents, p. ex. la microscopie électronique à balayage [SEM]
Methods and systems include, using a monitoring system, initiating a control logic configured to control a production control system pertaining to a refrigeration system connected to a plurality of production trains. The method may include obtaining a plurality of production parameters; calculating, using the plurality of production parameters, an isentropic efficiency value for the primary compressor if the production flow rate is less than a production threshold; comparing each of the plurality of isentropic efficiency values; determining from the comparing each of the plurality of isentropic efficiency values, a primary compressor having a lowest isentropic efficiency value; selecting the respective primary compressor having the lowest isentropic efficiency value. The method may include, using a production control system, shutting down the selected primary compressor.
F25J 1/02 - Procédés ou appareils de liquéfaction ou de solidification des gaz ou des mélanges gazeux nécessitant l'emploi d'une réfrigération, p. ex. de l'hélium, de l'hydrogène
79.
HYDROSTATIC BAILER AND LEAD IMPRESSION BLOCK COMBINATION TOOL FOR DOWNHOLE FISH DIAGNOSIS AND SOLIDS STRIPPING THROUGH SAMPLE COLLECTION
An apparatus includes a hydrostatic bailer and a lead impression block. The hydrostatic bailer is disposed in the well and removes debris from the fish using a plunger, a shear pin, and a valve. The valve controls hydraulic communication between an orifice of a hollow body of the valve and a cavity of the hydrostatic bailer by opening and closing. The shear pin is configured to shear and allow the plunger to move within the hydrostatic bailer to open the valve and remove the debris from the fish. The lead impression block is connected to the hollow body of the valve in the hydrostatic bailer. The lead impression block is configured to set against the fish, using the hydrostatic bailer, and obtain an impression of the fish on a single run into the well in which the debris is removed from the fish.
E21B 47/098 - Localisation ou détermination de la position d'objets dans les trous de forage ou dans les puitsIdentification des parties libres ou bloquées des tubes utilisant des garnitures d'empreinte, p. ex. pour détecter des enfoncements ou des perforations
Methods, apparatus, and systems for determining a level of a liquid in a liquid-containing vessel are disclosed. The liquid-containing vessel may be fluidically connected to a displacer cage. The method may include obtaining, with a load measurement device, a weight force of a displacer suspended from the load measurement device and disposed within the displacer cage. The method may also include submerging the displacer into the liquid and obtaining, with the load measurement device, a net force acting on the displacer. The method may further include obtaining, with a liquid density measurement sensor disposed within the displacer cage, a liquid density at a first location of the liquid. The method may still further include determining, using, at least, the net force and the liquid density at the first location of the liquid, the level of the liquid in the vessel.
G01F 23/04 - Indication ou mesure du niveau des liquides ou des matériaux solides fluents, p. ex. indication en fonction du volume ou indication au moyen d'un signal d'alarme par des éléments plongeants, p. ex. réglettes-jauges
G01F 23/16 - Indication ou mesure du niveau des liquides ou des matériaux solides fluents, p. ex. indication en fonction du volume ou indication au moyen d'un signal d'alarme par mesurage de la pression les dispositifs d'indication, d'enregistrement ou d'alarme étant actionnés par des moyens mécaniques ou hydrauliques, p. ex. en utilisant un gaz, du mercure ou un diaphragme comme élément de transmission, ou par une colonne de liquide
G01F 23/80 - Dispositions pour le traitement des signaux
G01F 25/20 - Test ou étalonnage des appareils pour la mesure du volume, du débit volumétrique ou du niveau des liquides, ou des appareils pour compter par volume des appareils pour mesurer le niveau des liquides
A cement swell packer includes a base tubular that includes at least one end connection; a cement swell assembly configured to mount on the base tubular and including a portion of a dry cementitious material configured to form a hardenable or curable cement when exposed to a fluid in a wellbore, and a mesh configured to hold the portion of the dry cementitious material; and a liquid barrier formed over the dry cementitious material.
An electrical submersible pump (ESP) power cable includes a sheathing including a body that includes at least one conductor bore formed therethrough; and at least one power conductor threaded through the at least one conductor bore. The power cable has a density sufficient for the power cable to be at least substantially neutrally buoyant in a wellbore fluid in a wellbore.
E21B 43/12 - Procédés ou appareils pour commander l'écoulement du fluide extrait vers ou dans les puits
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
H01B 7/04 - Câbles, conducteurs ou cordons flexibles, p. ex. câbles traînants
Described is a method for identifying hydrocarbon fields using genomic data. Soil samples are obtained from a geographic site, and genetic analysis is performed on the soil samples to obtain genome sequence data. Gene detection is performed on the genome sequence data to determine genes present in the soil samples. Protein sequences corresponding to the determined genes are determined and used to determine the presence of proteins involved in hydrocarbon metabolization in the soil samples.
Methods and systems for correcting a seismic dataset are disclosed. The methods may include receiving a seismic dataset comprising a plurality of traces and sorting the plurality of traces into a plurality of bins, wherein each bin comprises a range of seismic source-seismic receiver midpoint locations, range of offsets, and range of azimuths. The methods may also include, for each of the plurality of bins determining a pilot trace based on a plurality of sorted traces in the bin, selecting a pilot refraction window and a pilot reflection window from the pilot trace; selecting for each of the plurality of sorted traces, a refraction window and a reflection window from the sorted trace, determining a correction value based on the refraction window, the pilot refraction window, the reflection window and the pilot reflection window; and determining a corrected trace by applying the correction value to the trace.
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
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
Various measurement devices, systems including measurement devices, and methods for using measurement devices are discussed. As one of many examples, a measurement device is discussed that includes: a mesh configured to allow a ground material in contact with the measurement device pass through the mesh, a motion sensor coupled to the mesh, a drive system coupled to the mesh, and an operational sensor coupled to the mesh.
Implementations of the present disclosure includes a testing apparatus that includes a base, multiple threaded studs, and a plate. The base has a body defining a flat surface and multiple apertures each arranged to receive an electrode extending through a respective one of the apertures into soil disposed beneath the base. The threaded studs are rotationally coupled to the base. The plate is threadedly coupled to the threaded studs such that rotation of the threaded studs changes an elevation of the plate with respect to the base. The plate includes a lowermost surface facing the base and an uppermost surface facing away from the base and arranged to receive a load. The lowermost surface is coupled to an end of each electrode such that, as the plate changes in elevation, each electrode moves through its respective aperture, changing a position of each electrode with respect to the soil.
A self-healing cement structure may be used for repairing defects. An example method of using such a cement structure includes: providing a cement structure in a wellbore, wherein the cement structure includes: a cement and elastomer particles at 1% by weight of the cement (bwoc) to 25% bwoc; applying heat to the cement structure to heat at least a portion of the elastomer particles above a melting point of an elastomer of the elastomer particles to cause at least a portion of the elastomer to melt and infiltrate into a defect in the cement structure; and allowing the elastomer to cool below the melting point of the elastomer to yield a repaired cement structure.
A composition comprising a promotor component is disclosed comprising a mixture of one or more catalytically active components and one or more oxidized disulfide oil (ODSO) compounds, including a water-soluble fraction of ODSO. A composition comprising an aqueous solution of one or more catalytically active components and a promotor component is also disclosed. In certain embodiments the ODSO is obtained from the effluent of an enhanced MEROX process. The compositions facilitate transfer of catalytically active components (or components that will be catalytically active in the finished solid catalyst material) onto the surface of support materials.
A system for reducing internal combustion engine emissions includes an engine, a catalytic converter fluidly connected to a combustion chamber via an exhaust line, a glow plug positioned along the exhaust line between the catalytic converter and the combustion chamber, and a flame accelerator, without a fluid connection to a separate fuel supply. Methods of using the system include igniting a mixture of air and fuel in the exhaust line using the glow plug, producing an amount of heated combustion gas.
F01N 3/20 - Silencieux ou dispositifs d'échappement comportant des moyens pour purifier, rendre inoffensifs ou traiter les gaz d'échappement pour rendre les gaz d'échappement inoffensifs par conversion thermique ou catalytique des composants nocifs des gaz d'échappement caractérisés par les méthodes d'opérationCommande spécialement adaptés à la conversion catalytique
Methods for treating a kerogen-containing subterranean formation including providing a slickwater fluid comprising formate, present in a molality ranging from about 1.5 to about 15.0; and at least one oxidant; and, introducing the slickwater fluid into a subterranean formation comprising kerogen.
C09K 8/58 - Compositions pour les méthodes de récupération assistée pour l'extraction d'hydrocarbures, c.-à-d. pour améliorer la mobilité de l'huile, p. ex. fluides de déplacement
C09K 8/588 - Compositions pour les méthodes de récupération assistée pour l'extraction d'hydrocarbures, c.-à-d. pour améliorer la mobilité de l'huile, p. ex. fluides de déplacement caractérisées par l'utilisation de polymères spécifiques
C09K 8/594 - Compositions utilisées en combinaison avec du gaz injecté
C09K 8/68 - Compositions à base d'eau ou de solvants polaires contenant des composés organiques
91.
SYSTEM AND METHOD FOR MONITORING DOWNHOLE OPERATION
Systems and methods are discussed for characterizing usage of an operating tool configured for use within a wellbore. As an example, a system (200) is discussed that includes detecting system (210) and a processing device (220). The processing device (220) receives information from the detecting system (210) and may use the information to, for example, determine an efficiency using the time period for each of a plurality of tool gestures and a respective expected time period for each of the plurality of tool gestures.
Described is a method (300) for identifying hydrocarbon fields using genomic data. Soil samples are obtained (302) from a geographic site, and genetic analysis is performed (304) on the soil samples to obtain genome sequence data. Gene detection is performed (306) on the genome sequence data to determine genes present in the soil samples. Protein sequences corresponding to the determined genes are determined (308) and used to determine (310) the presence of proteins involved in hydrocarbon metabolization in the soil samples.
Various methods, systems, and devices for investigating welds are discussed. As an example, a method for investigating a weld (110) is discussed that includes: automatically configuring, by a controller (160), a plurality of acoustic sensors arranged across a face of a phased array device (130) to sense reflected acoustic signals; automatically configuring, by the controller (160), acoustic sources arranged across the face of the phased array device (130) to emit sent acoustic signals across an angular range from 40 degrees to 70 relative to the face; moving the phased array device (130) across a surface of an examined article (100) comprising the weld (110), where the face moves parallel to the surface of the examined article (100); detecting, by the acoustic sensors, the reflected acoustic signals, where the reflected acoustic signals comprise a subset of the sent acoustic signals reflected off of the weld; and displaying, by the controller (160), an image of the weld (110) corresponding to the reflected acoustic signals.
A system includes a packer (304) sealed against a casing string (108) deployed in the well, production tubing (152) extending through the packer (304) and configured to transport the production fluids (102) to a surface location, and an electric submersible pump (124) connected to the production tubing (152) at a location downhole from the packer (304). The electric submersible pump is configured to pump the production fluids (102) through the production tubing (152). The system further comprises a gas activated vent valve (300) installed on the production tubing (152) at a location downhole from the packer (304) and configured to open using a pressure exerted on the gas activated vent valve (300) by the gas (132) and a vent line (302) connected to an outlet (312) of the gas activated vent valve (300), extending through the packer (304), and configured to transport the gas (132) from the gas activated vent valve (300) to the surface location when the gas activated vent valve (300) is opened by the gas (132).
E21B 43/12 - Procédés ou appareils pour commander l'écoulement du fluide extrait vers ou dans les puits
E21B 43/38 - Aménagements pour séparer les matériaux produits par le puits dans le 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
95.
NATURAL GAS LIQUIDS QUALITY DIGITALIZED ANALYTICS AND PREDICTIVE SOLUTION
A Natural Gas Liquids (NGL) quality digitalized analytics and predictive solution computer-implemented method includes extracting, automatically and in real-time as measured data from elements of a natural gas liquids (NGL) network, values for operating parameters and quality parameters. The measured data is compared against maximum limits. If the comparison indicates the measured data is within limit: 1) normal operations continue and 2) performance is reported. If the comparison is not within limit: 1) an alert notification is issued; 2) an investigation is conducted via trending and root-cause analysis; and 3) corrective and mitigation actions are performed.
KING ABDULLAH UNIVERSITY OF SCIENCE AND TECHNOLOGY (Arabie saoudite)
ARAMCO SERVICES COMPANY (USA)
Inventeur(s)
He, Xupeng
Rao, Xiang
Kwak, Hyung Tae
Hoteit, Hussein
Abrégé
A method for performing fluid extraction from a fractured subsurface formation includes receiving a discrete fracture model representing the fractured subsurface formation and receiving pressure values and saturation values for multiple fluid phases across the discrete fracture model. Based on the pressure values for the multiple fluid phases across the discrete fracture model, face-centroid velocities are generated for the cells and the pressure values for the multiple fluid phases are updated by performing operations including a mimetic finite difference analysis. Based on the generated face-centroid velocities, an exit face and time-of-flight is determined for each cell and the saturation values are updated for the multiple fluid phases across the discrete fracture model based on the exit face and time-of-flight for each cell.
Devices and methods for descaling a pipeline utilizing a hybrid tool assembly are provided. The hybrid tool assembly includes an assembly head body which includes a bottom surface connected to the circumferential surface. The bottom surface defines an acid jetting opening, a water jetting opening, a gas purge opening and a laser opening. An acid jetting subassembly is fluidically coupled to the acid jetting opening and configured to jet acid onto the scales. A water jetting subassembly is fluidically coupled to the water jetting opening and configured to jet water. A gas purge subassembly is fluidically coupled to the gas purge opening and configured to purge gas. A laser subassembly is functionally coupled to the laser opening and configured to generate a laser beam. The gas purge subassembly is configured to operate together with at least one of the acid jetting subassembly, the water jetting subassembly or the laser subassembly.
B08B 7/00 - Nettoyage par des procédés non prévus dans une seule autre sous-classe ou un seul groupe de la présente sous-classe
B08B 7/04 - Nettoyage par des procédés non prévus dans une seule autre sous-classe ou un seul groupe de la présente sous-classe par une combinaison d'opérations
B08B 9/032 - Nettoyage des surfaces intérieuresÉlimination des bouchons par l'action mécanique d'un fluide en mouvement, p. ex. par effet de chasse d'eau
98.
CLOSED COMPARTMENT WELL TOOL FOR WELLHEAD RE-PACKING
A well tool assembly well tool includes a coupling subassembly (102) and a supporting subassembly (106) coupled to the coupling subassembly. The coupling subassembly is configured to couple to a pressure port positioned on an above-surface portion of a wellhead of a wellbore. The coupling subassembly includes a body configured to sealingly couple to the pressure port on the wellhead. The supporting subassembly includes a first plate (108) and a second plate (110), each configured to couple to the portion of the wellhead above and below the pressure port, respectively. The supporting subassembly is configured to orient the body between the first plate and the second plate to couple to the pressure port and to support a weight of the coupling subassembly.
An opening cone for a mechanical stage collar is used during a cementing operation in a wellbore. The mechanical stage collar includes ports activated by the opening cone. The opening cone includes a cylindrical midsection and a conical end section defining a hollow path through the opening cone and a ball suspended in a cage in the cylindrical midsection between a first profile with a first set of ribs and a second profile with a second set of ribs. The second profile is disposed downhole of the first profile and the second set of ribs is pressure rated to rupture at a predetermined pressure and release the ball into the conical end section. The ball is configured to plug the hollow path of the opening cone when released into the conical end section to stop flow through the hollow path.
E21B 33/16 - 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 utilisant des bouchons pour isoler la charge de cimentBouchons à cet effet
A flowmeter includes an inlet for receiving a wellbore fluid therein, an outlet for discharging the wellbore fluid and a stationary interior wall extending between the inlet and the outlet. A plurality of movable walls within the stationary interior wall defines a flow path therethrough. Each movable wall defines a threaded section on a first lateral end and rotatably supports an adjustment beam on a second lateral end. The adjustment beams include threads engaged with the threaded section of an adjacent movable wall. An actuator is operably coupled to an adjustment beam to rotate the adjustment beam and thereby drive the second lateral sides of the movable walls along the threaded sections of adjacent movable walls and adjust a diameter of the flow path. A sensor is operable to detect a parameter indicative of the pressures of the wellbore fluid from which a flowrate of the wellbore fluid may be determined.
