A system and method of obtaining a high SNR seismic while-drilling data and a robust velocity profile of a geological site having a main well and at least one uphole located in the vicinity of the main well, the seismic profile being obtained from seismic waves generated by a drilling device located at the main well. The method comprises deploying at least one distributed acoustic fiber optic cable vertically in the at least one uphole, at least a portion of the fiber optic cable being positioned at a depth exceeding a predetermined depth below the surface, receiving seismic data at recording station positioned on the at least one fiber optic cable at at least the predetermined depth, generating, at a processor a high SNR seismic while- drilling signal; yielding a reliable velocity profile from the seismic data received, and determining a presence of near surface hazards from the generated high SNR while drilling seismic data.
G01V 1/42 - Séismologie; Prospection ou détection sismique ou acoustique spécialement adaptées au carottage en utilisant des générateurs dans un puits et des récepteurs dans un autre endroit ou vice versa
A method for reservoir simulation is disclosed. The method includes selecting a coarse grid size (300) for a plurality of grid blocks in a reservoir model of a reservoir, computing, by a computer processor and based at least on a fractional flow curve of oil and water, a water saturation at a water front within a grid block of the plurality of grid blocks and an average water saturation of the grid block (302, 304), and computing, by the computer processor and based at least on the water saturation at the water front within the grid block and the average water saturation of the grid block, a water saturation distribution in the reservoir by solving reservoir simulator equations (308), wherein solving the reservoir simulator equations comprises computing a single water saturation value for each of the plurality of grid blocks based on the coarse grid size.
A method includes taking at least one image of a plurality of returned cuttings (103) from a well (111) using a fluorescent imaging camera (124), analyzing the at least one image with an imaging processing system (125) to obtain detection data including a calculated percentage of a first emitted fluorescent light to formation cuttings, sending the detection data to an analysis and control program (130) to correlate the returned cuttings (103) with a depth in the well (111), and automatically controlling at least one drilling parameter for drilling the well (111) based on the detection data.
4.
METHOD FOR INTELLIGENT AUTOMATIC ROCK FRAGMENTS DEPTH DETERMINATION WHILE DRILLING
A method for depth determination of drilled rock cuttings is disclosed. The taggant is injected and transported downhole along the mud stream (204, 205) and attaches to the rock cuttings. Taggant impregnated cuttings are detected at the surface (108) based on molecular weight, emission wavelengths or radio frequency characteristics for encoding the taggant. The identification code identifies the depth of the drill bit when the particular batch of the taggant is released into the mud. The detection data, in addition to mud properties, flow rates, drill volume and penetration rates, formation characteristics, and well specifications are transferred to and analyzed by a taggant analysis and control engine (202). The taggant analysis and control engine (202) controls an IoT controller (203) that adapts the parameters of the taggant injection pump (206) to achieve an intelligent controlled release to optimize the depth characterization process.
A reversible polycrystalline diamond compact (PDC) bit (200, 400) is disclosed. The reversible PDC bit (400) includes at least one blade (401a, 401b), at least one front cutter (402) disposed on a first side of the at least one blade (401a), and at least one rear cutter (403) disposed on a second side of the at least one blade (401b), wherein the first side is opposite to the second side along a circumferential direction of the reversible PDC bit (400), wherein rotating the reversible PDC bit (400) in a clockwise direction engages the at least one front cutter (402) to cut into a subterranean formation (104), and wherein rotating the reversible PDC bit (400) in a counter-clockwise direction engages the at least one rear cutter (403) to cut into the subterranean formation (104).
E21B 10/43 - Trépans rotatifs du type racleur comportant des dents, des lames ou des organes de coupe similaires, p.ex. du type à fourche, en queue de poisson caractérisés par la disposition des dents ou des autres éléments coupants
E21B 10/46 - Trépans caractérisés par des parties résistant à l'usure, p.ex. des diamants rapportés
6.
A LOW PH-BASED OIL RECOVERY METHOD FOR CARBONATE RESERVOIRS
Systems and methods include a computer-implemented method for generating and using a graph/document structure to store reservoir simulation results. A graph is generated that represents reservoir simulation results of a reservoir simulation performed on a reservoir using a reservoir simulation model. The graph represents a full set of relational data and non-relational data included in the reservoir simulation results. The graph stores graph information and relational data in a graph/document structure. Objects of the reservoir, elements of the reservoir simulation results, and inputs of the reservoir simulation model are represented as vertices in the graph. Relationships between vertices are represented as edges in the graph. An edge is defined by a pair of vertices in the graph.
E21B 41/00 - Matériel ou accessoires non couverts par les groupes
G01V 99/00 - Matière non prévue dans les autres groupes de la présente sous-classe
G06F 30/12 - CAO géométrique caractérisée par des moyens d’entrée spécialement adaptés à la CAO, p.ex. interfaces utilisateur graphiques [UIG] spécialement adaptées à la CAO
G06F 30/20 - Optimisation, vérification ou simulation de l’objet conçu
8.
ONLINE MEASUREMENT OF DISPERSED OIL PHASE IN PRODUCED WATER
Online measurement of dispersed oil phase in produced water can be implemented a method on-site of a flowline transporting a fluid that includes dispersed oil in water. A sample of the fluid flowed through the flowline is obtained. The sample includes the oil phase and the water phase. The sample is combined with a chemical element that can separate the oil phase in the sample from the water phase in the sample. The separated oil phase and the chemical element are transferred into a measurement cell. The chemical element is removed from the measurement cell. After the chemical element is removed from the measurement cell, a quantity of the oil phase in the sample in the measurement cell is determined by a capacitive measurement technique. The determined quantity of the oil phase in the sample is provided.
Systems and methods include a computer implemented method for evaluating rock physical properties. Drilling acoustic signals are received in real time during a drilling operation through rock at a drilling location. Transformed data is generated in a frequency domain from the drilling acoustic signals. The transformed data includes frequency and amplitude information for the drilling acoustic signals. De-noised transformed data is generated from the transformed data by filtering noise including background noise generated in a recording system and top drive rotation generated traces. A lithological significant frequency range that includes de-noised significant data points is determined from the de-noised transformed data. Physical properties of the rock are determined in real time using drill bit rotation rates and the amplitudes of the de-noised significant data points.
Cutters for a downhole drill bit can be formed by providing a catalyst-free synthesized polycrystalline diamond (PCD) having a cross-sectional dimension of at least 8 millimeters; providing a substrate comprising tungsten carbide; and attaching the synthesized PCD to the substrate comprising tungsten carbide to form a PDC cutter.
C04B 37/00 - Liaison des articles céramiques cuits avec d'autres articles céramiques cuits ou d'autres articles, par chauffage
C04B 35/56 - Produits céramiques mis en forme, caractérisés par leur composition; Compositions céramiques; Traitement de poudres de composés inorganiques préalablement à la fabrication de produits céramiques à base de non oxydes à base de carbures
C04B 35/622 - Procédés de mise en forme; Traitement de poudres de composés inorganiques préalablement à la fabrication de produits céramiques
E21B 10/46 - Trépans caractérisés par des parties résistant à l'usure, p.ex. des diamants rapportés
B22F 7/08 - Fabrication de couches composites, de pièces ou d'objets à base de poudres métalliques, par frittage avec ou sans compactage de pièces ou objets composés de parties différentes, p.ex. pour former des outils à embouts rapportés avec une ou plusieurs parties non faites à partir de poudre
11.
DRILLING TOOLS MADE OF WURTZITE BORON NITRIDE (W-BN)
Systems and methods include a computer-implemented method can be used to make drilling tools from new wurtzite boron nitride (w-BN) superhard material. An ultra-high-pressure, high-temperature operation is performed on pure w-BN powder to synthesize w-BN and cubic boron nitride (c-BN) compact having a first size greater than particles of the pure w-BN powder. The ultra-high-pressure, high-temperature operation includes pressurizing the w-BN powder to a pressure of approximately 20 Gigapascal, heating the w-BN powder at a heating rate of 100 C/minute and cooling the w-BN powder at a cooling rate of 50 C/minute. The compact is cut to a second size smaller than the first size using laser cutting tools. The cut compact is bonded metallurgically, mechanically, or both metallurgically and mechanically onto a tool substrate to form the drilling tool.
E21B 10/55 - Trépans caractérisés par des parties résistant à l'usure, p.ex. des diamants rapportés le trépan étant du type racleur, p.ex. trépan du type à fourche comportant des éléments de coupe préformés
12.
COMPOSITIONS, SYSTEMS, AND METHODS FOR IRON SULFIDE SCALE IDENTIFICATION, PREVENTION, AND REDUCTION
Compositions and methods for prevention and reduction of iron sulfide scale formation, one method including detecting at least one component indicative of an iron sulfide scale precursor, the at least one component selected from the group consisting of: H2S;HS; S2-; S2- n; FeS(aq); Fe2+; Fe3+; and combinations of the same; preparing a composition to react with the iron sulfide scale precursor, the composition comprising at least one compound selected from the group consisting of: a methylating agent; a metal operable to react with sulfide species; a compound to increase the oxidation state of Fe2+; and combinations of the same; and applying the composition to the iron sulfide scale precursor to consume the iron sulfide scale precursor.
G01N 27/30 - Composants de cellules électrolytiques Électrodes, p.ex. électrodes pour tests; Demi-cellules
G01N 27/42 - Mesure du dépôt ou de la libération de matériaux d'un électrolyte; Coulométrie, c. à d. mesure de l'équivalent de Coulomb du matériau dans un électrolyte
A well pad construction system includes a construction area (20), surface compaction equipment (22, 24) to compact the construction area (20), an excavator (34) disposed at the construction area (20) and movable to generate an excavated area (37), a cellar (14) disposed in the excavated area (37), controlled low-strength material (CLSM), and backfill equipment disposed around the excavated area. The backfill equipment (42) is moveable over the construction area (20) to pour CLSM into a gap (18) between the cellar (14) and surrounding medium in the excavated area for holding the cellar (14) in place and providing a firm well pad (10) from which a rig (50) may operate.
A drilling assembly that includes a drill string, a drill bit assembly, and a transmission sub disposed between the drill bit assembly and the drill string. The transmission sub includes a first tube attached to the drill string and a second tube rotationally coupled to a downhole end of the first tube. The second tube is coupled to the drill bit assembly. The transmission sub also includes a clutch assembly coupled to the first tube and has mechanical engagement features configured to simultaneously engage mechanical engagement features of the first tube and mechanical engagement features of the second tube to rotationally lock the first tube to the second tube. At least a portion of the clutch assembly moves along a longitudinal axis of the first tube to disengage the second mechanical engagement features of the second tube to rotationally unlock the first tube from the second tube.
KING FAHD UNIVERSITY OF PETROLEUM AND MINERALS (Arabie saoudite)
Inventeur(s)
Al-Nakhli, Ayman
Mahmoud, Mohamed Ahmed Nasr Eldin
Abrégé
Reservoir stimulation treatment diversion methods, systems, and compositions, one method including identifying a reservoir requiring liquid stimulation treatment in a lesser-permeability portion of the reservoir; identifying a greater-permeability portion of the reservoir, the greater-permeability portion of the reservoir having a greater permeability than the lesser-permeability portion; disposing a gas in the greater-permeability portion of the reservoir; injecting a liquid stimulation treatment into the reservoir; and allowing the gas in the greater-permeability portion of the reservoir to divert the liquid stimulation treatment into the lesser-permeability portion to stimulate fluid production from the lesser-permeability portion of the reservoir.
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
KING FAHAD UNIVERSITY OF PETROLEUM & MINERALS (Arabie saoudite)
Inventeur(s)
Saleh, Tawfik Abdo
Al-Arfaj, Mohammed Khalid
Rana, Azeem A.
Abrégé
A water-based wellbore fluid may include an aqueous base fluid and a modified graphene shale inhibitor that comprises one or more substituents that are covalently bonded to graphene via a linking group. One of the one or more substituents may be a hydrocarbon group that has a number of carbon atoms in the range from 8 to 14.
Methods, systems, and computer-readable medium to perform operations for simulating performance of a reservoir that includes a wellbore. The operations include determining a constraint for an intelligent completion in a model of the wellbore, where the constraint includes a condition and a responsive action. The operations further include performing, in response to determining that the condition is satisfied, the responsive action. Further, the operations include determining, in response to performing the responsive action, transfer equations for the model of the wellbore. Yet further, the operations include building, using the transfer equations, a wellbore computation matrix for the model of the wellbore. In addition, the operations include solving the wellbore computation matrix and determining that a solution to the wellbore computation matrix has converged to an acceptable tolerance. The operations also include responsively determining that the converged solution is indicative of flow in the model of the wellbore.
E21B 43/00 - Procédés ou dispositifs pour l'extraction de pétrole, de gaz, d'eau ou de matériaux solubles ou fusibles ou d'une suspension de matières minérales à partir de puits
E21B 41/00 - Matériel ou accessoires non couverts par les groupes
E21B 43/12 - Procédés ou appareils pour commander l'écoulement du fluide extrait vers ou dans les puits
E21B 43/14 - Extraction d'un puits à horizons multiples
18.
SYSTEMS AND METHODS FOR ACTUATING DOWNHOLE DEVICES AND ENABLING DRILLING WORKFLOWS FROM THE SURFACE
Systems and methods for actuation of downhole devices are disclosed. The system includes a first cylindrical pipe having one or more first materials attached to an outer surface of the first cylindrical pipe, a second cylindrical pipe co-axial with the first cylindrical pipe and having a diameter greater than the first cylindrical pipe, the second cylindrical pipe comprising one or more second materials disposed on an inner surface of the second cylindrical pipe, wherein the first materials generate one or more signals when the first materials come in contact with the second materials, and a digital logic circuit configured to receive the one or more signals as input, and generate an output based on the input, the output configured for actuation of the downhole devices.
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
E21B 41/00 - Matériel ou accessoires non couverts par les groupes
H10N 30/85 - Matériaux actifs piézo-électriques ou électrostrictifs
E21B 34/06 - Aménagements des vannes pour les trous de forage ou pour les puits dans les puits
H02N 2/18 - Machines électriques en général utilisant l'effet piézo-électrique, l'électrostriction ou la magnétostriction fournissant une sortie électrique à partir d'une entrée mécanique, p.ex. générateurs
19.
SYSTEMS AND METHODS FOR CONTROLLED RELEASE OF SENSOR SWARMS DOWNHOLE
Methods and systems for monitoring conditions within a wellbore of a subterranean well include extending a drill string into the subterranean well from a terranean surface. The drill string has an actuator assembly, a sensor compartment, and a plurality of sensors located within the sensor compartment. The actuator assembly is instructed to transmit a swarm release signal to a central power unit of the sensor compartment so that the central power unit of the sensor compartment releases certain of the plurality of sensors from the sensor compartment. Data from the sensors is transferred to a data processing system after the sensors reach the terranean surface.
E21B 47/12 - Moyens pour la transmission de signaux de mesure ou signaux de commande du puits vers la surface, ou de la surface vers le puits, p.ex. pour la diagraphie pendant le forage
E21B 23/00 - Appareils pour déplacer, mettre en place, verrouiller, libérer ou retirer, les outils, les packers ou autres éléments dans les trous de forage
E21B 47/01 - Dispositifs pour supporter des instruments de mesure sur des trépans, des tubes, des tiges ou des câbles de forage; Protection des instruments de mesure dans les trous de forage contre la chaleur, les chocs, la pression ou similaire
20.
DEPLOYING WELLBORE PATCH FOR MITIGATING LOST CIRCULATION
Systems, methods, and apparatuses for deploying a lost circulation fabric (LCF) to seal a lost circulation zone during a drilling operation. The LCF may be contained within a lost circulation fabric deployment system (LCFDS) that is coupled to a tubular of a drilling string. The LCFDS may include a controller and sensors to detect the presence of a lost circulation zone and deploy the LCF upon detection of the lost circulation zone. In some implementations, a plurality of LCFDSs may be disposed on the tubular and work in cooperation to deploy a plurality of LCFs to form a seal along the lost circulation zone.
Systems, methods, and apparatuses for deploying a lost circulation fabric (LCF) to seal a lost circulation zone during a drilling operation. The LCF may be contained within a lost circulation fabric deployment system (LCFDS) that is coupled to a tubular of a drilling string. The LCFDS may include a controller and sensors to detect the presence of a lost circulation zone and deploy the LCF upon detection of the lost circulation zone. In some implementations, a plurality of LCFDSs may be disposed on the tubular and work in cooperation to deploy a plurality of LCFs to form a seal along the lost circulation zone.
E21B 33/13 - Procédés ou dispositifs de cimentation, de bouchage des trous, des fissures ou analogues
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 47/12 - Moyens pour la transmission de signaux de mesure ou signaux de commande du puits vers la surface, ou de la surface vers le puits, p.ex. pour la diagraphie pendant le forage
E21B 47/00 - Relevés dans les trous de forage ou dans les puits
22.
DEPLOYING WELLBORE PATCH FOR MITIGATING LOST CIRCULATION
Systems, methods, and apparatuses for deploying a lost circulation fabric (LCF) to seal a lost circulation zone during a drilling operation. The LCF may be contained within a lost circulation fabric deployment system (LCFDS) that is coupled to a tubular of a drilling string. The LCFDS may include a controller and sensors to detect the presence of a lost circulation zone and deploy the LCF upon detection of the lost circulation zone. In some implementations, a plurality of LCFDSs may be disposed on the tubular and work in cooperation to deploy a plurality of LCFs to form a seal along the lost circulation zone.
E21B 33/13 - Procédés ou dispositifs de cimentation, de bouchage des trous, des fissures ou analogues
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 47/12 - Moyens pour la transmission de signaux de mesure ou signaux de commande du puits vers la surface, ou de la surface vers le puits, p.ex. pour la diagraphie pendant le forage
E21B 47/00 - Relevés dans les trous de forage ou dans les puits
A method for reducing condensate in a subsurface formation is disclosed. The method includes introducing a reactive mixture including an aqueous solution, urea, dopamine, a silica nanoparticle precursor, a silane grafting compound, and an alcohol compound into the subsurface formation. The method also includes allowing generation of ammonia through thermal decomposition of the urea and allowing the silica nanoparticle precursor to hydrolyze, thereby forming silica nanoparticles. The method further includes allowing the silane grafting compound to graft onto the silica nanoparticles, thereby forming functionalized silica nanoparticles. The method also includes allowing polymerization of the dopamine, thereby forming polydopamine. The method also includes allowing the functionalized silica nanoparticles to attach to the subsurface formation via the polydopamine, thereby reducing condensate in the subsurface formation.
C09K 8/86 - Compositions à base d'eau ou de solvants polaires contenant des composés organiques
C09K 3/18 - Substances non couvertes ailleurs à appliquer sur des surfaces pour y minimiser l'adhérence de la glace, du brouillard ou de l'eau; Substances antigel ou provoquant le dégel pour application sur des surfaces
Methods for producing proppants with a polyurethane proppant coating are provided. The methods include forming aliphatic polycarbonate polyols from the copolymerization of epoxide and CO2 monomers, forming the polyurethane proppant coating by reacting the aliphatic polycarbonate polyols and at least one of diisocyanate monomers and isocyanate monomers, and coating proppant particles with the polyurethane proppant coating to produce coated proppants with polyurethane proppant coating.
Methods for producing proppants with a fluorinated polyurethane proppant coating are provided. The methods include coating the proppant particles with a strengthening agent, a strengthening agent, and a resin to produce proppants with fluorinated polyurethane proppant coating. Additionally, a proppant comprising a proppant particle and a fluorinated polyurethane proppant coating is provided. The fluorinated polyurethane proppant coating includes a strengthening agent, a strengthening agent, and a resin. The fluorinated polyurethane proppant coating coats the proppant particle. Additionally, a method for increasing a rate of hydrocarbon production from a subsurface formation through the use of the proppants is provided.
A composition includes an emulsion of nanocomposite in water and a proppant. The nanocomposite includes an epoxy resin and an organically modified montmorillonite compatible to the epoxy resin.
A system and method of evaluating and correcting for the effects of a near-surface anomaly on surface-to-borehole (STB) measurement data in a geological halfspace comprises transmitting electromagnetic radiation from an EM source located on a ground surface which is positioned over the near- surface anomaly, measuring EM fields at a plurality of remote EM receivers located on the surface at a far distance from the EM source, obtaining vertical STB measurement data downhole, determining an orientation and moment of a secondary source equivalent dipole associated with the near- surface anomaly excited by the radiation transmitted by the EM source based on measurements of the EM fields at the plurality of remote receivers, determining a correction factor for the secondary source equivalent dipole on the EM field measurements at the plurality of remote receivers, and removing the effects of the near surface anomaly on the vertical STB measurement data using the correction factor.
G01V 3/26 - 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
28.
NANOPARTICLE COATED PROPPANTS AND METHODS OF MAKING AND USE THEREOF
Methods for producing proppant with nanoparticle proppant coating are provided. The methods include coating the proppant particles with a strengthening agent, functionalized nanoparticles, and unfunctionalized organic resin to produce proppant with nanoparticle proppant coating. Additionally, a proppant comprising a proppant particle and a nanoparticle proppant coating is provided. The nanoparticle proppant coating includes a strengthening agent, functionalized nanoparticles, and unfunctionalized organic resin. The nanoparticle proppant coating coats the proppant particle. Additionally, a method for increasing a rate of hydrocarbon production from a subsurface formation through the use of the proppant is provided.
KING ABDULLAH UNIVERSITY OF SCIENCE AND TECHNOLOGY (Arabie saoudite)
Inventeur(s)
Hveding, Frode
Ashry, Islam
Yuan, Mao
Ooi, Boon Siew
Arsalan, Muhammad
Abrégé
Methods, systems, and apparatuses for simultaneous distributed temperature and vibration sensing using a multimode optical fiber (MMF) is disclosed. The distributed temperature and vibration sensing may include a single mode optical fiber (SMF) coupled to an MMF via a connection in which a central axis of the SMF is aligned with a central axis of the MMF. The connections provides of excitation of the fundamental mode within the MMF by light passing from the SMF into the MMF through the connection.
G01D 21/02 - Mesure de plusieurs variables par des moyens non couverts par une seule autre sous-classe
G01K 11/324 - Mesure de la température basée sur les variations physiques ou chimiques, n'entrant pas dans les groupes , , ou utilisant des changements dans la transmittance, la diffusion ou la luminescence dans les fibres optiques utilisant la diffusion Raman
G01D 5/353 - Moyens mécaniques pour le transfert de la grandeur de sortie d'un organe sensible; Moyens pour convertir la grandeur de sortie d'un organe sensible en une autre variable, lorsque la forme ou la nature de l'organe sensible n'imposent pas un moyen de conversion déterminé; Transducteurs non spécialement adaptés à une variable particulière utilisant des moyens optiques, c. à d. utilisant de la lumière infrarouge, visible ou ultraviolette avec atténuation ou obturation complète ou partielle des rayons lumineux les rayons lumineux étant détectés par des cellules photo-électriques en modifiant les caractéristiques de transmission d'une fibre optique
G01H 9/00 - Mesure des vibrations mécaniques ou des ondes ultrasonores, sonores ou infrasonores en utilisant des moyens sensibles aux radiations, p.ex. des moyens optiques
The present disclosure is directed to systems, methods, and apparatuses for obtaining sensor data from sensors incorporated into a drill bit during a drilling operation to form a wellbore. The obtained sensor data may be used to control an aspect of the drilling operation. The sensors may be incorporated into drill bit cutters of a drill bit, a drill bit body of a drill bit, or both. Example sensors include acoustic sensors, pressure sensor, vibration sensor, accelerometers, gyroscopic sensors, magnetometer sensors, and temperature sensors.
E21B 47/107 - Localisation des fuites, intrusions ou mouvements du fluide utilisant des moyens acoustiques
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 47/01 - Dispositifs pour supporter des instruments de mesure sur des trépans, des tubes, des tiges ou des câbles de forage; Protection des instruments de mesure dans les trous de forage contre la chaleur, les chocs, la pression ou similaire
A drill bit includes multiple cutting devices and a microelectronics unit. Each cutting device of the multiple cutting devices includes a cutting layer formed to cut a rock formation and a capacitive sensor disposed adjacent the cutting layer. The capacitive sensor is configured to generate an electric field across the cutting layer and to transmit a signal corresponding to a voltage associated with the electric field. The microelectronics unit of the drill bit is configured to receive the signal from the capacitive sensor of each cutting device of the multiple cutting devices such that the microelectronics unit receives multiple signals and to determine an indicator of mechanical wear of the drill bit based on a change in the voltage associated with the electric field across the cutting layer of each cutting device of the multiple cutting devices using the multiple signals.
E21B 10/42 - Trépans rotatifs du type racleur comportant des dents, des lames ou des organes de coupe similaires, p.ex. du type à fourche, en queue de poisson
E21B 10/46 - Trépans caractérisés par des parties résistant à l'usure, p.ex. des diamants rapportés
Methods of determining the integrity of a well are provided. The methods include mixing conductive materials into a fluid, introducing the fluid into the well, and allowing the conductive materials to coat a surface of a subsurface formation, thereby forming an electrically conductive data conduit coating. The methods further include transmitting data through the electrically conductive data conduit coating to determine the integrity of the well.
E21B 47/005 - Surveillance ou contrôle de la qualité ou du niveau de cimentation
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
C09K 8/00 - Compositions pour le forage des puits ou des trous de forage; Compositions pour le traitement des puits ou des trous de forage, p.ex. pour des opérations de complétion ou de réparation
E21B 33/138 - Plâtrage de la paroi du trou de forage; Injections dans la formation
33.
SELF-CONTAINED WELL INTERVENTION SYSTEM AND METHOD
A method for performing a well intervention operation includes the steps of: (a) sealingly coupling a lubricator onto an open top end of a well tree, the lubricator having a hollow interior in which a rotatable winch is contained, the winch having a cable wound thereabout; (b) attaching a tool to the cable; (c) lowering the tool within a well bore to which the well tree is attached; and (d) operating the winch from a location exterior to the lubricator to cause rotation of the winch and winding of the cable, whereby the tool is retrieved from the wellbore.
E21B 33/072 - 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 pour les outils manœuvrés par câbles
E21B 19/00 - Manipulation de tiges, tubages, tubes ou autre objets analogues à l'extérieur du trou de forage, p.ex. dans la tour de forage; Appareils pour faire avancer les tiges ou les câbles
Presented here are nanocomposites and rechargeable batteries, In certain embodiments, a nanocomposite is resistant to thermal runaway, and useful as an electrode material in rechargeable batteries that are safe, reliable, and stable when operated at high temperature and high pressure. The present disclosure also provides methods of preparing rechargeable batteries. For example, rechargeable batteries that include nanocomposites of the present disclosure as an electrode material have, in some embodiments, an enhanced performance and stability over a broad temperature range from room temperature to high temperatures. These batteries fill an important need by providing a safe and reliable power source for devices operated at high temperatures and pressures such as downhole equipment used in the oil industry.
H01M 4/13 - PROCÉDÉS OU MOYENS POUR LA CONVERSION DIRECTE DE L'ÉNERGIE CHIMIQUE EN ÉNERGIE ÉLECTRIQUE, p.ex. BATTERIES Électrodes Électrodes composées d'un ou comprenant un matériau actif Électrodes pour accumulateurs à électrolyte non aqueux, p.ex. pour accumulateurs au lithium; Leurs procédés de fabrication
H01M 10/0525 - Batteries du type "rocking chair" ou "fauteuil à bascule", p.ex. batteries à insertion ou intercalation de lithium dans les deux électrodes; Batteries à l'ion lithium
Presented here are nanocomposites, which are resistant to thermal runaway and are safe, reliable, and stable electrode materials for electrochemical storage systems (e.g., rechargeable batteries and supercapacitors) operated at high temperature and high pressure, electrochemical storage systems (e.g., rechargeable batteries and supercapacitors), and methods of making the same.
H01M 4/133 - PROCÉDÉS OU MOYENS POUR LA CONVERSION DIRECTE DE L'ÉNERGIE CHIMIQUE EN ÉNERGIE ÉLECTRIQUE, p.ex. BATTERIES Électrodes Électrodes composées d'un ou comprenant un matériau actif Électrodes pour accumulateurs à électrolyte non aqueux, p.ex. pour accumulateurs au lithium; Leurs procédés de fabrication Électrodes à base de matériau carboné, p.ex. composés d'intercalation du graphite ou CFx
H01M 4/136 - PROCÉDÉS OU MOYENS POUR LA CONVERSION DIRECTE DE L'ÉNERGIE CHIMIQUE EN ÉNERGIE ÉLECTRIQUE, p.ex. BATTERIES Électrodes Électrodes composées d'un ou comprenant un matériau actif Électrodes pour accumulateurs à électrolyte non aqueux, p.ex. pour accumulateurs au lithium; Leurs procédés de fabrication Électrodes à base de composés inorganiques autres que les oxydes ou les hydroxydes, p.ex. sulfures, séléniures, tellurures, halogénures ou LiCoFy
H01M 4/1393 - Procédés de fabrication d’électrodes à base de matériau carboné, p.ex. composés au graphite d'intercalation ou CFx
H01M 4/1397 - Procédés de fabrication d’électrodes à base de composés inorganiques autres que les oxydes ou les hydroxydes, p.ex. sulfures, séléniures, tellurures, halogénures ou LiCoFy
H01G 11/00 - Condensateurs hybrides, c. à d. ayant des électrodes positive et négative différentes; Condensateurs électriques à double couche [EDL]; Procédés de fabrication desdits condensateurs ou de leurs composants
Systems, methods, and apparatuses for detecting components of a multiphasic flow are disclosed. A flowmeter may include a plurality of optical fibers disposed across a fluid flow. The optical fibers may generate backscattering of a portion of a laser beam transmitted along the optical fibers. The backscattering may be produced by a grating formed by zinc dicyanoaurate formed in each of the optical fibers. Heterodyne detection may be used to determine a Brillouin frequency shift that is used to determine strain and temperature measurements at different locations along the optical fibers. Artificial Intelligence uses the strain and temperature measurements to determine a flow regime of the fluid flow and flow rates of components forming the fluid flow.
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
E21B 47/113 - Localisation des fuites, intrusions ou mouvements du fluide utilisant un rayonnement lumineux
G01F 1/05 - 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
G01F 1/688 - Dispositions de structure; Montage des éléments, p.ex. relativement à l'écoulement de fluide utilisant un élément de chauffage, de refroidissement ou de détection d'un type particulier
G01K 11/322 - Mesure de la température basée sur les variations physiques ou chimiques, n'entrant pas dans les groupes , , ou utilisant des changements dans la transmittance, la diffusion ou la luminescence dans les fibres optiques utilisant la diffusion de Brillouin
37.
METHODS AND SYSTEMS FOR DETERMINING FRACTURE AND MATRIX PERMEABILITY OF A SUBSURFACE FORMATION
Methods and systems for determining fracture and matrix permeability of a subsurface formation. The system includes two upstream reservoirs and two downstream reservoirs, and a sample cell connecting to the reservoirs with valves. The sample cell has a confining pressure (CF) from a fluid. A horizontal plug sample with sleeve is placed in a measurement cell with the confining fluid (CF). A pressure gauge is connected to the small upstream reservoir, and a pressure gauge is connected to the small downstream reservoir. The results provide two sets of effective-stress-dependent permeability values (including fracture permeability and matrix permeability, respectively) for characterizing the reservoir properties.
A system and method for specifying a composition for a frac fluid including varying crosslinker concentration and high-temperature stabilizer concentration to determine a discrete fracture network (DFN) and hydrocarbon production correlative with the DFN.
A casing for a drilling operation has a body portion having a length, a first end and a second end, an outer diameter, an inner diameter, and a central axis that is common to the outer diameter and the inner diameter, and an external thread formed on the outer diameter of the body portion, wherein the external thread starts at a first predetermined distance from the first end and ends at a second predetermined distance from the second end. The external thread includes a spiral groove or a helical thread formed on the outer diameter of the body portion. The casing includes a coating at least partially encapsulating the external thread, wherein the coating includes at least one material selected from the group consisting of polycrystalline diamond particles, diamond like carbon (DLC), tungsten carbide, boron nitride, silicon carbide, silicon nitride, and combinations thereof.
Cement slurries, cured cements, and methods of making cured cement and methods of using cement slurries are provided. The cement slurries have, among other attributes, improved elasticity and self-healing properties and may be used, for instance, in the oil and gas drilling industry. The cement slurry comprises water, a cement precursor material, and a block copolymer composition. The block copolymer composition has at least one copolymer backbone, with each copolymer backbone comprising at least two hard segments. Furthermore, a soft segment is disposed between the at least two hard segments. The copolymer backbone has at least one anhydride group grafted onto the soft segment, and the anhydride group is crosslinked by an aminosilane crosslinker.
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
A method and compounds for enhanced oil recovery (EOR) including flooding of a mixture of water and one or more of the compounds in a geological formation. The compounds have a fluoroalkyl group.
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
A system and method for flow synthesis of polymer nanoparticles in a continuous flow reactor having a channel. The polymer nanoparticles are synthesized from monomer in the presence of an initiator.
Systems, methods, and apparatuses for determining pore volume and pore volume compressibility of secondary porosity in rock samples is disclosed. In some implementations, determining a pore volume of a secondary porosity in a rock core sample may include saturating the rock sample with deuterium oxide (D2O) by applying a vacuum to the core sample covered by D2O; centrifuging the saturated rock sample at a selected rotational speed in the presence of a second fluid to displace a portion of the D2O from the rock sample with the second fluid; measuring the rock sample with low-field 1H nuclear magnetic resonance (NMR) to determine a volume of the second fluid within the rock sample; and determining a pore volume associated with a secondary porosity based on the volume of the second fluid within the rock sample.
G01N 15/08 - Recherche de la perméabilité, du volume des pores ou de l'aire superficielle des matériaux poreux
G01N 24/08 - Recherche ou analyse des matériaux par l'utilisation de la résonance magnétique nucléaire, de la résonance paramagnétique électronique ou d'autres effets de spin en utilisant la résonance magnétique nucléaire
G01R 33/44 - Dispositions ou appareils pour la mesure des grandeurs magnétiques faisant intervenir la résonance magnétique utilisant la résonance magnétique nucléaire [RMN]
44.
METHODS AND SYSTEMS FOR DETERMINING CORE PERMEABILITY IN PULSE DECAY EXPERIMENTS
Methods and systems method for determining core permeability of a subsurface formation. The method includes connecting an upstream reservoir to one end of a sample holder comprising a core sample of a subsurface formation, connecting a downstream reservoir to another end of the sample holder, providing a constant confining pressure within the sample holder, saturating the sample holder and the core sample with nitrogen at a saturation pressure, applying a pressure pulse to one end of the sample holder, and determining core permeability using the porosity of the mobile continuum when the pressure in the upstream reservoir, the downstream reservoir, and the mobile continuum is in equilibrium.
Methods, systems, and apparatus for carrying out rapid on-site optical chemical analysis in oil feeds are described. In one aspect, a system for manufacture of a tool includes a deposition reactor configured for molecular layer deposition or atomic layer deposition of metal powder to manufacture coated particles, a fabrication unit configured for 3D printing of the tool, and a controller that controls the deposition reactor and the fabrication unit, wherein the fabrication unit and the deposition reactor are integrated for automated fabrication of the tool using the coated particles from the deposition reactor as building material for the 3D printing.
B33Y 30/00 - Appareils pour la fabrication additive; Leurs parties constitutives ou accessoires à cet effet
B29C 64/153 - Procédés de fabrication additive n’utilisant que des matériaux solides utilisant des couches de poudre avec jonction sélective, p.ex. par frittage ou fusion laser sélectif
B29C 64/165 - Procédés de fabrication additive utilisant une combinaison de matériaux solides et liquides, p.ex. une poudre avec liaison sélective par liant liquide, catalyseur, inhibiteur ou absorbeur d’énergie
Real-time field data that is associated with a hydrocarbon reservoir drilling field is obtained. A carrying capacity index (CCI) and a cutting concentration annulus (CCA) are determined based on the real-time field data. In response to determining the CCI and CCA, the CCI is compared with a first predetermined value and the CCA is compared with a second predetermined value to obtain a comparison result. One or more parameters associated with the hydrocarbon reservoir drilling field are adjusted based on the comparison result through a user interface (UI).
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 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
A microchip (100) includes a PCB (102), a first contact feature (108) positioned along a first area of the PCB (102), a second contact feature (108) positioned along a second area of the PCB (102) that is disposed opposite the first area, a contact frame (110) including first and second contact members (124) respectively coupled to the first and second contact features (108) for signal communication between the first and second contact features (108) and an external electronic device, and a housing (112) enclosing an interior region of the microchip (100) and carrying the first and second contact members (124) of the contact frame (120).
Methods, systems, and computer-readable medium to perform operations including: obtaining, in real-time from one or more sensors of a drilling system, real-time drilling data of a drilling operation of drilling a wellbore; using the drilling data to calculate a carrying capacity index (CCI) of a drilling fluid and a cutting concentration in an annulus (CCA) of the wellbore; determining that at least one of the CCI and the CCA is outside a respective range; determining a corrective action to adjust the at least one of the CCI and the CCA to be within the respective range; and performing the corrective action.
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 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
49.
UNFOLDABLE DEVICE FOR CONTROLLING LOSS CIRCULATION
Embodiments of the disclosure provide an unfoldable device for controlling lost circulation in a target lost circulation zone in a borehole. The unfoldable device includes a sheet, a backbone, and a shell. The sheet has an unfolded state and a folded state. The backbone reinforces the sheet. The backbone includes a shape-memory material having an original state and a deformed state. The shell encapsulates the sheet in the folded state and the backbone in the deformed state. In some embodiments, the shell includes a degradable polymer that degrades in the borehole upon contact with a drilling fluid such that the sheet transitions to the unfolded state and the backbone transitions to the original state. The sheet in the unfolded state accumulates on a borehole wall at least partially covering an entrance to a macrochannel of the target lost circulation zone.
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
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 33/13 - Procédés ou dispositifs de cimentation, de bouchage des trous, des fissures ou analogues
Methods, systems, and computer-readable medium to perform operations including: determining, in real-time, values of drilling parameters of a drilling system drilling a wellbore; calculating, based on the values of the drilling parameters, a cuttings concentration in an annulus of the wellbore (CCA); calculating, based on the calculated CCA and a mud weight (MW) of a drilling fluid, an effective mud weight (MWeff) of the drilling fluid; and controlling, based on the effective mud weight, a component of the drilling system to adjust at least one of the drilling parameters.
E21B 21/08 - Commande ou surveillance de la pression ou de l'écoulement du fluide de forage, p.ex. remplissage automatique des trous de forage, commande automatique de la pression au fond
E21B 44/00 - Systèmes de commande automatique spécialement adaptés aux opérations de forage, c. à d. systèmes à fonctionnement autonome ayant pour rôle d'exécuter ou de modifier une opération de forage sans l'intervention d'un opérateur humain, p.ex. systèmes de ; Systèmes spécialement adaptés à la surveillance de plusieurs variables ou conditions de forage
E21B 45/00 - Mesure du temps de forage ou de la vitesse de pénétration
E21B 49/00 - Test pour déterminer la nature des parois des trous de 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
51.
REAL-TIME EQUIVALENT CIRCULATING DENSITY OF DRILLING FLUID
Methods, systems, and computer-readable medium to perform operations including: determining, in real-time, values of drilling parameters of a drilling system drilling a wellbore; calculating, based on the values of the drilling parameters, a cuttings concentration in an annulus of the wellbore (CCA); calculating, based on the calculated CCA and a mud weight (MW) of a drilling fluid, an effective mud weight (MWeff) of the drilling fluid; using the effective mud weight to calculate an equivalent circulating density (ECD) of the drilling fluid; and controlling, based on the equivalent circulating density, a component of the drilling system to adjust at least one of the drilling parameters.
E21B 21/08 - Commande ou surveillance de la pression ou de l'écoulement du fluide de forage, p.ex. remplissage automatique des trous de forage, commande automatique de la pression au fond
E21B 44/00 - Systèmes de commande automatique spécialement adaptés aux opérations de forage, c. à d. systèmes à fonctionnement autonome ayant pour rôle d'exécuter ou de modifier une opération de forage sans l'intervention d'un opérateur humain, p.ex. systèmes de ; Systèmes spécialement adaptés à la surveillance de plusieurs variables ou conditions de forage
52.
AUTOMATED PRODUCTION OPTIMIZATION TECHNIQUE FOR SMART WELL COMPLETIONS USING REAL-TIME NODAL ANALYSIS
Systems and methods include a method providing automated production optimization for smart well completions using real-time nodal analysis including real-time modeling. Real-time well rates and flowing bottom-hole pressure data are collected by a multilateral well optimizing system at various choke settings for multiple flow conditions for each lateral of a multilateral well during regular field optimization procedures. Surface and downhole pressures and production metrics for each of the laterals are recorded for one lateral at a time. A multilateral well production model is calibrated using the surface and downhole pressures and the production metrics for each of the laterals. Flowing parameters of individual laterals are estimated using the multilateral well production model. An optimum pressure drop across each downhole valve is determined using the multilateral well production model. A productivity of each lateral is estimated using the model during the commingled production at various choke valves settings.
Systems, methods, and devices for performing real-time detecting and spatially- positioning a waterfront in an oil-producing reservoirs are disclosed. An example method of predicting movement of a waterfront in a reservoir may include generating a plurality of electrical signals having different frequencies with a surface electric source; injecting currents corresponding to the plurality of generated signals into the earth near a well extending into the reservoir with a surface dipole; sensing a vertical component of an electric field generated by each of the injected currents at a location in the reservoir with a sensor; detecting a location of the waterfront within the reservoir based on the received vertical components of the electric fields; and analyzing the detected vertical components of the electric fields taken on at least two different points in time with machine learning to predict a rate of movement of the waterfront within the reservoir.
E21B 47/113 - Localisation des fuites, intrusions ou mouvements du fluide utilisant un rayonnement lumineux
E21B 47/125 - 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 la terre comme conducteur électrique
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 method for stimulating production of hydrocarbons from a sandstone formation includes the steps of injecting a stimulation fluid into the sandstone formation, the stimulation fluid formed from a hydrofluoric acid precursor and an oxidizer; injecting an ammonium containing compound into the sandstone formation; and injecting a nitrite containing compound into the sandstone formation. The method further includes maintaining the stimulation fluid, the ammonium containing compound, and the nitrite containing compound in the sandstone formation to initiate reaction of the ammonium containing compound and the nitrite containing compound to generate heat and nitrogen gas, where upon generation of heat within the formation the hydrofluoric acid precursor and the oxidizer react to form hydrofluoric acid in-situ to dissolve silica and silicate minerals and stimulate the sandstone formation. A treatment fluid for use in stimulating sandstone formations includes the stimulation fluid, the ammonium containing compound, and the nitrite containing compound.
C09K 8/74 - Produits chimiques érosifs, p.ex. acides combinés avec des additifs ajoutés à des fins spécifiques
C09K 8/66 - Compositions à base d'eau ou de solvants polaires
C09K 8/70 - Compositions pour la formation de crevasses ou de fractures caractérisées par leur forme ou par la forme de leurs composants, p.ex. mousses
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
55.
AUTOMATED PRODUCTION OPTIMIZATION TECHNIQUE FOR SMART WELL COMPLETIONS USING REAL-TIME NODAL ANALYSIS
Systems and methods include a method providing automated production optimization for smart well completions using real-time nodal analysis including comingled production calibration. Real-time well rates and flowing bottom-hole pressure data are collected at various choke settings for multiple flow conditions for each lateral of a multilateral well during regular field optimization procedures. Surface and downhole pressures and production metrics for each of the laterals are recorded for one lateral at a time during production of the well. Flowing parameters of individual laterals are estimated using the multilateral well production model. An optimum pressure drop across each downhole valve is determined using the multilateral well production model. Each lateral of the multilateral well is calibrated during the commingled production at various choke valves settings. The calibrating is done using the multilateral well production model, based at least in part on the optimum pressure drop across each downhole valve.
Systems and methods include a method for optimizing smart well completions using real-time nodal analysis including recommending changes to downhole settings. Real-time well rates and flowing bottom-hole pressure data at various choke settings for multiple flow conditions are collected for each lateral of a multilateral well. Recommended optimizing changes to downhole inflow control valve (ICV) settings for surface and subsurface ICVs are determined based on the real-time well rates and the flowing bottom-hole pressure data. The optimizing changes are designed to optimize production in the multilateral well. The recommended optimizing changes to the downhole ICV settings for the surface and subsurface ICVs in the laterals are provided for presentation to a user in a user interface of a multilateral well optimizing system. A user selection of one or more of the recommended optimizing changes is received. The recommended optimizing changes selected by the user are implemented.
A method for stimulating production of hydrocarbons from a sandstone formation includes the steps of injecting a stimulation fluid formed from a hydrofluoric acid generating precursor and an oxidizing agent, an ammonium containing compound, and a nitrite containing compound into the sandstone formation, where one or both of the hydrofluoric acid generating precursor and the oxidizing agent comprise a degradable encapsulation. The method further includes maintaining the stimulation fluid, the ammonium containing compound, and the nitrite containing compound in the sandstone formation to initiate reaction and generate heat and nitrogen gas. Upon generation of heat and degradation of the degradable encapsulation, the hydrofluoric acid generating precursor and the oxidizing agent react to form hydrofluoric acid in-situ to dissolve silica and silicate minerals and stimulate the sandstone formation. A treatment fluid for use in stimulating sandstone formations includes the stimulation fluid, the ammonium containing compound, and the nitrite containing compound.
C09K 8/74 - Produits chimiques érosifs, p.ex. acides combinés avec des additifs ajoutés à des fins spécifiques
C09K 8/66 - Compositions à base d'eau ou de solvants polaires
C09K 8/70 - Compositions pour la formation de crevasses ou de fractures caractérisées par leur forme ou par la forme de leurs composants, p.ex. mousses
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
A system and method for isolating a zone in a wellbore (102)having a sand screen (110) including applying hydrogel (118) into an annulus between the sand screen (110) and the geological formation (106) to form a hydrogel packer (202, 204) in the annulus.
A pressure regulator (107) is configured to manage a pressure downstream of a pump discharge (104F) during operation. A hydraulic piston (109) is exposed to pressure upstream of the pressure regulator (107) during operation. The hydraulic piston (109) extends into a first fluid reservoir (105B). The first fluid reservoir is defined by an inner surface of an outer housing of a subsurface safety valve (103). A subsurface safety valve (103) is fluidically couple to the hydraulic piston housing.
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
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 34/14 - Aménagements des vannes pour les trous de forage ou pour les puits dans les puits actionnés par le mouvement des outils, p.ex. obturateurs à manchons actionnés par des pistons ou par des outils à câble
E21B 43/12 - Procédés ou appareils pour commander l'écoulement du fluide extrait vers ou dans les puits
61.
METHOD FOR IMPROVING CEMENT TOUGHNESS USING A TRIAZINE-BASED POLYMERIC ADDITIVE
This document relates to methods for providing long-term zonal isolation in oil wells using cement compositions that contain triazine-based polymeric additives. The cement compositions containing the polymeric additives exhibit increased tensile strength, elastic strength, or both, without suffering a decrease in compressive strength, as compared to the same cement without the polymeric additive.
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
C04B 24/28 - Composés macromoléculaires obtenus autrement que par des réactions faisant intervenir uniquement des liaisons non saturées carbone-carbone
B28C 5/00 - Appareillages ou procédés pour la production de mélanges de ciment avec d'autres substances, p.ex. coulis, mortiers, compositions poreuses ou fibreuses
E21B 33/13 - Procédés ou dispositifs de cimentation, de bouchage des trous, des fissures ou analogues
62.
TESTING PETRO-PHYSICAL PROPERTIES USING A TRI-AXIAL PRESSURE CENTRIFUGE APPARATUS
A system for testing properties of a sample, the system including a test cell. The test cell includes a cell casing having a first end piece, a second end piece, and at least one wall extending between the first end piece and the second end piece. The cell casing defines a pressure boundary enclosing an interior region of the cell. The test cell further includes a sample chamber, a first reservoir, and a second reservoir disposed within the pressure boundary. The sample chamber defines an interior region. The first reservoir fluidly connects to the interior region of the sample chamber. The second reservoir fluidly connects to the interior region of the sample chamber. The test cell also has a piston assembly having a piston fluid chamber and a piston with a stem extending into the piston fluid chamber. The piston partially defines the sample chamber.
Systems and methods for identifying potential hydrocarbon traps in a subterranean region can include: receiving seismic data of the subterranean region, the seismic data acquired by at least one seismic sensor, the seismic data indicating positions of physical barriers to hydrocarbon flow in the subterranean region and using anisotropic lateral and upward erosion to identify possible locations of hydrocarbons.
A method of altering wettability of a subterranean formation penetrated by a well is described. A first oxidizer including a persulfate is introduced to the subterranean formation. A second oxidizer including a bromate is introduced to the subterranean formation. The well is shut in for a period of time to allow the first oxidizer and the second oxidizer to alter the wettability of the subterranean formation toward non-wetting of oil and of water.
C09K 8/58 - Compositions pour les méthodes de récupération assistée pour l'extraction d'hydrocarbures, c. à d. pour améliorer la mobilité de l'huile, p.ex. fluides de déplacement
65.
FORMING MINERAL IN FRACTURES IN A GEOLOGICAL FORMATION
A system and method for forming mineral or proppant in-situ in fractures in a geological formation via a fracturing fluid. The mineral or proppant is formed from rock in the geological formation.
A system for testing properties of a sample, the system including a test cell. The test cell includes a cell casing having a first end piece, a second end piece, and at least one wall extending between the first end piece and the second end piece. The cell casing defines a pressure boundary enclosing an interior region of the cell. The test cell further includes a sample chamber, a first reservoir, and a second reservoir disposed within the pressure boundary. The sample chamber defines an interior region. The first reservoir fluidly connects to the interior region of the sample chamber. The second reservoir fluidly connects to the interior region of the sample chamber. The test cell also has a piston assembly having a piston fluid chamber and a piston with a stem extending into the piston fluid chamber. The piston partially defines the sample chamber.
A porous micromodel network to simulate formation flows includes a substrate, two or more porous micromodels formed on the substrate and a fluid inlet formed on the substrate. The first porous micromodel defines a first fluidic flow pathway and is representative of a first hydrocarbon-carrying formation. Flow through the first fluidic flow pathway is representative of flow through the first hydrocarbon-carrying formation. The second porous micromodel is fluidically isolated from the first porous micromodel. The second porous micromodel defines a second fluidic flow pathway different from the first fluidic flow pathway. The second porous micromodel is representative of a second hydrocarbon-carrying formation different from the first hydrocarbon-carrying formation. Flow through the second fluidic flow pathway is representative of flow through the second hydrocarbon-carrying formation. The fluid inlet is fluidically configured to simultaneously flow fluid to the first fluidic flow pathway and the second fluidic flow pathway.
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
G01V 99/00 - Matière non prévue dans les autres groupes de la présente sous-classe
The present disclosure relates to methods of suspending proppants in a hydraulic fracturing fluid including adding a quantity of precursor nanoparticles including carbon nanotubes supported by metal oxide catalyst nanoparticles to the hydraulic fracturing fluid. The metal oxide catalyst nanoparticles and the hydraulic fracturing fluid are selected such that the metal oxide catalyst nanoparticles are dissolvable in the hydraulic fracturing fluid. The metal oxide catalyst nanoparticles dissolve in the hydraulic fracturing fluid, resulting in an amount of carbon nanotubes dispersed within the hydraulic fracturing fluid. The carbon nanotube dispersion increases the value of at least one of a Newtonian viscosity, a yield point, a plastic viscosity, and a density of the hydraulic fracturing fluid with the dispersed carbon nanotubes versus a similar or equivalent hydraulic fracturing fluid without the carbon nanotube dispersion. The method may further include adding proppants to the hydraulic fracturing fluid.
The present disclosure relates to methods of making nanocomposite coated proppants with a nanocomposite coating, including adding a quantity of precursor nanoparticles comprising carbon nanotubes supported by metal oxide catalyst nanoparticles to an uncured resin. The metal oxide catalyst nanoparticles and the uncured resin are selected such that the metal oxide catalyst nanoparticles are dissolvable in the uncured resin. The metal oxide catalyst nanoparticles are capable of dissolving in the uncured resin such that an amount of carbon nanotubes are dispersed within the uncured resin to form a nanocomposite coating. The method may further include coating proppant particles with the nanocomposite coating to make nanocomposite coated proppants.
Proppant compositions for hydraulic fracturing that include Portland cement clinker are provided. A cement clinker proppant composition for hydraulic fracturing may include Portland cement clinker and another proppant. Another cement clinker proppant composition for hydraulic fracturing may include resin-coated Portland cement clinker and another proppant. Methods of hydraulic fracturing using the cement clinker proppant compositions and manufacturing the cement clinker proppant compositions are also provided.
A system and method for evaluating kerogen-rich shale (KRS) including measuring, via scanning microscopy, electrical conductivity of a KRS sample and a mechanical property of the KRS sample.
G01Q 60/24 - Microscopie à forces atomiques AFM [Atomic Force Microscopy] ou appareils à cet effet, p.ex. sondes AFM
G01Q 60/00 - Types particuliers de microscopie à sonde à balayage SPM [Scanning-Probe Microscopy] ou appareils à cet effet; Composants essentiels de ceux-ci
G01N 23/2251 - Recherche ou analyse des matériaux par l'utilisation de rayonnement [ondes ou particules], p.ex. rayons X ou neutrons, non couvertes par les groupes , ou en mesurant l'émission secondaire de matériaux en utilisant des microsondes électroniques ou ioniques en utilisant des faisceaux d’électrons incidents, p.ex. la microscopie électronique à balayage [SEM]
G01N 23/20091 - Recherche ou analyse des matériaux par l'utilisation de rayonnement [ondes ou particules], p.ex. rayons X ou neutrons, non couvertes par les groupes , ou en utilisant la réflexion de la radiation par les matériaux en mesurant le spectre de dispersion d’énergie [EDS] du rayonnement diffracté
72.
DUAL INJECTION FOR HYDROCARBON RESERVOIR MANAGEMENT
In a dual injection method for hydrocarbon reservoir management, a production well (102a, 102b) is formed from a surface to a hydrocarbon-bearing zone (104) in the reservoir. A first injection well (106a) and a second injection well (106b) are formed from the surface to a first depth and a second depth, respectively, in a water-bearing zone (108) below the hydrocarbon-bearing zone, the second depth shallower than the first depth. A first injectant of a first type and a second injectant of a second type injected into the water-bearing zone through the first injection well and the second injection well, respectively.The second injectant is injected to sweep hydrocarbons in the hydrocarbon-bearing zone toward the production well. The first injectant is injected to sweep the second injectant toward the hydrocarbon-bearing zone. At least a portion of the hydrocarbons are produced through the production well.
The present disclosure relates methods of suspending at least one weighting agent in a drilling fluid. The embodiments include synthesizing carbon nanotubes via chemical vapor deposition on iron oxide catalyst nanoparticles to form a quantity of nanoparticles. Individual nanoparticles of the iron oxide catalyst nanoparticles include a transition metal disposed on iron oxide. The embodiments further include adding a quantity of nanoparticles to the drilling fluid which results in an amount of carbon nanotubes dispersed within the drilling fluid. The dispersion of the quantity of nanoparticles increases the value of at least one of a Newtonian viscosity, a yield point, a plastic viscosity, and a density of the drilling fluid with the dispersed nanoparticles versus a similar or equivalent drilling fluid without the nanoparticle dispersion. The method may further include adding at least one weighting agent which will become suspended in the drilling fluid.
The present disclosure relates to methods of suspending at least one weighting agent in drilling fluids. The embodiments include adding a quantity of precursor nanoparticles including carbon nanotubes supported by metal oxide catalyst nanoparticles to the drilling fluid. The metal oxide catalyst nanoparticles and the drilling fluid are selected such that the metal oxide catalyst nanoparticles are dissolvable in the drilling fluid. The metal oxide catalyst nanoparticles dissolve in the drilling fluid, resulting in an amount of carbon nanotubes dispersed within the drilling fluid. The carbon nanotube dispersion increases the value of at least one of a Newtonian viscosity, a yield point, a plastic viscosity, and a density of the drilling fluid with the dispersed carbon nanotubes versus a similar or equivalent hydraulic fracturing fluid without the carbon nanotube dispersion. The method may further include adding at least one weighting agent which will become suspended in the drilling fluid.
Methods for producing proppants with block copolymer proppant coating are provided. The methods include coating proppant particles with the block copolymer proppant coating to produce coated proppants with block copolymer proppant coating. The block copolymer proppant coating is a block copolymer composition having at least one copolymer backbone. Each copolymer backbone comprises at least two hard segments and a soft segment disposed between the at least two hard segments. Additionally, a proppant comprising a proppant particle and a block copolymer proppant coating is provided. The block copolymer proppant coating is a block copolymer composition having at least one copolymer backbone, in which each copolymer backbone comprises at least two hard segments. A soft segment is disposed between the at least two hard segments. The copolymer backbone has at least one anhydride group grafted onto the soft segment. Furthermore, the anhydride group is crosslinked by an amine-containing crosslinker.
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
77.
METHOD TO USE A BUOYANT BODY TO MEASURE TWO-PHASE FLOW IN HORIZONTAL WELLS
Provided is a method for the determination of the water cut and volumetric flow rate of a fluid flowing through a density inflow control valve (102). A density inflow control valve (102) may include a floating device (204) that moves between a relaxed choke position and a restricted choke position depending on the density of the fluid flowing through the valve. Pressure gauges upstream and downstream of the inflow control device may be used to measure the pressure drop across the inflow control valve over time. The water cut of the downhole fluid flowing through the valve may be determined from the pressure drop over time and the pressure drop associated with the relaxed choke position and the restricted choke position. The volumetric flow rate may be determined from the average water cut and the density of the downhole fluid, as determined from the single phase densities.
The disclosure generally describes methods, software, and systems for automating parameters used in drilling operations. A computer-implemented method includes the following steps. Real-time information associated with fluid density, drilling operational parameters, and rheology is received from devices installed on site and downhole at a managed pressure drilling (MPD) operation. The real-time information is processed to ensure accuracy of the real-time information, and the real-time information is stored in a database. Real-time measurements of equivalent circulating density (ECD) are determined from the stored real-time information using modeling techniques. Hydraulic calculations are performed to determine annular pressure losses (APL). Surface backpressure (SBP) is determined in real time based on the APL. The MPD operation is automatically updated based on the determined SBP.
E21B 21/08 - Commande ou surveillance de la pression ou de l'écoulement du fluide de forage, p.ex. remplissage automatique des trous de forage, commande automatique de la pression au fond
E21B 44/00 - Systèmes de commande automatique spécialement adaptés aux opérations de forage, c. à d. systèmes à fonctionnement autonome ayant pour rôle d'exécuter ou de modifier une opération de forage sans l'intervention d'un opérateur humain, p.ex. systèmes de ; Systèmes spécialement adaptés à la surveillance de plusieurs variables ou conditions de forage
79.
CONTROLLING FLUID VOLUME VARIATIONS OF A RESERVOIR UNDER PRODUCTION
Techniques for controlling a hydrocarbon production system include determining a first estimate of a prior FVC detectability probability map based on a plurality of reservoir data that includes four-dimensional (4D) seismic data of a subterranean reservoir; determining a second estimate of the prior FVC detectability probability map under seismic data noise conditions; determining an updated detectable FVC probability based on the 4D seismic data; determining an updated FVC probability based on the updated detectable FVC probability and the first and second estimates of the prior FVC detectability probability maps; and generating a control instruction for at least one of a fluid injection system or a hydrocarbon production assembly based on the updated FVC probability.
The subject matter of this specification can be embodied in, among other things, a method for geological modeling includes receiving a forward depositional model, determining a Latin Hypercube Sampling (LHS) stratigraphic model based on the projected forward depositional model, performing forward depositional modeling, transform the forward depositional model from time domain to stratigraphic-depth domain, determining one or more pseudo-wells based on the transformed model, determining a mismatch value based on the transformed forward depositional model and a collection of simulated physical value, and determining a kriging surrogate model based on the LHS stratigraphic model and the mismatch value.
A method (400) including: receiving (402), by a data processing apparatus, a set of seismic data of the hydrocarbon reservoir; setting (404), by the data processing apparatus, an initial velocity model and an initial density model; generating (406), by the data processing apparatus, wavefields of the hydrocarbon reservoir based on the set of seismic data; selecting (408), by the data processing apparatus, a spatial direction; generating (410), by the data processing apparatus, a velocity gradient and a reflectivity gradient of the selected spatial direction based on the wavefields; and updating (412), by the data processing apparatus, the velocity model and the density model using the velocity gradient and the reflectivity gradient of the selected spatial direction.
A system and method to determine effective fracture surface-area per cluster of hydraulic fractures of a hydraulically-fractured well by estimating total effective fracture-area associated with a wellbore and estimating relative distribution of effective fracture surface-area along the wellbore.
Synthesizing Janus material including forming a lamellar phase having water layers and organic layers, incorporating nanosheets and a functional agent into the lamellar phase, and attaching the functional agent to the nanosheets in the lamellar phase to form Janus nanosheets.
C09K 8/58 - Compositions pour les méthodes de récupération assistée pour l'extraction d'hydrocarbures, c. à d. pour améliorer la mobilité de l'huile, p.ex. fluides de déplacement
84.
NONSTATIONARY MAXIMUM LIKELIHOOD METHOD TO ESTIMATE DISPERSION SPECTRA FOR FULL WAVEFORM SONIC LOGGING
The present disclosure describes methods and systems for estimating dispersion spectra for full waveform sonic (FWS) logging. One computer-implemented method includes receiving FWS data, performing frequency-spatial (FX) transform on the FWS data, using a nonstationary predictive error filtering (PEF) inversion on the transformed FWS data to estimate local matrix L and matrix P, calculating an inverse covariance matrix based on the estimated local matrix L and matrix P, and obtaining a nonstationary maximum likelihood method (MLM) spectra based on the inverse covariance matrix.
G01V 1/36 - Exécution de corrections statiques ou dynamiques sur des enregistrements, p.ex. correction de l'étalement; Etablissement d'une corrélation entre signaux sismiques; Elimination des effets produits par un excès d'énergie
G01V 1/28 - Traitement des données sismiques, p.ex. pour analyse, pour interprétation, pour correction
G01V 1/40 - Séismologie; Prospection ou détection sismique ou acoustique spécialement adaptées au carottage
Methods for treating water comprising dissolved solids in a wellbore include injecting water into a wellbore, where the wellbore has a depth that is sufficient for introducing a hydrostatic pressure that imparts supercritical pressure to water present at a water depth greater than or equal to the minimum depth needed to impart water supercritical pressure. A heating element is inserted into the wellbore to a heating element depth that is greater than or equal to the required depth. Power is transmitted to the heating element causing the heating element to heat water to a temperature sufficient to form supercritical water that causes the dissolved solids to precipitate out of the water as precipitated solids. Water and the precipitated solids are separated and extracted. The heating element includes a microwave antenna and a shell encapsulating the microwave antenna formed from a material that is capable of heating upon exposure to microwave radiation.
E21B 21/06 - Dispositions pour traiter les fluides de forage à l'extérieur du trou de forage
C09K 8/58 - Compositions pour les méthodes de récupération assistée pour l'extraction d'hydrocarbures, c. à d. pour améliorer la mobilité de l'huile, p.ex. fluides de déplacement
86.
DOWNHOLE MONITORING USING FEW-MODE OPTICAL FIBER BASED DISTRIBUTED ACOUSTIC SENSING
KING ABDULLAH UNIVERSITY OF SCIENCE AND TECHNOLOGY (Arabie saoudite)
Inventeur(s)
Hveding, Frode
Ashry, Islam
Yuan, Mao
Bin Alias, Mohd Sharizal
Ooi, Boon Siew
Arsalan, Muhammad
Abrégé
The subject matter of this specification can be embodied in, among other things, a method for removing intermodal distortion that includes receiving a collection of distorted backscattered Rayleigh signals from a collection of modes of an optical fiber, where the collection of distorted backscattered Rayleigh signals are distorted by an intermodal coupling among the collection of modes, receiving a collection of distortion parameters that are descriptive of distortion effects of the intermodal coupling, and determining an undistorted backscattered Rayleigh signal based on the collection of distorted backscattered Rayleigh signals and the collection of distortion parameters.
G01H 9/00 - Mesure des vibrations mécaniques ou des ondes ultrasonores, sonores ou infrasonores en utilisant des moyens sensibles aux radiations, p.ex. des moyens optiques
G01V 1/22 - Transmission des signaux sismiques aux appareils d'enregistrement ou de traitement
G01V 1/40 - Séismologie; Prospection ou détection sismique ou acoustique spécialement adaptées au carottage
A method for recovering at least one of oil and gas from a geological formation includes injecting water into a wellbore, where the wellbore has a depth that is sufficient for introducing a hydrostatic pressure that imparts supercritical pressure to water present at a depth greater than or equal to the depth. A heating element is inserted into the wellbore to a heating element depth that is greater than or equal to the depth. Power is transmitted to the heating element causing the heating element to heat water to a temperature sufficient to form supercritical water. The heating element includes a microwave antenna and a shell encapsulating the microwave antenna formed from a material that is capable of heating upon exposure to microwave radiation.
E21B 36/04 - Aménagements pour le chauffage, le refroidissement, l'isolation, dans les trous de forage ou dans les puits, p.ex. pour être utilisés dans les zones de permagel utilisant des réchauffeurs électriques
E21B 43/24 - Procédés de récupération assistée pour l'extraction d'hydrocarbures utilisant la chaleur, p.ex. injection de vapeur
88.
REAL TIME ANALYSIS OF FLUID PROPERTIES FOR DRILLING CONTROL
Techniques are described for controlling drilling operations based on real time measurement and analysis of fluid properties in a drilling environment. Sensor data can be collected that provides measurement(s) of fluid properties (for example, density and rheology) of the drilling fluid (in other words, downhole mud) around the drill. The measurements can be provided to a hydraulic model that calculates downhole pressure loss in the annulus. Based on this calculation, a calculation of equivalent circulating density (ECD) can be performed. In some implementations, the calculations are performed in real time with respect to the collection of the sensor data. The real time pressure loss and ECD calculations can be used to control bottom hole circulating pressures. The results of the calculations may be used to automatically control drilling operations.
E21B 21/08 - Commande ou surveillance de la pression ou de l'écoulement du fluide de forage, p.ex. remplissage automatique des trous de forage, commande automatique de la pression au fond
E21B 44/00 - Systèmes de commande automatique spécialement adaptés aux opérations de forage, c. à d. systèmes à fonctionnement autonome ayant pour rôle d'exécuter ou de modifier une opération de forage sans l'intervention d'un opérateur humain, p.ex. systèmes de ; Systèmes spécialement adaptés à la surveillance de plusieurs variables ou conditions de forage
89.
SEISMIC SURVEYS USING TWO-WAY VIRTUAL SOURCE REDATUMING
In an example implementation, first seismic energy is generated using first seismic sources positioned on an earth's surface. First data including measurements of the first seismic energy is obtained from first geophones positioned at a first depth below the earth's surface. Second data including measurements of the first seismic energy is obtained from second geophones positioned on the earth's surface. Second seismic energy is generated using second seismic sources positioned on an earth's surface and proximal to the second geophones. Third data including measurements of the second seismic energy is obtained from third geophones positioned at the first depth below the earth's surface. A propagation of the first seismic energy along a first path is estimated based on the first, second and third data. One or more characteristics of the target are determined based on the estimate.
G01V 1/28 - Traitement des données sismiques, p.ex. pour analyse, pour interprétation, pour correction
G01V 1/36 - Exécution de corrections statiques ou dynamiques sur des enregistrements, p.ex. correction de l'étalement; Etablissement d'une corrélation entre signaux sismiques; Elimination des effets produits par un excès d'énergie
90.
QUASI-FUNDAMENTAL-MODE OPERATED MULTIMODE FIBER FOR DISTRIBUTED ACOUSTIC SENSING
KING ABDULLAH UNIVERSITY OF SCIENCE AND TECHNOLOGY (Arabie saoudite)
Inventeur(s)
Hveding, Frode
Ashry, Islam
Yuan, Mao
Bin Alias, Mohd Sharizal
Ooi, Boon Siew
Arsalan, Muhammad
Abrégé
Systems and methods include a number of optical pulses are transmitted by transmitting, by a distributed acoustic sensor (DAS), where the optical pulses are transmitted at an input port associated with a multimode fibers (MMF) used by the DAS, and where the fundamental mode of the MMF is excited. A number of backscattered Rayleigh signals are collected by the DAS. The Rayleigh signals are recorded as an output intensity profile. A position along the MMF that is subject to vibrations and corresponding vibration parameters are determined by analyzing the recorded output intensity profile.
G01D 5/353 - Moyens mécaniques pour le transfert de la grandeur de sortie d'un organe sensible; Moyens pour convertir la grandeur de sortie d'un organe sensible en une autre variable, lorsque la forme ou la nature de l'organe sensible n'imposent pas un moyen de conversion déterminé; Transducteurs non spécialement adaptés à une variable particulière utilisant des moyens optiques, c. à d. utilisant de la lumière infrarouge, visible ou ultraviolette avec atténuation ou obturation complète ou partielle des rayons lumineux les rayons lumineux étant détectés par des cellules photo-électriques en modifiant les caractéristiques de transmission d'une fibre optique
G01H 9/00 - Mesure des vibrations mécaniques ou des ondes ultrasonores, sonores ou infrasonores en utilisant des moyens sensibles aux radiations, p.ex. des moyens optiques
G01V 1/22 - Transmission des signaux sismiques aux appareils d'enregistrement ou de traitement
91.
DEVICE AND PROCESS FOR MAINTAINING ZERO CAPILLARY PRESSURE BOUNDARY CONDITION DURING CORE FLOOD EXPERIMENTS
A core sample holder assembly for performing core flood experiments includes a first end cap having a first cylindrical body with a first central chamber and a first inner end that is ring shaped, and a second end cap having a second cylindrical body with a second central chamber and a second inner end that is ring shaped. Three flow lines are spaced elevationally apart, the three flow lines extending from a first outward end to a first inward facing surface of each end cap. A flexible sleeve circumscribes the first end cap and the second end cap. A test sample bore is defined by the first inner end, the second inner end, and an inner diameter surface of the flexible sleeve. A central axis extends through the first end cap, the second end cap, and the flexible sleeve, the first end cap, the second end cap, and the flexible sleeve being axially aligned.
Systems and methods for producing hydrocarbons from a subterranean well include an electrical submersible pump assembly with a motor. The motor has a motor housing and a stator is located within the motor housing. The stator has a stator body with an interior cavity. A rotor assembly is located within the interior cavity of the stator. The rotor assembly includes a rotor shaft, a rotor member, and an intermediate rotor bearing assembly, The rotor member and the intermediate rotor bearing assembly circumscribe the rotor shaft. The rotor shaft extends along the central axis of the stator. A liner is located along an interior surface of the interior cavity, the liner being a thin walled member that is secured to the motor housing and seals the stator body from a wellbore fluid. The liner has a polygonal cross section.
F04B 47/06 - Pompes ou installations de pompage spécialement adaptées pour élever un fluide à partir d'une grande profondeur, p.ex. pompes de puits dont les ensembles pompe-moteur sont placés à grande profondeur
E21B 43/12 - Procédés ou appareils pour commander l'écoulement du fluide extrait vers ou dans les puits
F04B 47/08 - Pompes ou installations de pompage spécialement adaptées pour élever un fluide à partir d'une grande profondeur, p.ex. pompes de puits dont les ensembles pompe-moteur sont placés à grande profondeur les moteurs étant actionnés par un fluide
Innovative aspects of the subject matter described in this specification may be embodied in methods that include obtaining a seismic data image. A first plane-wave destruction filter dip estimation is applied to the seismic data image to generate an initial dip model. A second plane-wave destruction filter dip estimation is applied to the seismic data image using the initial dip model to generate a pattern-guided dip estimation. The pattern-guided dip estimation is stored in a data store.
G01V 1/36 - Exécution de corrections statiques ou dynamiques sur des enregistrements, p.ex. correction de l'étalement; Etablissement d'une corrélation entre signaux sismiques; Elimination des effets produits par un excès d'énergie
Provided herein are compositions and methods for treating wells in geologic formations. The method involves introducing a first aqueous composition containing an organic acid into a well, introducing a second aqueous composition into the well, and forming a third composition useful for stimulating wells, fracturing geologic formations, and cleaning wells of filter cakes and other well blockages.
Techniques for determining a drill bit location includes identifying a plurality of acoustic energy signals received at a plurality of sets of acoustic receivers from a passive acoustic energy source that is part of a wellbore drilling system; processing the plurality of acoustic energy signals; determining a location of a drill bit of the wellbore drilling system based on the processed plurality of acoustic signals; and updating a geo-steering path of the drill bit based on the determined location of the drill bit.
G01V 1/37 - Exécution de corrections statiques ou dynamiques sur des enregistrements, p.ex. correction de l'étalement; Etablissement d'une corrélation entre signaux sismiques; Elimination des effets produits par un excès d'énergie spécialement adaptés aux systèmes sismiques utilisant une agitation continue du sol
G01V 1/42 - Séismologie; Prospection ou détection sismique ou acoustique spécialement adaptées au carottage en utilisant des générateurs dans un puits et des récepteurs dans un autre endroit ou vice versa
The present application provides an aqueous fluid containing a gas-generating compound such as an azo compound, a hydrazide compound, or a semicarbazide compound. The aqueous fluid may also contain an amine compound, an oxidizer, or viscosifier, and a foaming surfactant. The aqueous composition may be storable at pH of less than about 5 without any appreciable gas generation, and may be activated to produce gas when mixed with a wellbore fluid for use in downhole applications.
C09K 8/00 - Compositions pour le forage des puits ou des trous de forage; Compositions pour le traitement des puits ou des trous de forage, p.ex. pour des opérations de complétion ou de réparation
B01J 7/00 - Appareillage pour la production de gaz
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
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
C09K 8/594 - Compositions utilisées en combinaison avec du gaz injecté
C09K 8/68 - Compositions à base d'eau ou de solvants polaires contenant des composés organiques
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 33/13 - Procédés ou dispositifs de cimentation, de bouchage des trous, des fissures ou analogues
E21B 43/16 - Procédés de récupération assistée pour l'extraction d'hydrocarbures
The present application provides a gas-generating aqueous fluid containing a gas-generating compound like an azo compound, and an organic amine like a primary, secondary or tertiary amine, a hydrazine, a hydrazide, or a semicarbazide. The aqueous fluid may also a viscosifier, and a foaming surfactant. The present application also provides a method of using the gas-generating composition to modulate density of a wellbore fluid for use in downhole applications. The method optionally includes adding an oxidizer to the wellbore fluid.
C09K 8/38 - Compositions de forage gazeuses ou en mousse
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
98.
ELECTRONIC SUBMERSIBLE PUMPS FOR OIL AND GAS APPLICATIONS
A method of removing fluid from a well using a downhole pump includes deploying the downhole pump to a vertical position within a production tubing disposed in the well, securing the downhole pump to the production tubing at the vertical position, powering a motor of the downhole pump with an electrical line of the downhole pump that extends from a surface of the well and that terminates at a profile of the downhole pump, and activating the motor to pump fluid out of the well.
A semi-autonomous downhole taxi with fiber optic communication is described. The taxi includes a housing configured to travel within a horizontal section of a wellbore. A docking station is detachably attached to the housing. The docking station is configured to couple to a wireline to pass the taxi through a vertical section of the wellbore. The docking station is configured to be detached from and re-attached to the housing. A fiber optic cable spool is attached to and carried by the housing. A fiber optic cable is wound on the fiber optic cable spool. The fiber optic cable mechanically connects the docking station and the housing. The fiber optic cable is configured to unspool from the fiber optic cable spool as the housing, detached from the docking station, travels through the horizontal section of the wellbore. The fiber optic cable is configured to pas data between the docking station and the housing. The data is associated with wellbore operations to be performed by the taxi in the horizontal section of the wellbore.
E21B 23/00 - Appareils pour déplacer, mettre en place, verrouiller, libérer ou retirer, les outils, les packers ou autres éléments dans les trous de forage
E21B 47/135 - Moyens pour la transmission de signaux de mesure ou signaux de commande du puits vers la surface, ou de la surface vers le puits, p.ex. pour la diagraphie pendant le forage par énergie électromagnétique, p.ex. gammes de fréquence radio utilisant des ondes lumineuses, p.ex. ondes infrarouges ou ultraviolettes
100.
SYSTEMS AND METHODS FOR MONITORING DOWNHOLE CONDITIONS
A bottom hole assembly (28) includes a well logging tool (56) including a plurality of sensors (58), a vibrator tool (34) coupled to the well logging tool for inserting the well logging tool into a wellbore (14), and a spoolable composite tube (12) coupled to the vibrator tool, the spoolable composite tube configured to carry power and data cables from the surface to the plurality of sensors in the well logging tool. The well logging tool may further include one or more cameras (60) installed on a distal end of the tool to provide a live visual means to check a well condition. A method for monitoring a well condition includes inserting a bottom hole assembly into a wellbore, and receiving, in real-time, data pertaining to the monitored well condition on the surface.
E21B 17/20 - Tubes de forage flexibles ou articulés
E21B 47/002 - Relevés dans les trous de forage ou dans les puits par inspection visuelle
E21B 23/14 - Appareils pour déplacer, mettre en place, verrouiller, libérer ou retirer, les outils, les packers ou autres éléments dans les trous de forage pour déplacer un câble ou un outil manoeuvré par câble, p.ex. pour les opérations de diagraphie ou de perforation dans les puits déviés
E21B 28/00 - Dispositions pour la génération de vibrations pour les trous de forage ou les puits, p.ex. pour activer la production
brevets
