KING FAHD UNIVERSITY OF PETROLEUM & MINERALS (Arabie saoudite)
Inventeur(s)
Kalgaonkar, Rajendra Arunkumar
Alali, Eyad
Bataweel, Mohammed Abudallah
Ullah, Nisar
Mansha, Muhammad
Abrégé
A fracturing fluid may include a first surfactant and a second surfactant. The first surfactant may have a structure represented by formula (I):
A fracturing fluid may include a first surfactant and a second surfactant. The first surfactant may have a structure represented by formula (I):
A fracturing fluid may include a first surfactant and a second surfactant. The first surfactant may have a structure represented by formula (I):
wherein m is an integer ranging from 2 to 3, and n, o, and k are each, independently, integers ranging from 2 to 10. The second surfactant having a structure represented by Formula (II):
A fracturing fluid may include a first surfactant and a second surfactant. The first surfactant may have a structure represented by formula (I):
wherein m is an integer ranging from 2 to 3, and n, o, and k are each, independently, integers ranging from 2 to 10. The second surfactant having a structure represented by Formula (II):
A fracturing fluid may include a first surfactant and a second surfactant. The first surfactant may have a structure represented by formula (I):
wherein m is an integer ranging from 2 to 3, and n, o, and k are each, independently, integers ranging from 2 to 10. The second surfactant having a structure represented by Formula (II):
wherein R2 is a C15-C27 hydrocarbon group or a C15-C29 substituted hydrocarbon group, R3 is a C1-C10 hydrocarbon group, and p and q are each, independently, an integer ranging from 1 to 4. Methods of treating a hydrocarbon-bearing formation include injecting the fracturing fluid in the hydrocarbon-bearing formation, the fracturing fluid being configured to transport a proppant in fractures of the hydrocarbon-bearing formation.
A rotatable plate is configured to be coupled to a rotary table of a rig floor. The rotatable plate defines a central passage through which a tubular can be passed. Multiple arms each have a first end rotably coupled to the rotatable plate. The arms are hinged such that a distal end of the arms, away from the rotatable plate, are configured to move towards or away from the passage. Each of arms extends away from the rotatable plate towards the passage. The arms are biased away from the passage. Rollers are rotably coupled to one of the distal ends of the arms.
A feed stream is flowed to a catalytic reactor. The catalytic reactor includes a non-thermal plasma and a catalyst. The feed stream includes hydrogen sulfide and carbon dioxide. The feed stream is contacted with the catalyst in the presence of the non-thermal plasma at a reaction temperature, thereby converting the hydrogen sulfide and the carbon dioxide in the feed stream to produce a product. The product includes a hydrocarbon and sulfur. The product is separated into a product stream and a sulfur stream. The product stream includes the hydrocarbon from the product. The sulfur stream includes the sulfur from the product.
C07C 1/12 - Préparation d'hydrocarbures à partir d'un ou plusieurs composés, aucun d'eux n'étant un hydrocarbure à partir d'oxydes de carbone à partir d'anhydride carbonique avec de l'hydrogène
C01B 17/04 - Préparation du soufre; Purification à partir de composés sulfurés gazeux, y compris les sulfures gazeux
B01J 8/00 - Procédés chimiques ou physiques en général, conduits en présence de fluides et de particules solides; Appareillage pour de tels procédés
4.
SYSTEM AND METHOD FOR AUTOMATED DRILL CUTTING SAMPLING, PREPARATION, ANALYSIS, AND PACKAGING
A modular system for analyzing drilled cuttings includes a sampler unit, a washer unit, an analysis unit, and a central processing unit. The sampler unit receives the drilled cuttings from a shale shaker disposed on a rig site that obtains the drilled cuttings. The washer unit removes debris from the drilled cuttings. The analysis unit determines lithological properties of the drilled cuttings. The packager unit packages the drilled cuttings. The central processing unit coordinates operations to process the drilled cuttings through each of the sampler unit, washer unit, analysis unit and packager unit. The central processing unit facilitates a processing link among the sampler unit, washer unit, analysis unit and packager unit so that the sampler unit, washer unit, analysis unit and packager unit are integrated to form the modular system.
E21B 21/06 - Dispositions pour traiter les fluides de forage à l'extérieur du trou de forage
E21B 49/00 - Test pour déterminer la nature des parois des trous de forage; Essais de couches; Procédés ou appareils pour prélever des échantillons du terrain ou de fluides en provenance des puits, spécialement adaptés au forage du sol ou aux puits
An engine system includes an engine configured to combust liquid natural gas and generate an exhaust gas comprising methane; a catalytic reactor coupled downstream of the engine and configured to convert methane into a product through one or more of oxidative coupling of methane (OCM) reaction and steam methane reforming (SMR) reaction; and a recirculation loop configured to recirculate at least a part of the product back to the engine.
F01N 3/035 - Silencieux ou dispositifs d'échappement comportant des moyens pour purifier, rendre inoffensifs ou traiter les gaz d'échappement pour refroidir ou pour enlever les constituants solides des gaz d'échappement au moyen de filtres en combinaison avec d'autres dispositifs avec des réacteurs catalytiques
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'opération; Commande spécialement adaptés à la conversion catalytique
6.
METHOD FOR DETERMINING THE QUALITY OF CRUDE OIL EXITING A GAS-OIL SEPARATION PLANT OR CRUDE OIL PROCESSING PLANT
A method for determining the quality of crude oil exiting a gas-oil separation plant (GOSP) is disclosed. The GOSP comprises sensors that determine process parameters of the crude oil. The method involves determining, from the process parameters, WiO-parameters that depend on the concentration of water in the crude oil (WiO), determining virtual parameters of the crude oil, determining total parameters by adding the virtual parameters to the WiO-parameters. Further, a feedback loop involves changing one or more of the total parameters, determining the quality of the crude oil exiting the GOSP, wherein when the quality is improved, the change in the one or more total parameters is maintained, and when the quality is worsened, the change in the one or more total parameters is reversed. The feedback-loop is repeated as long as the quality of the crude oil exiting the GOSP increases.
G05B 13/04 - Systèmes de commande adaptatifs, c. à d. systèmes se réglant eux-mêmes automatiquement pour obtenir un rendement optimal suivant un critère prédéterminé électriques impliquant l'usage de modèles ou de simulateurs
Systems and methods for production for consistently sized and shaped petroleum coke from vacuum residue, one method including supplying processed vacuum residue to an extruder; heating the processed vacuum residue throughout a horizontal profile of the extruder from an inlet to an outlet of the extruder; venting hydrocarbon off-gases from the extruder along the horizontal profile of the extruder from the inlet to the outlet of the extruder; and cutting consistently sized and shaped petroleum coke at the outlet of the extruder.
King Abdullah University of Science and Technology (Arabie saoudite)
Inventeur(s)
Hodgkins, Robert Peter
Koseoglu, Omer Refa
Basset, Jean-Marie Maurice
Huang, Kuo-Wei
Sedjerari, Anissa Bendjeriou
Gangwar, Manoj K.
Murugesan, Sathiyamoorthy
Abrégé
Disclosed herein are modified zeolites and methods for making modified zeolites. In one or more embodiments disclosed herein, a modified zeolite may include a microporous framework comprising a plurality of micropores having diameters of less than or equal to 2 nm. The microporous framework may include at least silicon atoms and oxygen atoms. The modified zeolite may further include organometallic moieties each bonded to bridging oxygen atoms. The organometallic moieties may include a titanium atom. The titanium atom may be bonded to a bridging oxygen atom, and the bridging oxygen atom may bridge the titanium atom of the organometallic moiety and a silicon atom of the microporous framework.
C01B 39/40 - Type ZSM-5 utilisant au moins un agent structurant organique
B01J 29/40 - Zéolites aluminosilicates cristallines; Leurs composés isomorphes du type pentasil, p.ex. types ZSM-5, ZSM-8 ou ZSM-11
B01J 35/10 - Catalyseurs caractérisés par leur forme ou leurs propriétés physiques, en général solides caractérisés par leurs propriétés de surface ou leur porosité
B01J 35/02 - Catalyseurs caractérisés par leur forme ou leurs propriétés physiques, en général solides
B01J 37/02 - Imprégnation, revêtement ou précipitation
C01B 39/02 - Zéolites aluminosilicates cristallines; Leurs composés isomorphes; Leur préparation directe; Leur préparation à partir d'un mélange réactionnel contenant une zéolite cristalline d'un autre type, ou à partir de réactants préformés; Leur post-traitement
A method for determining sweet spots in a subterranean formation includes drilling a plurality of wellbores in the subterranean formation using a drill tool; lowering a logging tool in each of the plurality of wellbores to collect measurements; calculating a reservoir quality index parameter for each wellbore of the plurality of wellbores based on petrophysical logs; creating a reservoir quality index map using the petrophysical logs; calculating a linear flow index parameter for each wellbore of the plurality of wellbores based on production data provided by the petrophysical logs; correlating the reservoir quality index parameter and the linear flow index parameter for each wellbore of the plurality of wellbores to locate sweet spots; and ranking a basin based on the located sweet spots and the correlated parameters.
Computer-implemented stratigraphic play quality generation is disclosed. Stratigraphic data can be processed from each of a plurality of respective data sources to generate conditioned stratigraphic data. From at least some of the conditioned stratigraphic data, attributes of at least one seismic sequence can be extracted, and at least one seismic surface and at least one structural element associated with at least some of the conditioned stratigraphic data can be determined. At least some of the conditioned stratigraphic data representing sedimentary layers can be correlated with seismic reflection data to ascertain a subsurface of the geologic area at a respective depth. Reservoir properties associated with the geologic area are linked to elastic properties, and a 2D model built. Moreover, 3D map can be generated that is usable for a prospective drilling plan.
This disclosure presents a method and an apparatus for improving production performance of a well using a drill stem test tool (DSTT). The method includes isolating a zone of interest in the wellbore, then reducing and recording pressure inside the drill string while recording acoustic emissions from the sensors on the DSTT, then correlating the recordings of the acoustic emissions with the pressure. The method includes using the processed acoustic emissions to determine a candidate sound of interest and a pressure at which the candidate sound of interest is recorded, then comparing the candidate sound of interest with a reference lookup table of known lithology classifications. The method includes determining a collapse pressure of the wellbore using the lithology of the wellbore and the pressure at which the candidate sound of interest is recorded.
A feed stream is flowed to a catalytic reactor. The catalytic reactor includes a non-thermal plasma and a catalyst. The feed stream includes hydrogen sulfide and carbon dioxide. The feed stream is contacted with the catalyst in the presence of the non-thermal plasma at a reaction temperature, thereby converting the hydrogen sulfide and the carbon dioxide in the feed stream to produce a product. The product includes a hydrocarbon and sulfur. The product is separated into a product stream and a sulfur stream. The product stream includes the hydrocarbon from the product. The sulfur stream includes the sulfur from the product.
F01N 3/10 - 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
C07C 1/02 - Préparation d'hydrocarbures à partir d'un ou plusieurs composés, aucun d'eux n'étant un hydrocarbure à partir d'oxydes de carbone
F02M 21/02 - Appareils pour alimenter les moteurs en combustibles non liquides, p.ex. en combustibles gazeux stockés sous forme liquide en combustibles gazeux
B01D 53/14 - SÉPARATION Épuration chimique ou biologique des gaz résiduaires, p.ex. gaz d'échappement des moteurs à combustion, fumées, vapeurs, gaz de combustion ou aérosols par absorption
A system for well control during tripping phases in drilling operations in a wellbore, the system comprising: a drill string extending from an entry of the wellbore to a drill bit at a distal end of the drill string within the wellbore; a near bit sub mounted along the drill string adjacent to the drill bit; a first smart multi-directional two-way check valve mounted along the drill string adjacent to the near bit sub; and a controller configured to operate the valve. The controller controls the valve to apply suction or discharge flow to the near bit sub to counter inertial effects of drilling mud viscosity within the wellbore.
E21B 21/08 - Commande ou surveillance de la pression ou de l'écoulement du fluide de forage, p.ex. remplissage automatique des trous de forage, commande automatique de la pression au fond
E21B 21/10 - Aménagements des vannes dans les systèmes de circulation des fluides de forage
E21B 34/10 - Aménagements des vannes pour les trous de forage ou pour les puits dans les puits actionnés par un fluide de commande provenant de l'extérieur du trou de forage
E21B 34/16 - Moyens de commande situés à l'extérieur du trou de forage
14.
METHOD AND SYSTEM FOR CONNECTING FORMATION FRACTURES USING FRACBOTS
A fracbot for fracturing a formation, comprising: a drill bit; a rotary swivel configured to rotate the drill bit; a motor configured to induce vibrations that create a spiral movement of the fracbot, wherein the spiral movement of the fracbot allows the fracbot to traverse existing fractures in the formation comprising a first fracture and a second fracture; a battery configured to power the fracbot; and a coating encompassing the fracbot configured to dissolve at a predefined temperature, wherein the fracbot is configured to create a channel that connects the first fracture and the second fracture.
Systems and methods of production for consistently sized and shaped optically anisotropic mesophase pitch from vacuum residue, one method including supplying processed vacuum residue to an extruder; heating the processed vacuum residue throughout a horizontal profile of the extruder from an inlet to an outlet of the extruder; venting hydrocarbon off-gases from the extruder along the horizontal profile of the extruder from the inlet to the outlet of the extruder; and physically shaping the consistently sized and shaped mesophase pitch at the outlet of the extruder for production of carbon fibers.
C10B 57/00 - Autres procédés de carbonisation ou de cokéfaction; Caractéristiques générales des procédés de distillation destructive
D01F 9/155 - Filaments de carbone; Appareils spécialement adaptés à leur fabrication par décomposition de filaments organiques à partir de brai ou de résidus de distillation à partir de brai de pétrole
C10B 57/04 - Autres procédés de carbonisation ou de cokéfaction; Caractéristiques générales des procédés de distillation destructive utilisant des charges de composition spéciale
A stuffing box for sealing a top opening of a vertical pump, including: a housing with a vertical tube for rotatably disposing a shaft of the vertical pump, an annular bearing that: divides the vertical tube in a lower half and an upper half, and fills an annular space between an inner wall of the vertical tube and the shaft, such that as less fluid as possible passes from the lower half through the annular bearing to the upper half, an outlet pipe for discharging the fluid passing through the annular bearing.
A method and a system for the coproduction of hydrogen, electrical power, and heat energy. An exemplary method includes desulfurizing a feed stream to form a desulfurized feed stream, reforming the desulfurized feed stream to form a methane rich gas, and providing the methane rich gas to a membrane separator. A hydrogen stream is produced in a permeate from the membrane separator. A retentate stream from the membrane separator is provided to a solid oxide fuel cell (SOFC). Electrical power is produced in the SOFC from the retentate stream.
H01M 8/0612 - Combinaison d’éléments à combustible avec des moyens de production de réactifs ou pour le traitement de résidus avec des moyens de production des réactifs gazeux à partir de matériaux contenant du carbone
H01M 8/1231 - PROCÉDÉS OU MOYENS POUR LA CONVERSION DIRECTE DE L'ÉNERGIE CHIMIQUE EN ÉNERGIE ÉLECTRIQUE, p.ex. BATTERIES Éléments à combustible; Leur fabrication Éléments à combustible avec électrolytes solides fonctionnant à haute température, p.ex. avec un électrolyte en ZrO2 stabilisé avec les deux réactifs gazeux ou vaporisés
B01D 53/04 - SÉPARATION Épuration chimique ou biologique des gaz résiduaires, p.ex. gaz d'échappement des moteurs à combustion, fumées, vapeurs, gaz de combustion ou aérosols par adsorption, p.ex. chromatographie préparatoire en phase gazeuse avec adsorbants fixes
B01D 53/22 - SÉPARATION Épuration chimique ou biologique des gaz résiduaires, p.ex. gaz d'échappement des moteurs à combustion, fumées, vapeurs, gaz de combustion ou aérosols par diffusion
C01B 3/48 - 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 suivie par une réaction de la vapeur d'eau avec l'oxyde de carbone
C01B 3/56 - Séparation de l'hydrogène ou des gaz contenant de l'hydrogène à partir de mélanges gazeux, p.ex. purification par contact avec des solides; Régénération des solides usés
H01M 8/04014 - Dispositions auxiliaires, p.ex. pour la commande de la pression ou pour la circulation des fluides relatives à l’échange de chaleur Échange de chaleur par combustion des réactifs
H01M 8/0662 - Traitement des réactifs gazeux ou des résidus gazeux, p.ex. nettoyage
C01B 3/50 - Séparation de l'hydrogène ou des gaz contenant de l'hydrogène à partir de mélanges gazeux, p.ex. purification
18.
NON-COMINGLED CONCENTRIC TUBING PRODUCTION FROM TWO DIFFERENT RESERVOIRS
An apparatus for obtaining fluids via a well is disclosed. The apparatus includes an outer tubing disposed in the well and set at a shallow reservoir comprising a first fluid, an inner tubing disposed concentrically within the outer tubing and set at a deeper reservoir further downhole than the shallow reservoir, the deeper reservoir comprising a second fluid, a first packer disposed between the outer tubing and an external tubing and disposed above the shallow reservoir, and a second packer disposed between the outer tubing and the inner tubing and disposed above the deeper reservoir, wherein the second packer blocks an annulus through which the first fluid is extracted via the outer tubing. The first fluid is obtained from the shallow reservoir and the second fluid is obtained from the deeper reservoir by drilling via the well.
A conduit inspection tool system includes a conduit inspection tool that includes a body that includes one or more wheels configured to move the body through and in contact with a conduit; at least two power generating sub-systems coupled to the body, each of the at least two power generating sub-systems configured to generate electrical power to operate the one or more wheels to move the body through and in contact with the conduit; and at least one energy storage device electrically coupled to the at least two power generating sub-systems, the at least one energy storage device configured to store electrical power generated by the at least two power generating sub-systems; and a control system communicably coupled to the at least two power generating sub-systems and the at least one energy storage device.
H02K 7/02 - Masses additionnelles pour augmenter l'inertie, p.ex. volants
H02K 7/116 - Association structurelle avec des embrayages, des freins, des engrenages, des poulies ou des démarreurs mécaniques avec des engrenages
B60L 50/30 - Propulsion électrique par source d'énergie intérieure au véhicule utilisant de la puissance de propulsion emmagasinée mécaniquement, p.ex. par un volant
B60L 50/90 - Propulsion électrique par source d'énergie intérieure au véhicule utilisant de la puissance de propulsion fournie par des moyens spécifiques non couverts par les groupes , p.ex. par la conversion directe de l'énergie nucléaire thermique en électricité
B60L 50/53 - Propulsion électrique par source d'énergie intérieure au véhicule utilisant de la puissance de propulsion fournie par des batteries ou des piles à combustible en combinaison avec une alimentation externe, p.ex. par des lignes aériennes de contact
B60L 50/60 - Propulsion électrique par source d'énergie intérieure au véhicule utilisant de la puissance de propulsion fournie par des batteries ou des piles à combustible utilisant de l'énergie fournie par des batteries
B08B 9/049 - Nettoyage de conduites ou de tubes ou des systèmes de conduites ou de tubes Élimination des bouchons utilisant des dispositifs de nettoyage introduits dans et déplacés le long des tubes les dispositifs de nettoyage comportant des moyens autopropulseurs pour se déplacer dans les tubes
F16L 55/32 - Moyens de propulsion autonomes portés par le hérisson ou le chariot
20.
SLICKWATER HYDRAULIC FRACTURING WITH EXOTHERMIC REACTANTS
Compositions and methods for increasing a stimulated reservoir volume in a hydrocarbon-bearing formation in fluid communication with a wellbore, one method including drilling a plurality of lateral extensions at varying depths in the formation extending from a vertical wellbore using slickwater hydraulic fracturing fluid, the slickwater hydraulic fracturing fluid comprising at least one friction reducer; and injecting an exothermic reaction component into the plurality of lateral extensions to create a plurality of fractures extending outwardly from and between the plurality of lateral extensions to create a multilateral fracture network.
E21B 37/06 - Procédés ou appareils pour nettoyer les trous de forage ou les puits utilisant des moyens chimiques pour empêcher ou limiter le dépôt de paraffine ou de substances analogues
21.
IN-SITU WETTABILITY MEASUREMENT USING MULTIPLE PARTITIONING TRACERS
A method includes developing a lab-scale representative correlation between wettability index and tracer test return curve data for core samples, obtaining tracer test return curve data for rock at a well of interest, and determining a wettability index of the rock in situ using the representative correlation and the tracer test return curve data for the well. A method includes obtaining core samples of a rock representative of a formation of interest, determining a wettability index of each of the core samples, performing a tracer test on each of the core samples and obtaining tracer return curve data for each of the core samples, building a correlation between the wettability index and the tracer return curve data of the core samples, running a single-well tracer test at a well, obtaining tracer return curve data for the well, and determining a wettability index for the rock of the well.
E21B 47/11 - Localisation des fuites, intrusions ou mouvements du fluide utilisant la radioactivité
G01N 13/00 - Recherche des effets de surface ou de couche limite, p.ex. pouvoir mouillant; Recherche des effets de diffusion; Analyse des matériaux en déterminant les effets superficiels, limites ou de diffusion
Upstream process equipment (102) transmits a predetermined fluid to downstream process equipment (103). A valve (109) fluidly couples the upstream process equipment (102) to the downstream process equipment (103). A first pressure sensor (104) and a first temperature sensor (105) are coupled to the upstream process equipment (102) and upstream from the valve (109). A second pressure sensor (106) and a second temperature sensor (107) are coupled to the downstream process equipment (103) and downstream from the valve (109). A control system (101) is coupled to the first pressure sensor (104), the first temperature sensor (105), the second pressure sensor (106), and the second temperature sensor (107). The control system (101) determines a first fluid flowrate (108) of the predetermined fluid using a fluid flow model (110) based on pressure data (112, 113) from the first pressure sensor (104) and the second pressure sensor (106), temperature data (112, 113) from the first temperature sensor (105) and the second temperature sensor (107), a size of the valve (109), at least one fluid parameter (111) regarding the predetermined fluid, and a valve flow coefficient of the valve (109).
G01F 1/36 - Mesure du débit volumétrique ou du débit massique d'un fluide ou d'un matériau solide fluent, dans laquelle le fluide passe à travers un compteur par un écoulement continu en utilisant des effets mécaniques en mesurant la pression ou la différence de pression la pression ou la différence de pression étant produite par une contraction de la veine fluide
G01F 15/08 - Séparateurs d'air ou de gaz en combinaison avec des compteurs de liquides; Séparateurs de liquide en combinaison avec des compteurs de gaz
E21B 43/34 - Aménagements pour séparer les matériaux produits par le puits
G01F 15/00 - MESURE DES VOLUMES, DES DÉBITS VOLUMÉTRIQUES, DES DÉBITS MASSIQUES OU DU NIVEAU DES LIQUIDES; COMPTAGE VOLUMÉTRIQUE - Détails des appareils des groupes ou accessoires pour ces derniers, dans la mesure où de tels accessoires ou détails ne sont pas adaptés à ces types particuliers d'appareils, p.ex. pour l'indication à distance
System and methods for delivering objects formed of a solid material into a circulation fluid of a subterranean well include a volume transfer container (58). The volume transfer container has an inlet port (60), an outlet port (62), and a charge access opening sized to provide for the filling of the volume transfer container with the objects. A discharge line extends from a pump assembly (72) to the volume transfer container (58). A transfer line (52) extends from the volume transfer container (58) to the drilling assembly, providing a fluid flow path from the volume transfer container to the drilling assembly (36) that is free of any pump.
E21B 21/00 - Procédés ou appareils pour nettoyer les trous de forage par jet de fluide, p.ex. en utilisant l'air d'échappement du moteur
E21B 33/138 - Plâtrage de la paroi du trou de forage; Injections dans la formation
E21B 21/06 - Dispositions pour traiter les fluides de forage à l'extérieur du trou de forage
C09K 8/50 - Compositions pour le plâtrage des parois de trous de forage, c. à d. compositions pour la consolidation temporaire des parois des trous de forage
24.
MULTIMODAL APPROACH TO TARGET STRATIGRAPHIC PLAYS THROUGH SEISMIC SEQUENCE STRATIGRAPHY, ROCK PHYSICS, SEISMIC INVERSION AND MACHINE LEARNING
Computer-implemented stratigraphic play quality generation is disclosed. Stratigraphic data can be processed from each of a plurality of respective data sources to generate conditioned stratigraphic data. From at least some of the conditioned stratigraphic data, attributes of at least one seismic sequence can be extracted, and at least one seismic surface and at least one structural element associated with at least some of the conditioned stratigraphic data can be determined. At least some of the conditioned stratigraphic data representing sedimentary layers can be correlated with seismic reflection data to ascertain a subsurface of the geologic area at a respective depth. Reservoir properties associated with the geologic area are linked to elastic properties, and a 2D model built. Moreover, 3D map can be generated that is usable for a prospective drilling plan.
A system for sidewall coring includes a sidewall coring tool lowered into a wellbore for positioning a coring bit inside a subterranean formation, an injection assembly, and an array of sensors. The coring bit is capable of collecting a core sample by rotating with respect to a housing of the sidewall coring tool. The injection assembly injects a plurality of fluids into a sidewall core and is configured to selectively inject a plurality of fluids into the core sample. The array of sensors is embedded within a sidewall cutter enclosure for recording measurements during an injection process. The array of sensors produces information relating to the core sample.
E21B 49/06 - Test pour déterminer la nature des parois des trous de forage; Essais de couches; Procédés ou appareils pour prélever des échantillons du terrain ou de fluides en provenance des puits, spécialement adaptés au forage du sol ou aux puits par prélèvements mécaniques d'échantillons du terrain au moyen d'outils de forage latéral ou de dispositifs de raclage
26.
CUTTING PIPES IN WELLBORES USING DOWNHOLE AUTONOMOUS JET CUTTING TOOLS
A downhole autonomous jet cutting tool includes a main body with a generally cylindrical configuration. The main body includes a locking unit actuable to engage the tool to an inner surface of the pipe, a hydraulic motor with a rotor and a stator, and a rotatable jet cutting nozzle assembly operable to emit a stream of fluid to cut the pipe. The tool also includes a sensor module to detect interactions between the pipe and walls of the wellbore and a control unit in electronic communication with the sensor module and the locking unit. The control unit can identify, based on output of the sensor module, a location where interaction between the pipe and the walls of the wellbore limits downhole movement of the pipe, actuate the locking unit to engage the tool in the inner surface of the pipe, and initiate the stream of fluid from the nozzle assembly.
E21B 29/00 - Découpage ou destruction de tubes, packers, bouchons ou câbles, situés dans les trous de forage ou dans les puits, p.ex. découpage de tubes endommagés, de fenêtres; Déformation des tubes dans les trous de forage; Remise en état des tubages de puits sans les retirer du sol
E21B 47/09 - Localisation ou détermination de la position d'objets dans les trous de forage ou dans les puits; Identification des parties libres ou bloquées des tubes
E21B 29/02 - Découpage ou destruction de tubes, packers, bouchons ou câbles, situés dans les trous de forage ou dans les puits, p.ex. découpage de tubes endommagés, de fenêtres; Déformation des tubes dans les trous de forage; Remise en état des tubages de puits sans les retirer du sol au moyen d'explosifs ou par des moyens thermiques ou chimiques
A method may include obtaining first nuclear magnetic resonance (NMR) data for a saturated core sample regarding a geological region of interest. The method may further include determining, using the first NMR data, spatial porosity data based on the saturated core sample. The spatial porosity data may describe various porosity values as a function of a sampling position of the saturated core sample. The method may further include obtaining second NMR data for a desaturated core sample regarding the geological region of interest. The method may further include determining, using the second NMR data, spatial permeability data based on the desaturated core sample. The method may further include determining a geological model for the geological region of interest using the spatial porosity data, the spatial permeability data, and a fitting process.
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
E21B 49/00 - Test pour déterminer la nature des parois des trous de forage; Essais de couches; Procédés ou appareils pour prélever des échantillons du terrain ou de fluides en provenance des puits, spécialement adaptés au forage du sol ou aux puits
The present disclosure concerns a cement dispersant for cement compositions wherein the cement dispersant is a polynaphthalene sulfonate salt having a weight average molecular weight of from 2500 g/mol to 3000 g/mol. The cement compositions are of from 10 weight percent to 70 weight percent of a cement precursor based on the total weight of the cement composition, from 5 weight percent to 70 weight percent water based on the total weight of the cement composition, and from 0.001 percent by weight of cement (BWOC) to 1.0 percent BWOC the cement dispersant. The cement dispersant provides improved rheological properties, allowing for good cement dispensing and increased presence of weighting agents.
C09K 8/467 - Compositions de cimentation, p.ex. pour la cimentation des tubes dans les trous de forage; Compositions de bouchage, p.ex. pour tuer des puits contenant des liants inorganiques, p.ex. ciment Portland contenant des additifs pour des utilisations spécifiques
30.
METHOD FOR MEASURING THE SPATIAL WATER PERMEABILITY PROFILE OF POROUS MEDIA BY USING NON-DESTRUCTIVE NUCLEAR MAGNETIC RESONANCE TECHNIQUE
A method includes deriving spatial permeability along a core axis by saturating the rock with an aqueous solution, performing T2 NMR on the saturated rock to detect spatial NMR data along the core axis, desaturating the rock, performing T2 NMR on the desaturated rock to detect spatial NMR data along the core axis, determining the spatial cutoff data for the saturated and desaturated rock along the core axis, and analyzing the spatial NMR data. The method further includes deriving spatial permeability along a second core axis by additionally performing T2 NMR on the saturated rock to detect spatial NMR data along a second core axis, performing T2 NMR on the desaturated rock to detect spatial NMR data along a second core axis, and determining the spatial cutoff data for the saturated and desaturated rock along the second core axis.
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
G01V 3/32 - Prospection ou détection électrique ou magnétique; Mesure des caractéristiques du champ magnétique de la terre, p.ex. de la déclinaison ou de la déviation spécialement adaptée au carottage fonctionnant par résonance magnétique électronique ou nucléaire
G01R 33/50 - Systèmes d'imagerie RMN basés sur la détermination des temps de relaxation
31.
GEL FLUID COMPOSITES COMPRISING NANOSILICA AND QUANTUM DOTS FOR SEALING WATER PRODUCTION IN A WELLBORE
According to embodiments disclosed herein, a gel fluid composite may include a nanosilica gel and a plurality of quantum dot tracers. The nanosilica gel may be configured to seal one or more downhole fractures in a wellbore. The plurality of quantum dot tracers may be dispersed in the nanosilica gel. The plurality of quantum dot tracers may each include a semiconductor particle core housed in a silica shell.
C09K 8/504 - Compositions à base d'eau ou de solvants polaires
C09K 8/516 - Compositions pour le plâtrage des parois de trous de forage, c. à d. compositions pour la consolidation temporaire des parois des trous de forage caractérisées par leur forme ou par la forme de leurs composants, p.ex. matériaux encapsulés
C09K 11/56 - Substances luminescentes, p.ex. électroluminescentes, chimiluminescentes contenant des substances inorganiques luminescentes contenant du soufre
E21B 33/138 - Plâtrage de la paroi du trou de forage; Injections dans la formation
E21B 47/005 - Surveillance ou contrôle de la qualité ou du niveau de cimentation
32.
SYSTEMS, DEVICES, AND METHODS FOR NETWORK AND OBSOLESCENCE MANAGEMENT
Systems and methods are provided for network and obsolescence management. In one embodiment, a platform device is provided including a real-time system interface module (RSIM), a database module (DBM), a logic control module (LCM) and a reporting module (RM). The platform device collects data for network elements, systems, devices and network services, and examines the network elements and network service to generate a network obsolescence report. The platform device may output an obsolescence report including one or more obsolescence measurements. Processes are also provided for network and obsolescence management.
G06F 16/27 - Réplication, distribution ou synchronisation de données entre bases de données ou dans un système de bases de données distribuées; Architectures de systèmes de bases de données distribuées à cet effet
G06F 8/71 - Gestion de versions ; Gestion de configuration
Upstream process equipment transmits a predetermined fluid to downstream process equipment. A valve fluidly couples the upstream process equipment to the downstream process equipment. A first pressure sensor and a first temperature sensor are coupled to the upstream process equipment and upstream from the valve. A second pressure sensor and a second temperature sensor are coupled to the downstream process equipment and downstream from the valve. A control system is coupled to the first pressure sensor, the first temperature sensor, the second pressure sensor, and the second temperature sensor. The control system determines a first fluid flowrate of the predetermined fluid using a fluid flow model based on pressure data from the first pressure sensor and the second pressure sensor, temperature data from the first temperature sensor and the second temperature sensor, a size of the valve, at least one fluid parameter regarding the predetermined fluid, and a valve flow coefficient of the valve.
G01F 1/34 - Mesure du débit volumétrique ou du débit massique d'un fluide ou d'un matériau solide fluent, dans laquelle le fluide passe à travers un compteur par un écoulement continu en utilisant des effets mécaniques en mesurant la pression ou la différence de pression
G01F 1/684 - Dispositions de structure; Montage des éléments, p.ex. relativement à l'écoulement de fluide
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
G05D 7/06 - Commande de débits caractérisée par l'utilisation de moyens électriques
A sub-surface safety valve (SSSV) advisory system is disclosed. The SSSV advisory system includes a memory and a computer processor connected to the memory and that generates at least one control signal to perform an open and close sequence for testing a SSSV in a well environment, measures, during the open and close sequence of the SSSV, an open and close sequence signature of the SSSV, compares the measured open and close sequence signature to a normal open and close sequence signature of the SSSV to generate a comparison result, and generates, based on the comparison result, an integrity measure of the SSSV.
F16K 37/00 - Moyens particuliers portés par ou sur les soupapes ou autres dispositifs d'obturation pour repérer ou enregistrer leur fonctionnement ou pour permettre de donner l'alarme
E21B 41/00 - Matériel ou accessoires non couverts par les groupes
E21B 34/06 - Aménagements des vannes pour les trous de forage ou pour les puits dans les puits
A body defines a central flow passage. A check valve is located within the central flow passage. The check valve is supported by the body. The check valve is arranged such that a fluid flow travels in a downhole direction during operation of the float collar. An auxiliary flow passage is substantially parallel to the central flow passage and is defined by the body. The auxiliary flow passage includes an inlet upstream of the check valve and an outlet at a downhole end of the float collar. A rupture disk seals the inlet of the auxiliary flow passage. The rupture disk is configured to burst at a specified pressure differential.
E21B 34/06 - Aménagements des vannes pour les trous de forage ou pour les puits dans les puits
E21B 47/18 - Moyens pour la transmission de signaux de mesure ou signaux de commande du puits vers la surface, ou de la surface vers le puits, p.ex. pour la diagraphie pendant le forage utilisant des ondes acoustiques à travers le fluide du puits
E21B 34/10 - Aménagements des vannes pour les trous de forage ou pour les puits dans les puits actionnés par un fluide de commande provenant de l'extérieur du trou de forage
E21B 47/13 - Moyens pour la transmission de signaux de mesure ou signaux de commande du puits vers la surface, ou de la surface vers le puits, p.ex. pour la diagraphie pendant le forage par énergie électromagnétique, p.ex. gammes de fréquence radio
A system includes a subsurface safety valve and a lock tool. The subsurface safety valve is installed within the production tubing and has a main bore delineated by an inner circumferential surface of the subsurface safety valve and a lock profile machined into the inner circumferential surface of the subsurface safety valve. The lock tool is movably disposed around a conduit and has a locking dog configured to engage with the lock profile of the subsurface safety valve and a conduit seal made of a swellable elastomer. The conduit seal is activated by an activation fluid and has an expanded position and an unexpanded position.
E21B 34/06 - Aménagements des vannes pour les trous de forage ou pour les puits dans les puits
E21B 23/02 - Appareils pour déplacer, mettre en place, verrouiller, libérer ou retirer, les outils, les packers ou autres éléments dans les trous de forage pour verrouiller les outils ou autres éléments sur des supports ou dans des retraits entre sections adjacentes du tubage
E21B 33/10 - Etanchement ou bouchage des trous de forage ou des puits dans le trou de forage
37.
CLAY NANOPARTICLE PREPARATION FOR INDUSTRIAL APPLICATIONS
A method of enriching nano-bentonite from a raw bentonite composition comprises the steps of mixing the raw bentonite composition with water to produce a bentonite solution, increasing the temperature of the bentonite solution to produce a warm bentonite solution, mixing the warm bentonite solution at a mixing rate to produce a colloidal solution, filtering the colloidal solution with a micro-sieve to produce a filtered colloidal solution, centrifuging the filtered colloidal solution at a centrifuge rate for a centrifuge time to produce a separated colloidal solution, wherein the nano-sized impurities are selected from the group consisting of quartz, feldspar, cristbalite, calcite, iron oxides, magnetite, calcium carbonate, and combinations of the same, and drying the separated colloidal solution to remove water to produce the nano-bentonite.
C01B 39/02 - Zéolites aluminosilicates cristallines; Leurs composés isomorphes; Leur préparation directe; Leur préparation à partir d'un mélange réactionnel contenant une zéolite cristalline d'un autre type, ou à partir de réactants préformés; Leur post-traitement
B01J 29/06 - Zéolites aluminosilicates cristallines; Leurs composés isomorphes
A system includes a microfluidic device having a substrate, a reservoir defined in the substrate a microfluidic channel formed in the substrate, a microheater, and a detector. The reservoir is configured to store a fluid sample to be tested for the presence or absence of a compound. The microfluidic channel extends from the reservoir and includes a first portion fluidically connected to the reservoir, a second portion, and a detection portion fluidically connected between the first and second portions. The microheater is arranged adjacent to the reservoir and is configured to heat the fluid sample to a temperature at which the fluid sample releases a byproduct in response to being heated. The detector is arranged in the detector portion and is configured to indicate a presence or absence of the compound in the byproduct released from the heated sample.
B01L 3/00 - Récipients ou ustensiles pour laboratoires, p.ex. verrerie de laboratoire; Compte-gouttes
B01L 7/00 - Appareils de chauffage ou de refroidissement; Dispositifs d'isolation thermique
G01N 21/78 - Systèmes dans lesquels le matériau est soumis à une réaction chimique, le progrès ou le résultat de la réaction étant analysé en observant l'effet sur un réactif chimique produisant un changement de couleur
A method for mitigating water invasion to a submersible motor includes: forming an accumulation zone within an inner space of the submersible motor, wherein the accumulation zone is disposed at a bottom of the inner space below a motor shaft; measuring a conductivity of a fluid inside the accumulation zone using a sensor, wherein the fluid comprises water and dielectric oil; comparing the conductivity of the fluid with a threshold value; upon detecting that the conductivity of the fluid is greater than the threshold value, activating a solenoid pump to discharge the fluid from the accumulation zone to an outside of the submersible motor.
F04D 27/00 - Commande, p.ex. régulation, des pompes, des installations ou des systèmes de pompage spécialement adaptés aux fluides compressibles
G01M 3/16 - Examen de l'étanchéité des structures ou ouvrages vis-à-vis d'un fluide par utilisation d'un fluide ou en faisant le vide par détection de la présence du fluide à l'emplacement de la fuite en utilisant des moyens de détection électrique
G01F 23/22 - 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 en mesurant des variables physiques autres que les dimensions linéaires, la pression ou le poids, selon le niveau à mesurer, p.ex. par la différence de transfert de chaleur de vapeur ou d'eau
F04D 13/08 - Ensembles comprenant les pompes et leurs moyens d'entraînement la pompe étant entraînée par l'électricité pour utilisation en position immergée
40.
PIPERAZINE-BASED VISCOELASTIC SURFACTANTS FOR HYDRAULIC FRACTURING APPLICATIONS
KING FAHD UNIVERSITY OF PETROLEUM & MINERALS (Arabie saoudite)
Inventeur(s)
Kalgaonkar, Rajendra Arunkumar
Alali, Eyad
Bataweel, Mohammed Abudullah
Ullah, Nisar
Mansha, Muhammad
Abrégé
A wellbore fluid including a first surfactant, a second surfactant, an activator and an aqueous base fluid is provided. The first surfactant has a structure represented by Formula (I):
A wellbore fluid including a first surfactant, a second surfactant, an activator and an aqueous base fluid is provided. The first surfactant has a structure represented by Formula (I):
A wellbore fluid including a first surfactant, a second surfactant, an activator and an aqueous base fluid is provided. The first surfactant has a structure represented by Formula (I):
where Y1, Y2, Y3, Y4 are each, independently, a sulfonate, a carboxylate, an ester or a hydroxyl group, m is an integer ranging from 2 to 3, and n, o, and k are each, independently, integers ranging from 2 to 10. The second surfactant has a structure represented by Formula (III):
A wellbore fluid including a first surfactant, a second surfactant, an activator and an aqueous base fluid is provided. The first surfactant has a structure represented by Formula (I):
where Y1, Y2, Y3, Y4 are each, independently, a sulfonate, a carboxylate, an ester or a hydroxyl group, m is an integer ranging from 2 to 3, and n, o, and k are each, independently, integers ranging from 2 to 10. The second surfactant has a structure represented by Formula (III):
A wellbore fluid including a first surfactant, a second surfactant, an activator and an aqueous base fluid is provided. The first surfactant has a structure represented by Formula (I):
where Y1, Y2, Y3, Y4 are each, independently, a sulfonate, a carboxylate, an ester or a hydroxyl group, m is an integer ranging from 2 to 3, and n, o, and k are each, independently, integers ranging from 2 to 10. The second surfactant has a structure represented by Formula (III):
where R2 is a C15-C27 hydrocarbon group or a C15-C29 substituted hydrocarbon group, R3 is a C1-C10 hydrocarbon group, and p and q are each, independently, an integer ranging from 1 to 4. A method of using the wellbore fluid for treating a hydrocarbon-containing formation is also provided.
Systems and methods for cutting objects within a subterranean well include a laser system having a laser drilling head located at a terminal downhole end of a laser tool body directing a head laser beam in a direction downhole. A laser scanner assembly located within the laser tool body has a scanner head directing a scanner laser beam and can move both axially along a length of the laser tool body and rotate around a central axis of the laser tool body. A laser cutter assembly located within the laser tool body has a cutter head directing a cutter laser beam and can rotate around the central axis of the laser tool body. A cable bundle formed of a plurality of fiber optic cables extends from an uphole end of the laser tool body to each of the laser drilling head, the laser scanner assembly, and the laser cutter assembly.
E21B 29/02 - Découpage ou destruction de tubes, packers, bouchons ou câbles, situés dans les trous de forage ou dans les puits, p.ex. découpage de tubes endommagés, de fenêtres; Déformation des tubes dans les trous de forage; Remise en état des tubages de puits sans les retirer du sol au moyen d'explosifs ou par des moyens thermiques ou chimiques
B23K 26/38 - Enlèvement de matière par perçage ou découpage
B23K 26/08 - Dispositifs comportant un mouvement relatif entre le faisceau laser et la pièce
E21B 31/00 - Repêchage ou dégagement d'objets dans les trous de forage ou dans les puits
E21B 7/15 - Forage thermique, p.ex. forage à la flamme la chaleur étant produite par l'électricité
E21B 47/09 - Localisation ou détermination de la position d'objets dans les trous de forage ou dans les puits; Identification des parties libres ou bloquées des tubes
42.
METHOD FOR INCREASING THE QUALITY OF CRUDE OIL EXITING A GAS-OIL SEPARATION PLANT
A method for increasing the quality of crude oil exiting a gas-oil separation plant (GOSP) is disclosed. The GOSP hass sensors that determine process parameters of the crude oil, the method comprising determining, from the process parameters, WiO-parameters that depend on the concentration of water in the crude oil (WiO), determining virtual parameters of the crude oil, determining total parameters by adding the virtual parameters to the WiO-parameters, and performing a feedback loop. The feedback loop involves changing one or more of the total parameters, determining the quality of the crude oil exiting the GOSP, wherein when the quality is improved, the change in the one or more total parameters is maintained, when the quality is worsened, the change in the one or more total parameters is reversed, and repeating the feedback-loop as long as the quality of the crude oil exiting the GOSP increases.
A proxy apparatus for analyzing database queries in a secure network using a valid-query library that is constructed during an initial period following the deployment of an application. The proxy apparatus receives, in an operational mode, an operational database query from the secure network, generates an identifier for the received operational database query based at least upon a query code of the received operational database query; identifies a source and a destination of the received operation database query and compares the generated identifier, the identified source, and the identified destination to the valid-query library. When the comparing fails to match any entries in the valid-query library, the proxy apparatus terminates the operational database query; and when the comparing step matches an entry in the valid-query library, the proxy apparatus relays the received operational database query based on the destination identification.
G06F 21/54 - Contrôle des usagers, programmes ou dispositifs de préservation de l’intégrité des plates-formes, p.ex. des processeurs, des micrologiciels ou des systèmes d’exploitation au stade de l’exécution du programme, p.ex. intégrité de la pile, débordement de tampon ou prévention d'effacement involontaire de données par ajout de routines ou d’objets de sécurité aux programmes
G06F 21/62 - Protection de l’accès à des données via une plate-forme, p.ex. par clés ou règles de contrôle de l’accès
A system and method control login access of computer resource assets. The system comprises a computer resource asset and a gateway sub-system. The gateway sub-system has a processor to monitor N login failure conditions of a user, and to control access of the computer resource asset by the user depending on the user meeting the N login failure conditions. The method comprises storing predetermined login information associated with a user, receiving inputted login information from the user at a communication interface, evaluating the inputted login information by a processor configured by software therein, determining a matching or not matching of the predetermined login information, monitoring N login failure conditions of the user, in which N is greater than 1, and controlling access of a computer resource asset by the user depending on the user meeting the N login failure conditions. A method comprises steps performed during operation of the system.
KING FAHD UNIVERSITY OF PETROLEUM & MINERALS (Arabie saoudite)
Inventeur(s)
Kalgaonkar, Rajendra Arunkumar
Bataweel, Mohammed Abudullah
Alali, Eyad
Ullah, Nisar
Mansha, Muhammad
Abrégé
A wellbore fluid including a first surfactant, a second surfactant, an activator and an aqueous base fluid is provided. The first surfactant has a structure represented by Formula (I):
A wellbore fluid including a first surfactant, a second surfactant, an activator and an aqueous base fluid is provided. The first surfactant has a structure represented by Formula (I):
A wellbore fluid including a first surfactant, a second surfactant, an activator and an aqueous base fluid is provided. The first surfactant has a structure represented by Formula (I):
where Y1, Y2, Y3, Y4 are each, independently, a sulfonate, a carboxylate, an ester or a hydroxyl group, m is an integer ranging from 2 to 3, and n, o, and k are each, independently, integers ranging from 2 to 10. The second surfactant has a structure represented by Formula (III):
A wellbore fluid including a first surfactant, a second surfactant, an activator and an aqueous base fluid is provided. The first surfactant has a structure represented by Formula (I):
where Y1, Y2, Y3, Y4 are each, independently, a sulfonate, a carboxylate, an ester or a hydroxyl group, m is an integer ranging from 2 to 3, and n, o, and k are each, independently, integers ranging from 2 to 10. The second surfactant has a structure represented by Formula (III):
A wellbore fluid including a first surfactant, a second surfactant, an activator and an aqueous base fluid is provided. The first surfactant has a structure represented by Formula (I):
where Y1, Y2, Y3, Y4 are each, independently, a sulfonate, a carboxylate, an ester or a hydroxyl group, m is an integer ranging from 2 to 3, and n, o, and k are each, independently, integers ranging from 2 to 10. The second surfactant has a structure represented by Formula (III):
where R2 is a C15-C27 hydrocarbon group or a C15-C29 substituted hydrocarbon group, R3 is a C1-C10 hydrocarbon group, and p and q are each, independently, an integer ranging from 1 to 4. A method of using the wellbore fluid for treating a hydrocarbon-containing formation is also provided.
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 43/27 - Procédés pour activer la production par formation de crevasses ou de fractures par emploi de produits chimiques érosifs, p.ex. d'acides
E21B 43/16 - Procédés de récupération assistée pour l'extraction d'hydrocarbures
46.
SYSTEM AND METHOD FOR USE OF A STAGE CEMENTING DIFFERENTIAL VALVE TOOL
A stage cementing differential valve tool includes a body extending from a first end to a second end. The body may include one or more ports that may be configured to circulate a cement slurry, an external sleeve may be slidably coupled to an outer surface to the body, and an internal sleeve assembly may be slidably coupled to an inner surface to the body. The external sleeve and the internal sleeve assembly may be configured to open and close the one or more ports. The stage cementing differential valve tool may also include a sealing element extending from the outer surface of the body that is configured to swell in a downhole fluid environment and a plug having shoulders with break-off points that is configured to actuate the internal sleeve assembly.
E21B 33/14 - Procédés ou dispositifs de cimentation, de bouchage des trous, des fissures ou analogues pour la cimentation des tubes dans les trous de forage ou de sondage
E21B 34/14 - Aménagements des vannes pour les trous de forage ou pour les puits dans les puits actionnés par le mouvement des outils, p.ex. obturateurs à manchons actionnés par des pistons ou par des outils à câble
E21B 34/06 - Aménagements des vannes pour les trous de forage ou pour les puits dans les puits
47.
SYSTEMS AND METHODS FOR CONTROLLING USER ACCESS TO COMPUTER RESOURCES OF AN ORGANIZATION BY SEPARATED EMPLOYEES
In an example method, a system obtains a data record indicating an anticipated change in an employment status of a user at an organization, including a data field indicating an effective time of the anticipated change. At a first time prior to the effective time, the system modifies an access privilege of the user with respect to computer resources of the organization, including (i) allowing the user to perform first operations using the computer resources between the first time and a second time subsequent to the first time, and (ii) preventing the user from performing second operations using the computer resources starting at the first time. At the second time, the system further modifies the access privilege of the user, including preventing the user from performing the operations using the computer resources starting at the second time.
Processes for producing olefins include integration of steam cracking with a dual catalyst metathesis process. The processes include steam cracking a hydrocarbon feed to form a cracking reaction effluent containing butenes, separating the cracking reaction effluent to produce a cracking C4 effluent including normal butenes, isobutene, and 1,3-butadiene, subjecting the cracking C4 effluent to selective hydrogenation to convert 1,3-butadiene in the cracking C4 effluent to normal butenes, removing isobutene from a hydrogenation effluent to produce a metathesis feed containing normal butenes, and contacting the metathesis feed with a metathesis catalyst and a cracking catalyst directly downstream of the metathesis catalyst to produce a metathesis reaction effluent. Contacting with the metathesis catalyst causes metathesis of normal butenes to produce ethylene, propene, and C5+ olefins, and contacting with the cracking catalyst causes C5+ olefins produced through metathesis to undergo cracking reactions to produce additional propene, ethylene, or both.
C10G 69/06 - Traitement des huiles d'hydrocarbures par au moins un procédé d'hydrotraitement et au moins un autre procédé de conversion uniquement par plusieurs étapes en série comprenant au moins une étape de craquage thermique en l'absence d'hydrogène
C07C 1/22 - Préparation d'hydrocarbures à partir d'un ou plusieurs composés, aucun d'eux n'étant un hydrocarbure à partir de composés organiques ne renfermant que des atomes d'oxygène en tant qu'hétéro-atomes par réduction
C07C 6/04 - Réactions de métathèse sur une liaison carbone-carbone non saturée sur une double liaison carbone-carbone
C07C 41/06 - Préparation d'éthers par addition de composés à des composés non saturés uniquement par addition de composés organiques
C10G 51/02 - Traitement des huiles d'hydrocarbures, en l'absence d'hydrogène, uniquement par plusieurs procédés de craquage uniquement par plusieurs étapes en série
C10G 51/06 - Traitement des huiles d'hydrocarbures, en l'absence d'hydrogène, uniquement par plusieurs procédés de craquage uniquement par plusieurs étapes en parallèle
C10G 65/10 - Traitement des huiles d'hydrocarbures, uniquement par plusieurs procédés d'hydrotraitement uniquement par plusieurs étapes en série ne comprenant que des étapes de craquage
C10G 65/12 - Traitement des huiles d'hydrocarbures, uniquement par plusieurs procédés d'hydrotraitement uniquement par plusieurs étapes en série comprenant des étapes de craquage et d'autres étapes d'hydrotraitement
B01J 19/18 - Réacteurs fixes avec éléments internes mobiles
49.
SYSTEM AND METHOD FOR HISTORY MATCHING RESERVOIR SIMULATION MODELS
King Abdullah University of Science and Technology (Arabie saoudite)
Inventeur(s)
Alsinan, Marwah Mufid
He, Xupeng
Kwak, Hyung Tae
Hoteit, Hussein
Abrégé
A method for history matching utilizing Bayesian Markov Chain Monte Carlo (MCMC) workflow may include selecting a reservoir simulation model of interest, identifying a mathematical model relevant to the reservoir simulation model, and identifying a plurality of history matching parameters as initial priors. The method may include constructing a first model, utilizing the initial priors, to obtain updated priors. The method may include constructing a second model to obtain posteriors. The method may include determining history matching accuracy of the reservoir simulation model by comparing medians of the posteriors and a plurality of measured data. The method may further include, upon determining accuracy of the reservoir simulation model, performing a plurality of predictions of a reservoir.
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
Compositions inhibit corrosion in various commercial settings, such as in a refinery and/or in an oil and gas application. The compositions include at least one fatty acid and at least two amphipathic molecules selected from the group consisting of dodecenyl succinic acid, dimer fatty acid and benzalkonium chloride.
A fracturing fluid composition includes an aqueous fluid, a proppant particle, and a date tree fiber. A method of treating a hydrocarbon-bearing formation is also provided. The method includes injecting a fracturing fluid in the hydrocarbon-bearing formation, where the fracturing fluid includes an aqueous fluid, a proppant particle, and a date tree fiber.
A method of making a composition of matter is provided. The method includes pH-modifying, that is, deacidifying, neutralizing or basifying, one or more water-soluble oxidized disulfide oil (WS-ODSO) compounds or mixture of compounds. The WS-ODSO is combined with an effective amount of an alkaline agent. The process results in a pH-modified, that is, deacidified, neutralized or basified, WS-ODSO composition, for example which can be used as a component in synthesis of materials such as zeolitic material.
C10G 17/02 - Raffinage des huiles d'hydrocarbures, en l'absence d'hydrogène, avec des acides, des composés libérant un acide ou des liquides contenant un acide, p.ex. avec une boue acide avec des acides ou des liquides contenant un acide, p.ex. avec une boue acide
C10G 53/14 - Traitement des huiles d'hydrocarbures, en l'absence d'hydrogène, par plusieurs procédés de raffinage uniquement par plusieurs étapes en série comprenant au moins une étape d'oxydation
54.
Polyaromatic hydrocarbon-based host-guest complex for heavy crude oil viscosity reduction
This disclosure relates to water-soluble viscosity reducer complexes for use in reducing the viscosity of heavy oil in oil recovery operations. The viscosity reducer complexes contain a hydrophilic component of polyaromatic-hydrocarbon-based polymers and a hydrophilic component of cyclodextrin-based polymers.
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
C08G 65/331 - Polymères modifiés par post-traitement chimique avec des composés organiques contenant de l'oxygène
C08L 33/26 - Homopolymères ou copolymères de l'acrylamide ou de la méthacrylamide
In accordance with one or more embodiments of the present disclosure, a method for producing aromatic compounds from pyrolysis gasoline includes hydrotreating a stream comprising the pyrolysis gasoline, thereby producing a hydrotreated pyrolysis gasoline stream comprising paraffins; aromatizing the hydrotreated pyrolysis gasoline stream comprising paraffins, thereby producing a stream comprising benzene-toluene-xylenes (BTX); and processing the stream comprising BTX in an aromatics recovery complex, thereby producing the aromatic compounds from the pyrolysis gasoline.
C10G 69/02 - Traitement des huiles d'hydrocarbures par au moins un procédé d'hydrotraitement et au moins un autre procédé de conversion uniquement par plusieurs étapes en série
C10G 67/02 - Traitement des huiles d'hydrocarbures, uniquement par au moins un procédé d'hydrotraitement et au moins un procédé de raffinage en l'absence d'hydrogène uniquement par plusieurs étapes en série
C10G 69/12 - Traitement des huiles d'hydrocarbures par au moins un procédé d'hydrotraitement et au moins un autre procédé de conversion uniquement par plusieurs étapes en série comprenant au moins une étape de polymérisation ou d'alkylation
Compositions and methods for determining the origin location of a subterranean sample are provided. Compositions include a nanoparticle tag including a superparamagnetic iron oxide core, an intermediate layer including a fluorescent dye, and a polymer shell. The nanoparticles can be synthesized by functionalizing a superparamagnetic iron oxide nanoparticle core and covalently bonding a fluorescent dye to the functionalized nanoparticle core. In some implementations, a polymer is covalently bonded to the functionalized, fluorescent superparamagnetic iron oxide nanoparticle core. The nanoparticle tag can be used to determine the origin location of a subterranean sample by mixing the nanoparticle tag into a fluid, flowing the fluid into a subterranean formation, recovering subterranean samples from the subterranean formation, and separating tagged samples from untagged samples using a magnet. The origin location of the subterranean sample can be determined by analyzing the fluorescent signal of the nanoparticle tag.
Compositions and methods for determining the origin location of a subterranean sample are provided. Compositions include a polymer-clay composite tag. The tag includes a nanoclay including a plurality of layers, and a polymer intercalated between the layers of the nanoclay. The polymer is functionalized with a fluorescent dye. A method to determine the origin location of a subterranean sample includes mixing a barcoded polymer-clay composite tag into a fluid, flowing the fluid through a work string into a subterranean formation, recovering subterranean samples from the subterranean formation, and determining the origin location of the subterranean sample by detecting the presence of the barcoded polymer-clay composite tag.
C01B 33/44 - Produits obtenus à partir de silicates échangeurs de base, en couches, par échange d'ions avec des composés organiques tels que des composés ammonium, phosphonium ou sulfonium ou par insertion de composés organiques, p.ex. matériaux organoargiles
C08F 8/34 - Introduction d'atomes de soufre ou de groupes contenant du soufre
C08F 26/02 - Homopolymères ou copolymères de composés contenant un ou plusieurs radicaux aliphatiques non saturés, chaque radical ne contenant qu'une seule liaison double carbone-carbone et l'un au moins étant terminé par une liaison simple ou double à l'azote ou par une simple ou une double liaison à l'azote
A method may include obtaining, from a camera device, thermal image data for a steam area of a plant facility. The steam area may include a steam trap for a steam network. The method may further include obtaining plant steam data regarding the steam trap. The method may further include determining pixel data regarding the steam trap using the thermal image data and an image segmentation process. The method further includes determining various temperature values across the steam trap using the pixel data. The method may further include determining predicted steam trap data using the temperature values, the plant steam data, and a machine-learning model. The method may further include transmitting a command that adjusts one or more parameters of the steam network based on the predicted steam trap data.
G05B 13/02 - Systèmes de commande adaptatifs, c. à d. systèmes se réglant eux-mêmes automatiquement pour obtenir un rendement optimal suivant un critère prédéterminé électriques
Systems and methods include a computer-implemented method for using first- and second-order derivatives from discrete pressure data of a well to characterize the well and intersected reservoir under dynamic conditions. Discrete data for the well and associated reservoir is arranged chronologically. First- and second-order derivatives of pressure versus a time series are determined at a first focal point using a five-point function considering beginning and ending points in a time period. First- and second-order derivatives are determined at successive focal points, applying terminal corrections. Numerical values and plots of first- and second-order derivative profiles are presented. Diagnostic plots and data for determining geological features for the associated reservoir and well parameters are generated. Reservoir simulation models are executed to generate a forecast of future production rates under different constraints. A production strategy and future development plans for the well are managed, and future sales revenue estimates are provided.
An apparatus includes a funnel, a core, a first coating, a second coating, and a third coating. The funnel includes multiple inlet ports and an outlet port. The core is disposed within the funnel. The first coating is disposed on and surrounds an outer surface of the core. The first coating is configured to dissolve in response to being exposed to water. The second coating is disposed on and surrounds an outer surface of the first coating. The second coating is configured to dissolve in response to being exposed to water. The third coating is disposed on and surrounds an outer surface of the second coating. The third coating is configured to dissolve in response to being exposed to a hydrocarbon.
Techniques include flowing a multiphase fluid from a hydrocarbon production well through a conduit; measuring, with an ultrasonic tomographic multiphase flow meter (UMM), ultrasonic waveforms generated by the UMM from the multiphase fluid; measuring properties of the multiphase fluid with fluid measurement sensors coupled to the conduit; identifying the ultrasonic waveforms and the properties with a machine-learning control system; determining multiphase fractions of the multiphase fluid from the one or more ultrasonic waveforms with a first ML model; determining a total flow rate of the multiphase fluid from the measured properties of the multiphase fluid with a second ML model; and determining a volumetric flow rate of a liquid phase or a gas phase based on the determined multiphase fraction and the determined total flow rate.
A system and method including a sulfur recovery system (SRU) having a Claus system, reacting hydrogen sulfide and oxygen in a furnace to give sulfur dioxide, performing a Claus reaction in the furnace to give elemental sulfur, performing the Claus reaction in a Claus reactor to give elemental sulfur at a temperature greater than a dew point of the elemental sulfur, performing the Claus reaction in a Claus cycling reactor to give elemental sulfur at a temperature less than a solidification temperature of the elemental sulfur, depositing the elemental sulfur as solid elemental sulfur on catalyst in the Claus cycling reactor, and regenerating (heating) the Claus cycling reactor thereby forming elemental sulfur vapor from the solid elemental sulfur.
A downhole tool (1) includes a bore isolation valve (4), a sensor (15) configured to receive a downlink signal, an annular pressure sensor (7), a valve actuation mechanism (12) coupled to the bore isolation valve (4) and responsive to the downlink signal, a pressure relief mechanism (9) configured to provide a negative pressure pulse signal indicative of the annular pressure by venting fluid from a bore (5) of the tool body, and a battery (17). A method includes drilling a well with a drill bit coupled to an on demand annular pressure tool (1) initially in a deactivated mode, and activating the tool (1) by a downlink signal when fluid flow out of the annulus drops below the fluid flow into the well to close a bore (5) of the tool (1), pressurizing the drill string, holding pressure in the drill string, measuring annular pressure with the tool (1), and sending a negative pressure pulse signal indicative of the annular pressure.
An electrostatic coalescer apparatus for separating water from a crude oil emulsion comprises a vessel housing having a cavity, an inlet for receiving a crude oil emulsion and outlets for water and purified crude oil. First and second pairs of electrodes are positioned in the vessel cavity. A first Scott- T transformer circuit is coupled to the first pair of electrodes and a second Scott-T transformer circuit is coupled to the second pair of electrodes. The first and second Scott- T transformer circuit receive as an input a 3 -phase power supply and output a 2 -phase high voltage signal pairs of electrodes. The 2-phase voltage generated between the first pair of electrodes is of the same amplitude and phase as the voltage generated between the second pair of electrodes via the respective Scott-T transformer circuits. A method comprises steps performed during operation of the apparatus.
Systems and methods for evaluating a subsurface region of the earth for hydrocarbon exploration, development, or production are disclosed. Embodiments of the present disclosure are configured to determine advanced radioactive formation data from commonly acquired well logging data sets. In particular, a predictive model is trained to generate “synthetic” spectral gamma ray logs are from basic neutron, density and total gamma ray logs measured from a well within the formation. The predictive model comprises a neural network that is trained using multi-resolution graph clustering techniques to correlate patterns in the density, neutron and gamma ray log data to patterns in spectral gamma ray log data. Embodiments of the present disclosure are further configured to use the synthetic spectral gamma ray logs output by the model to quantify the clay content of the formation, its permeability and determine a hydrocarbon productivity index for the formation.
G01V 5/06 - Prospection ou détection au moyen de radiations nucléaires, p.ex. de la radioactivité naturelle ou provoquée spécialement adaptée au carottage pour détecter des minerais à radioactivité naturelle
E21B 49/00 - Test pour déterminer la nature des parois des trous de forage; Essais de couches; Procédés ou appareils pour prélever des échantillons du terrain ou de fluides en provenance des puits, spécialement adaptés au forage du sol ou aux puits
66.
PARAMETER-REDUCED CALIBRATION WORKFLOW FOR SUBSIDENCE MAP INPUT IN STRATIGRAPHIC MODELS
Methods and systems for calibrating a subsidence map are disclosed. The method includes selecting a stratigraphic model that represents a geological formation and defining the subsidence map with a first set of variable values. The method further includes obtaining target outputs measured from the geological formation. The method still further includes determining first model outputs from the stratigraphic model by inputting the subsidence map with the first set of variable values into the stratigraphic model and determining a first residual between the target outputs and the first model outputs using an objective function.
A computer receives a measured wetness of and a measured δ2H value associated with a test gas sample from a hydrocarbon formation. The measured wetness is a molar ratio of heavy gas compounds over a total gas within the measured sample. The computer receives calculated wetnesses calculated δ2H values associated with a gas samples taken from one or more analogous hydrocarbon reservoirs. The measured wetness received for the test gas sample is identified from among the plurality of calculated wetnesses. The computer determines a corresponding δ2H value from among the calculated δ2H values that corresponds to the measured wetness of the test gas sample. The computer determines a predicted sample VRo (vitrinite reflectance equivalent) for the test gas sample based on the corresponding δ2H value and a correlation of δ2H values to VRo values. Hydrocarbons are produced from the hydrocarbon formation based on the predicted sample VRo.
Compositions and methods for determining the origin location of a subterranean rock sample. Compositions include a nanoparticle tag with a fluorescent core and a polymer shell. The fluorescent core can include up-converting nanoparticles, rare earth element doped oxide, long persistent fluorescent materials, or encapsulated lanthanide complexes. Methods include mixing a nanoparticle tag into a fluid, flowing the fluid through a work string into a subterranean formation, recovering subterranean rock samples from the subterranean formation, and determining an origin location of the subterranean rock sample by detecting the presence of the nanoparticle tag on the sample.
C09K 11/02 - Emploi de substances particulières comme liants, revêtements de particules ou milieux de suspension
C09K 11/77 - Substances luminescentes, p.ex. électroluminescentes, chimiluminescentes contenant des substances inorganiques luminescentes contenant des métaux des terres rares
C09K 11/68 - Substances luminescentes, p.ex. électroluminescentes, chimiluminescentes contenant des substances inorganiques luminescentes contenant des métaux réfractaires contenant du chrome, du molybdène ou du tungstène
C09K 8/16 - Compositions contenant de l'argile caractérisées par les composés inorganiques autres que l'argile
E21B 49/02 - Test pour déterminer la nature des parois des trous de forage; Essais de couches; Procédés ou appareils pour prélever des échantillons du terrain ou de fluides en provenance des puits, spécialement adaptés au forage du sol ou aux puits par prélèvements mécaniques d'échantillons du terrain
E21B 49/00 - Test pour déterminer la nature des parois des trous de forage; Essais de couches; Procédés ou appareils pour prélever des échantillons du terrain ou de fluides en provenance des puits, spécialement adaptés au forage du sol ou aux puits
Compositions and methods for determining the origin location of subterranean rock samples. In some implementations, the compositions include a nanoparticle tag that includes a natural polysaccharide, a fluorescent dye, and superparamagnetic nanoparticles. In some implementations, a method of determining the origin location of a subterranean rock sample includes mixing the nanoparticle tag into a fluid, flowing the fluid into a subterranean formation, recovering subterranean rock samples from the formation, separating tagged rock samples from untagged rock samples using a magnet, and determining the origin location by analyzing a fluorescent signal of the nanoparticle tag.
In wellbore abandonment operations using recycled tire rubber, a quantity of shredded rubber obtained by shredding waste tires is mixed with a quantity of a wellbore fluid to form a wellbore abandonment fluid. A first plug of cement is flowed into a wellbore to be abandoned. After the first plug of cement has set, the wellbore abandonment fluid is flowed into the wellbore such that the wellbore abandonment fluid contacts and is uphole of the first plug of cement within the wellbore. After flowing the wellbore abandonment fluid into the wellbore, a second plug of cement is flowed into the wellbore such that the second plug of cement contacts and is uphole of the wellbore abandonment fluid.
C09K 8/42 - Compositions de cimentation, p.ex. pour la cimentation des tubes dans les trous de forage; Compositions de bouchage, p.ex. pour tuer des puits
A method of forming a barrier to overcome lost circulation in a subterranean formation. The method includes injecting a polymer-sand nanocomposite into one or more lost circulation zones in the subterranean formation where the polymer-sand nanocomposite is formed from sand mixed with a polymer hydrogel. Further, the polymer hydrogel includes a hydrogel polymer, an organic cross-linker, and a salt. The sand additionally comprises a surface modification. The associated method of preparing a polymer-sand nanocomposite lost circulation material for utilisation in forming the barrier is provided.
C09K 8/512 - Composés macromoléculaires contenant des agents de réticulation
C09K 8/516 - Compositions pour le plâtrage des parois de trous de forage, c. à d. compositions pour la consolidation temporaire des parois des trous de forage caractérisées par leur forme ou par la forme de leurs composants, p.ex. matériaux encapsulés
72.
TWO STAGE CATALYTIC PROCESS FOR PYROLYSIS OIL UPGRADING TO BTEX
In accordance with one or more embodiments of the present disclosure, a multi-stage process for upgrading pyrolysis oil comprising polyaromatic compounds to benzene, toluene, ethylbenzene, and xylenes (BTEX) includes upgrading the pyrolysis oil in a slurry-phase reactor zone to produce intermediate products, wherein the slurry-phase reactor zone comprises a mixed metal oxide catalyst; and hydrocracking the intermediate products in a fixed-bed reactor zone to produce the BTEX, wherein the fixed-bed reactor zone comprises a mesoporous zeolite-supported metal catalyst.
C10G 65/10 - Traitement des huiles d'hydrocarbures, uniquement par plusieurs procédés d'hydrotraitement uniquement par plusieurs étapes en série ne comprenant que des étapes de craquage
C10G 69/04 - Traitement des huiles d'hydrocarbures par au moins un procédé d'hydrotraitement et au moins un autre procédé de conversion uniquement par plusieurs étapes en série comprenant au moins une étape de craquage catalytique en l'absence d'hydrogène
C10G 69/06 - Traitement des huiles d'hydrocarbures par au moins un procédé d'hydrotraitement et au moins un autre procédé de conversion uniquement par plusieurs étapes en série comprenant au moins une étape de craquage thermique en l'absence d'hydrogène
An apparatus includes a funnel, a core, a first coating, a second coating, and a third coating. The funnel includes multiple inlet ports and an outlet port. The core is disposed within the funnel. The first coating is disposed on and surrounds an outer surface of the core. The first coating is configured to dissolve in response to being exposed to water. The second coating is disposed on and surrounds an outer surface of the first coating. The second coating is configured to dissolve in response to being exposed to water. The third coating is disposed on and surrounds an outer surface of the second coating. The third coating is configured to dissolve in response to being exposed to a hydrocarbon.
E21B 43/12 - Procédés ou appareils pour commander l'écoulement du fluide extrait vers ou dans les puits
E21B 34/08 - Aménagements des vannes pour les trous de forage ou pour les puits dans les puits sensibles à l'écoulement ou à la pression du fluide obtenu
74.
Slow settling micro-proppants for far field stimulation
A method of stimulating petroleum production includes introducing a fracturing fluid into a petroleum formation, thereby creating at least one fracture to stimulate the petroleum production. The fracturing fluid is introduced into the petroleum formation at a pressure above the breakdown pressure of the formation. The fracturing fluid includes a plurality of proppants each including a proppant particle and a coating. The coating includes a hydrophobic coating, a cross-linked hydrogel, or both. From 1 to 50 wt. % of the plurality of proppants includes micro proppants having a particle size ranging from 0.5 to 150 μm, and from 50 to 99 wt. % of the plurality of proppants includes macro proppants having a particle size of 100 mesh or greater.
A downhole device that drills a wellbore includes a stabilizer which has a body and blades. The blades are disposed on a surface of the body and each blade has a hollow space. The blades each include a dissolvable window that is disposed on a surface of each of the blades and a light source that emits light to the wellbore. The dissolvable window blocks light emitted from the light source thereby reducing or eliminating light from being transmitted to the wellbore. The dissolvable window dissolves upon exposure to a fluid containing a dissolving medium, thereby allowing the light source to transmit light to the wellbore. Methods of using the downhole device to activate downhole chemicals are also provided.
A system and method detect an evolving sinkhole due to displacement and pose changes of a plurality of nodes distributed geographically. The system comprises a base station, a plurality of nodes, and a user device. The plurality of nodes are distributed geographically, with each node secured into the ground on the Earth's surface. A sensor senses a state of the nodes relative to the ground, including a displacement and pose changes of the nodes relative to the ground. The sensed states of the nodes used to generate a geophysical map of the ground, including the displacement and the pose change of at least one node due to an evolution of a sinkhole. An output device is configured to display the geophysical map and the sinkhole to a user.
E21B 47/12 - Moyens pour la transmission de signaux de mesure ou signaux de commande du puits vers la surface, ou de la surface vers le puits, p.ex. pour la diagraphie pendant le forage
G01V 9/00 - Prospection ou détection par des procédés non prévus dans les groupes
E21B 44/00 - Systèmes de commande automatique spécialement adaptés aux opérations de forage, c. à d. systèmes à fonctionnement autonome ayant pour rôle d'exécuter ou de modifier une opération de forage sans l'intervention d'un opérateur humain, p.ex. systèmes de ; Systèmes spécialement adaptés à la surveillance de plusieurs variables ou conditions de forage
E21B 49/00 - Test pour déterminer la nature des parois des trous de forage; Essais de couches; Procédés ou appareils pour prélever des échantillons du terrain ou de fluides en provenance des puits, spécialement adaptés au forage du sol ou aux puits
E21B 47/113 - Localisation des fuites, intrusions ou mouvements du fluide utilisant un rayonnement lumineux
77.
SYSTEM AND METHOD FOR MAPPING A BOREHOLE USING LIDAR
A system and method map a borehole using LIDAR. The system comprises a tool and a mapping sub-system. The tool includes an intermediate LIDAR sub-system and a distal LIDAR sub-system. The intermediate LIDAR sub-system has an intermediate emitter and an intermediate receiver. The intermediate emitter emits light and the intermediate receiver receives reflected light from the intermediate object. The distal LIDAR sub-system has a distal emitter and a distal receiver. The distal emitter emits light, and the distal receiver receives reflected light from the distal object. The mapping sub-system determines a position of the tool, determines an inner surface of the borehole, and generates and outputs a map of the borehole from the position and the inner surface. A method comprises steps performed during operation of the system.
E21B 47/085 - Mesure du diamètre ou des dimensions correspondantes des trous de forage utilisant des moyens de radiation, p.ex. des moyens acoustiques, radioactifs ou électromagnétiques
G01S 17/89 - Systèmes lidar, spécialement adaptés pour des applications spécifiques pour la cartographie ou l'imagerie
E21B 47/002 - Relevés dans les trous de forage ou dans les puits par inspection visuelle
E21B 47/09 - Localisation ou détermination de la position d'objets dans les trous de forage ou dans les puits; Identification des parties libres ou bloquées des tubes
78.
DETERMINING MATURITY OF PALEOZOIC UNCONVENTIONAL SHALE GAS
A method of fabricating and utilizing an unconventional reservoir maturity chart is provided. A historical dataset for a Paleozoic or a pre-Paleozoic shale or sandstone unconventional reservoir is utilized to obtain carbon isotopic ratio values for δ13C1, δ13C2, and vitrinite reflectance equivalents (VRE). Such data is utilized to plot several maturity shapes based upon VRE values, where several of the maturity shapes have a maturity shape boundary defined by the relationship δ13C1=δ13C2. The method for utilizing the unconventional reservoir maturity chart may include determining a maturity level for the hydrocarbon gas sample based upon a relative position of the plotted data point versus a first maturity shape, a second maturity shape, a third maturity shape, and a fourth maturity shape. The method may also permit determining a production plan for the unconventional reservoir associated with the hydrocarbon gas sample.
A side-outlet adaptor assembly for repairing a side-outlet of a wellhead spool is disclosed. The side-outlet adaptor assembly includes an isolation sleeve having a first portion adapted to be received by the side-outlet and a second portion adapted to be received by an adaptor, the adaptor having a wellhead-side opening adapted to receive the isolation sleeve and a gate-valve-side (GV-side) opening adapted to receive a valve replacement (VR) plug, and a test port arranged on the adaptor for performing a pressure test of the side-outlet.
E21B 34/02 - Aménagements des vannes pour les trous de forage ou pour les puits dans les têtes de puits
E21B 33/068 - Têtes de puits; Leur mise en place comportant des dispositions pour introduire des objets dans les puits ou pour les en retirer, ou pour y introduire des fluides
E21B 19/22 - Manipulation de tubes ou de tiges enroulés, p.ex. de tubes de forage flexibles
80.
BI-PHASE (SCOTT-T) TRANSFORMER DOUBLE VOLTED AC ELECTROSTATIC COALESCER
An electrostatic coalescer apparatus for separating water from a crude oil emulsion comprises a vessel housing having a cavity, an inlet for receiving a crude oil emulsion and outlets for water and purified crude oil. First and second pairs of electrodes are positioned in the vessel cavity. A first Scott-T transformer circuit is coupled to the first pair of electrodes and a second Scott-T transformer circuit is coupled to the second pair of electrodes. The first and second Scott-T transformer circuit receive as an input a 3-phase power supply and output a 2-phase high voltage signal pairs of electrodes. The 2-phase voltage generated between the first pair of electrodes is of the same amplitude and phase as the voltage generated between the second pair of electrodes via the respective Scott-T transformer circuits. A method comprises steps performed during operation of the apparatus.
A computer-implemented method for managing, in a production environment of an enterprise, a change to a segregation of duties access risk function. At least one computing device accesses information representing a proposed change to an access risk function, and processes the information to determine a related access risk function. The computing device(s) access information associated with the related access risk function and, using the information associated with the proposed change and the information associated with the related access risk function, evaluate respective details in the proposed change. The computing device(s) generate and transmit a message that includes information representing details of the proposed change.
G06Q 10/06 - Ressources, gestion de tâches, des ressources humaines ou de projets; Planification d’entreprise ou d’organisation; Modélisation d’entreprise ou d’organisation
Embodiments for determining a stuck pipe location include determining that a pipe is stuck in a wellbore due to an obstruction; deploying a fiber optic stuck pipe location detector inside the pipe, activating a first fiber optic sensor to detect a baseline reading, and manipulating the pipe. Some embodiments include detecting micro-noises caused by the stretching of the pipe, wirelessly acquiring data related to the micro-noises from the first fiber optic sensor, and determining a location of the obstruction by comparing the baseline reading with the data related to the micro-noises. Some embodiments include recovering the pipe at a predetermined point around the location of the obstruction while leaving the first fiber optic sensor inside the pipe.
E21B 47/09 - Localisation ou détermination de la position d'objets dans les trous de forage ou dans les puits; Identification des parties libres ou bloquées des tubes
E21B 47/008 - Surveillance des systèmes de pompe de fond de trou, p.ex. pour la détection de conditions appelées "cognement sur le fluide"
E21B 47/002 - Relevés dans les trous de forage ou dans les puits par inspection visuelle
83.
Cathodic Current Measurement of Outer Casings or Tubulars using Electro-Magnetic Radiation
A method for determining a cathodic current (such as from a cathodic protection system) in a tubular disposed within a wellbore drilled in a subterranean zone. A electromagnetic tool disposed within the tubular includes an electromagnetic transmitter, an electromagnetic receiver, a helical transmitter coil, and a helical receiver coil. An axis of the helical transmitter coil and an axis of the helical receiver coil are substantially parallel to an axis of the tubular. An electromagnetic field is transmitted by flowing a first electrical current to the helical transmitter coil. During the transmitting, an electromagnetic signal is received by the electromagnetic receiver via the helical receiver coil. A second electrical current is calculated based on the electromagnetic signal received by the electromagnetic receiver. A magnitude of the cathodic current flowing through the tubular is calculated based on a difference between the first electrical current and the second electrical current.
G01N 17/02 - Systèmes de mesure électro-chimique de l'action due aux intempéries, de la corrosion ou de la protection contre la corrosion
G01V 3/28 - Prospection ou détection électrique ou magnétique; Mesure des caractéristiques du champ magnétique de la terre, p.ex. de la déclinaison ou de la déviation spécialement adaptée au carottage fonctionnant au moyen de champs magnétiques ou électriques produits ou modifiés par la formation terrestre environnante ou par les dispositifs de détection en utilisant des bobines d'induction
E21B 47/00 - Relevés dans les trous de forage ou dans les puits
E21B 41/02 - Lutte contre la corrosion sur place dans les trous de forage ou dans les puits
84.
GASKETED SPECTACLE PLATE ASSEMBLY FOR INDUSTRIAL PIPE SYSTEMS
A spectacle plate assembly and method for its production includes adhesively bonding a ring-shaped flexible sealing gasket to cover all, or substantially all of a contoured gasket receiving surface that is formed on both sides of the circular plate, the upper surfaces of the contoured gasket receiving surface lying above the plane of the surface of the adjacent plate to provide a unitary structure in preparation for positioning the plate between the opposing faces of a pair of stationary flanges.
F16K 3/06 - Robinets-vannes ou tiroirs, c. à d. dispositifs obturateurs dont l'élément de fermeture glisse le long d'un siège pour l'ouverture ou la fermeture à faces d'obturation planes; Garnitures d'étanchéité à cet effet avec éléments de fermeture articulés à pivot en forme de plaques disposées entre l'alimentation et l'évacuation
F16K 3/02 - Robinets-vannes ou tiroirs, c. à d. dispositifs obturateurs dont l'élément de fermeture glisse le long d'un siège pour l'ouverture ou la fermeture à faces d'obturation planes; Garnitures d'étanchéité à cet effet
F16K 3/314 - Formes ou structures de la partie coulissante; Sa fixation sur sa tige
85.
METHOD AND SYSTEM FOR DETERMINING SEISMIC PROCESSING PARAMETERS USING MACHINE LEARNING
A method may include obtaining an input gather regarding a geological region of interest. The method may further include obtaining parameterization data regarding a seismic processing operation. The parameterization data may correspond to a first set of process parameter values that are different from a second set of process parameter values that are used to generate the input gather. The method may further include generating a predicted output gather using a machine-learning model, the input gather, and the parameterization data. The machine-learning model may include an encoder model and a decoder model. The method may further include generating a seismic image of the geological region of interest using the predicted output gather.
Systems and methods include a system for deploying and using a customized logging-while-drilling (LWD) tool. A command is provided by a tool control system to a mechanical drive of a LWD tool to cause pads and caliper fingers of the LWD tool to extend radially, lock in place using a locking mechanism, and begin to capture downhole measurements while the LWD tool is deployed in a borehole of a well. Pressure pulse cycles produced by a series of distinct high and low flow rates by the tool control system are provided to create pulses to be detected downhole by pressure transducers. A measurement sequence for caliper and resistivity images is triggered by the tool control system. The measurement sequence is terminated by the tool control system to conserve energy.
E21B 47/00 - Relevés dans les trous de forage ou dans les puits
E21B 47/002 - Relevés dans les trous de forage ou dans les puits par inspection visuelle
E21B 47/08 - Mesure du diamètre ou des dimensions correspondantes des trous de forage
E21B 47/12 - Moyens pour la transmission de signaux de mesure ou signaux de commande du puits vers la surface, ou de la surface vers le puits, p.ex. pour la diagraphie pendant le forage
87.
CHEMICAL HYDROSTATIC BACKPRESSURE REDUCTION METHODOLOGY TO FLOW FLUIDS THROUGH DISPOSAL WELLS
To control hydrostatic backpressure of disposal wells (102a-f) connected to a disposal plant (108) surface network, density of water to be injected from a water disposal plant system into disposal wells formed in a subterranean zone (100), a density of a hydrostatic backpressure-modifying additive to modify a density of the water, a target total injection flow rate of the water, and a vertical depth of a portion of the subterranean zone through which the water is to be injected are identified. Injected water flow rate upstream of an injection point into the multiple disposal wells, wellhead injection pressure needed to achieve the target total injection flow rate and a total injection rate are periodically received. Based on these parameters, dosage rate of the additive to maintain the target total injection flow rate is periodically determined. An additive quantity is injected into the water and periodically modified based on the periodically determined dosage rate.
Systems and methods include a computer-implemented method for monitoring emissions in real time. Flaring emissions are determined in real time for a flare stack based on: 1) a flaring volume in conjunction with heat and material balances of systems that discharge to a flare system, and 2) a composition of each relief source that discharges to the flare system. A molar balance around the flare stack is performed in real time using the flaring emissions to determine the emissions.
G01N 33/00 - Recherche ou analyse des matériaux par des méthodes spécifiques non couvertes par les groupes
F23G 7/08 - Procédés ou appareils, p.ex. incinérateurs, spécialement adaptés à la combustion de déchets particuliers ou de combustibles pauvres, p.ex. des produits chimiques de gaz d'évacuation ou de gaz nocifs, p.ex. de gaz d'échappement utilisant des torchères, p.ex. dans des cheminées
89.
SYSTEM AND METHOD USING SENSORS EMBEDDED ON TAPE FOR CORROSION MONITORING
A system and method use a sensor embedded in flexible tape to monitor for corrosion of a structure, such as a conveyance line in a well. The system comprises the structure, a spool, a flexible tape, a sensor, a spool driver, and a processor. The structure includes a window adjacent to an element under test. The flexible tape is retained by the spool. The sensor is embedded in the tape, with the sensor being configured to detect a corrosion of the element and to generate corresponding sensor data. The spool driver is coupled to the spool and advances the tape from the spool to position the sensor adjacent to the window, thereby to position the sensor adjacent to the element to detect the corrosion. The processor is configured by code stored therein to receive the sensor data and to generate and output an alert of the detected corrosion.
E21B 47/12 - Moyens pour la transmission de signaux de mesure ou signaux de commande du puits vers la surface, ou de la surface vers le puits, p.ex. pour la diagraphie pendant le forage
90.
MICRO-ELECTROMECHANICAL SYSTEM (MEMS) INTERFEROMETER FOR FT-MIR SPECTROSCOPY
A microelectromechanical (MEMS) interferometer is provided. The MEMS interferometer includes a pair of movable mirrors that are positioned along perpendicular axes, wherein each of the pair of movable mirrors is coupled to a mechanism. The mechanism includes an electrostatic actuator driving a displacement amplification mechanism, and the displacement amplification mechanism driving each of the pair of the movable mirrors. The MEMS interferometer includes a beam splitter that is positioned at an intersection of the perpendicular axes extending through each movable mirror and the beam splitter. The MEMS interferometer also includes a metasurface microbolometer placed in line with the beam splitter to measure an intensity of a recombined beam from the pair of movable mirrors.
Microcapsule encapsulated microcapsule (MIM) material compositions and methods for preparing the same are provided for self-repairing cements that include a plurality of first microcapsules where each of the first microcapsule comprises a first core and a first shell and a plurality of second microcapsules that each comprise a second core and a second shell where the plurality of second microcapsules are dispersed within a continuous phase comprised within the first core of each of the first microcapsules. The MIM material may be prepared such that the first and second shell comprise a cross-linked material. Compositions for self-healing cement slurries are also provided and include cement, sand, water, and microcapsule encapsulated microcapsules (MIM) materials.
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 grains; Traitement 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 28/02 - Compositions pour mortiers, béton ou pierre artificielle, contenant des liants inorganiques ou contenant le produit de réaction d'un liant inorganique et d'un liant organique, p.ex. contenant des ciments de polycarboxylates contenant des ciments hydrauliques autres que ceux de sulfate de calcium
A system and method automatically orient geological core samples. The system comprises a camera, a core analyzer module, and a core sample rotation apparatus. The camera is configured to capture a reference image of a cross-section of a reference core sample from a well and to capture a sample image of a cross-section of the to-be-oriented core sample from the well. The core analyzer module comprises code executable in a hardware processor to process the sample image to substantially match the reference image, and to determine an orientation angle of the match. The core sample rotation apparatus is configured to orient the to-be-oriented core sample by the orientation angle. A method comprises steps performed during operation of the system.
Systems and methods include a system for deploying and using a customized logging-while-drilling (LWD) tool. A command is provided by a tool control system to a mechanical drive of a LWD tool to cause pads and caliper fingers of the LWD tool to extend radially, lock in place using a locking mechanism, and begin to capture downhole measurements while the LWD tool is deployed in a borehole of a well. Pressure pulse cycles produced by a series of distinct high and low flow rates by the tool control system are provided to create pulses to be detected downhole by pressure transducers. A measurement sequence for caliper and resistivity images is triggered by the tool control system. The measurement sequence is terminated by the tool control system to conserve energy.
A system for controlling tubing member assembly diameter includes a control unit, a computing device, a tubing member assembly, and an elastomer member. The tubing member assembly includes an outer pipe member that defines a static diameter and an inner pipe member having an outer surface and defining a dynamic diameter that changes from a first inner pipe member value to a second inner pipe member value. The elastomer member is disposed between the outer pipe member and the inner pipe member such that an inner area of the elastomer member is disposed on the outer surface of the inner pipe member. The elastomer member expands from a first position to a second position to constrict the dynamic diameter from the first inner pipe member value to the second inner pipe member value responsive to receiving an electrical signal from the control unit.
This disclosure relates to blended polymeric membranes containing a polyimide polymeric matrix blended with a crosslinked polymer of intrinsic microporosity and methods of using the membranes for gas separation applications, such as removal of CO2 from natural gas.
B01D 71/64 - Polyimides; Polyamide-imides; Polyester-imides; Polyamide-acides ou précurseurs similaires de polyimides
B01D 69/02 - Membranes semi-perméables destinées aux procédés ou aux appareils de séparation, caractérisées par leur forme, leur structure ou leurs propriétés; Procédés spécialement adaptés à leur fabrication caractérisées par leurs propriétés
B01D 67/00 - Procédés spécialement adaptés à la fabrication de membranes semi-perméables destinées aux procédés ou aux appareils de séparation
B01D 53/22 - SÉPARATION Épuration chimique ou biologique des gaz résiduaires, p.ex. gaz d'échappement des moteurs à combustion, fumées, vapeurs, gaz de combustion ou aérosols par diffusion
C08L 79/08 - Polyimides; Polyester-imides; Polyamide-imides; Polyamide-acides ou précurseurs similaires de polyimides
C08J 3/00 - Procédés pour le traitement de substances macromoléculaires ou la formation de mélanges
A downhole well tool includes a tool body attached to a well string, a sealing packer element partially circumscribing the tool body from a first circumferential end to a second circumferential end, a side groove formed at least partially in the tool body and positioned between the first circumferential end and the second circumferential end of the sealing packer element, and a fluid conduit disposed within the tool body and extending to the side groove. The sealing packer element expands and seals against an inner wall of a wellbore. The side groove forms a channel in an exterior surface of the tool body between the first circumferential end and the second circumferential end of the sealing packer element, and the fluid conduit includes at least one nozzle positioned at the side groove, where the fluid conduit flows a fluid into the channel of the side groove.
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
Systems and methods include a computer-method for updating drilling parameters in real time. A predicted breakout geometry is determined for a drilling operation of a petrochemical well. Determining the predicted breakout geometry uses an analytical elastic breakout model and includes determining a predicted breakout width, a predicted breakout depth, and a predicted breakout angle. The predicted breakout geometry is compared with an observed breakout geometry at an observed breakout angle determined in real time using real-time caliper log data obtained from a multi-finger caliper during the drilling operation. A maximum horizontal stress value in the analytical elastic breakout model is adjusted until the predicted breakout geometry matches the observed breakout geometry within a percentage threshold. Mud weight calculations for the drilling operation are updated in response to the comparing and adjusting. Drilling parameters for the drilling operation are changed in real time in response to the updating.
E21B 44/00 - Systèmes de commande automatique spécialement adaptés aux opérations de forage, c. à d. systèmes à fonctionnement autonome ayant pour rôle d'exécuter ou de modifier une opération de forage sans l'intervention d'un opérateur humain, p.ex. systèmes de ; Systèmes spécialement adaptés à la surveillance de plusieurs variables ou conditions de forage
98.
MINIATURE FT-MIR USING A MEMS INTERFEROMETER WITH A METASURFACE EMITTER AND DETECTOR
A miniature Fourier transform mid-infrared (FT-MIR) spectrometer is provided. The FT-MIR includes a metasurface IR source to emit radiation when heated, a microelectromechanical (MEMS) interferometer, and a metasurface microbolometer to measure an interferogram from the MEMS interferometer, wherein the miniature FT-MIR spectrometer is less than about 20 mm in outer diameter.
G01N 21/3577 - Couleur; Propriétés spectrales, c. à d. comparaison de l'effet du matériau sur la lumière pour plusieurs longueurs d'ondes ou plusieurs bandes de longueurs d'ondes différentes en recherchant l'effet relatif du matériau pour les longueurs d'ondes caractéristiques d'éléments ou de molécules spécifiques, p.ex. spectrométrie d'absorption atomique en utilisant la lumière infrarouge pour l'analyse de liquides, p.ex. l'eau polluée
A system and method including a sulfur recovery system (SRU) having a Claus system, reacting hydrogen sulfide and oxygen in a furnace to give sulfur dioxide, performing a Claus reaction in the furnace to give elemental sulfur, performing the Claus reaction in a Claus reactor to give elemental sulfur at a temperature greater than a dew point of the elemental sulfur, performing the Claus reaction in a Claus cycling reactor to give elemental sulfur at a temperature less than a solidification temperature of the elemental sulfur, depositing the elemental sulfur as solid elemental sulfur on catalyst in the Claus cycling reactor, and regenerating (heating) the Claus cycling reactor thereby forming elemental sulfur vapor from the solid elemental sulfur.
C01B 17/04 - Préparation du soufre; Purification à partir de composés sulfurés gazeux, y compris les sulfures gazeux
B01J 8/06 - Procédés chimiques ou physiques en général, conduits en présence de fluides et de particules solides; Appareillage pour de tels procédés avec des particules immobiles, p.ex. dans des lits fixes les particules solides étant disposées dans des tubes
B01J 8/36 - Procédés chimiques ou physiques en général, conduits en présence de fluides et de particules solides; Appareillage pour de tels procédés les particules étant fluidisées selon la technique du "lit fluidisé" le déplacement des particules dans le lit fluidisé étant essentiellement horizontal
B01J 19/24 - Réacteurs fixes sans élément interne mobile
B01J 21/06 - Silicium, titane, zirconium ou hafnium; Leurs oxydes ou hydroxydes
F22B 1/16 - Méthodes de production de vapeur caractérisées par le genre de chauffage par exploitation de l'énergie thermique contenue dans une source chaude la source chaude étant un liquide chaud ou une vapeur chaude, p.ex. un liquide résiduel, une vapeur résiduelle
100.
TREATING SULFUR DIOXIDE CONTAINING STREAM BY ACID AQUEOUS ABSORPTION
Provided herein are methods and systems for treating a tail gas of a Claus process to remove sulfur-containing compounds. The method includes combusting a tail gas of a Claus process in an excess of oxygen gas to yield a thermal oxidizer effluent. The thermal oxidizer effluent includes sulfur dioxide, water vapor, and oxygen. The effluent is routed to a quench tower and contacted with a dilute aqueous acid quench stream to yield sulfurous acid, hydrated sulfur dioxide, or both. The sulfurous acid or hydrated sulfur dioxide is oxidized with the excess oxygen from the thermal oxidizer effluent to yield sulfuric acid.
