Aspects of the technology described herein make legacy hydrocarbon studies accessible to modern computer analysis. Whatever the initial format, the technology described herein analyzes the studies to identify characteristics that are interesting to people who study hydrocarbon environments. As an initial process, various segments within a hydrocarbon study received by the technology described herein are identified. The various segments can include text, maps, charts, and tables. Within each of these segments, specific types of text segments, maps, charts, and tables may be identified. For each segment identified, characteristics of interest may be determined through analysis of the segment. In one aspect, segment-specific analysis is performed on each type of segment. Different technologies may be used for different segments. Once the characteristics are identified, they may be stored in association with both the overall document and with a segment of the document from which the characteristic of interest was extracted.
Offshore systems and methods may be configured for oil production, offshore power generation, ammonia production, and carbon dioxide injection for EOR. For example, a method performed on an offshore facility may include: separating a produced hydrocarbon into a produced gas and a produced oil; combusting the produced gas to produce power and a flue gas; at least partially removing nitrogen from the flue gas to produce a carbon dioxide-enriched flue gas and a nitrogen-enriched flue gas; reforming a portion of the produced gas to produce a stream including hydrogen and carbon dioxide; at least partially separating the carbon dioxide from the stream to yield a carbon dioxide stream and a hydrogen stream; reacting the hydrogen stream and the nitrogen-enriched flue gas to yield ammonia; combining and compressing the carbon dioxide stream and the carbon dioxide-enriched flue gas; and injecting the compressed gas from the gas compressor into the gas reservoir.
C01B 3/02 - Production d'hydrogène ou de mélanges gazeux contenant de l'hydrogène
C01B 3/48 - Production d'hydrogène ou de mélanges gazeux contenant de l'hydrogène par réaction de composés organiques gazeux ou liquides avec des agents gazéifiants, p.ex. de l'eau, du gaz carbonique, de l'air par réaction d'hydrocarbures avec des agents gazéifiants suivie par une réaction de la vapeur d'eau avec l'oxyde de carbone
C09K 8/594 - Compositions utilisées en combinaison avec du gaz injecté
B01J 19/24 - Réacteurs fixes sans élément interne mobile
E21B 43/16 - Procédés de récupération assistée pour l'extraction d'hydrocarbures
F02C 6/00 - Ensembles fonctionnels multiples de turbines à gaz; Combinaisons d'ensembles fonctionnels de turbines à gaz avec d'autres appareils; Adaptations d'ensembles fonctionnels de turbines à gaz à des applications particulières
A methodology for spatially identifying conductive regions using pressure transience for characterizing conductive fractures and subsurface regions is provided. Hydraulic fracturing is utilized to create fractures within a reservoir, thereby increasing fluid permeability of the reservoir and permitting hydrocarbon fluids to flow into a wellbore and subsequently to be produced from the hydrocarbon reservoirs. The geometry, dimensions, and extent of the fractures may significantly impact the production characteristics of the well. However, given that fractures are thousands of feet below the surface, measuring the properties of the fractures can be difficult. In order to characterize the fractures, including determining locations of conductive fractures in the subsurface, sensors are positioned in monitoring wells. Pressure changes are then induced in a well, with the sensors measuring the effect of the pressure changes. In turn, the sensed data may be used in order to characterize the fractures in the subsurface.
A method of attenuating annular pressure buildup within a wellbore. The method includes running first and second strings of casing into a wellbore, wherein the first string of casing surrounds an upper portion of the second string of casing forming an annular region. The method also includes providing a packing of compressible material within the annular region. The compressible material comprises carbonaceous particles. The particles may reside within a porous sleeve or filter, or they may be packed together in a matrix using a cross-linked polymer or binder. The packing is fixed at a selected depth within the annular region, and is designed so that the compressible material absorbs pressure in response to thermal expansion of wellbore fluids during the production of hydrocarbon fluids from the wellbore. The method further includes placing a wellhead over the wellbore, thereby forming a trapped annulus in the wellbore over the annular region.
E21B 33/14 - Procédés ou dispositifs de cimentation, de bouchage des trous, des fissures ou analogues pour la cimentation des tubes dans les trous de forage ou de sondage
Methods of facilitating human interpretation of a plurality of time-series datasets generated from operation of hydrocarbon wells. The methods include obtaining the plurality of time-series datasets and displaying a vector map. The plurality of time-series datasets is generated from an operation of the hydrocarbon well and includes a first time-series dataset and a second time-series dataset, and optionally may include a third time-series dataset. The vector map includes a time axis and a plurality of points distributed along the time axis at a plurality of corresponding times. A color of each point of the plurality of points is defined in a plural-component color space and includes a first color component at a first intensity and a second color component at a second color component at a second intensity, and optionally a third color component at a third intensity when the plurality of time-series datasets includes a third time-series dataset.
Aspects of the technology described herein identify geologic features within seismic data using modern computer analysis. An initial step is the development of training data for the machine classifier. The training data comprises an image of seismic data paired with a label identifying points of interest that the classifier should identify within raw data. Once the training data is generated, a classifier can be trained to identify areas of interest in unlabeled seismic images. The classifier can take the form of a deep neural network, such as a U-net. Aspects of the technology described herein utilize a deep neural network architecture that is optimized to detect broad and flat features in seismic images that may go undetected by typical neural networks in use. The architecture can include a group of layers that perform aspect ratio compression and simultaneous comparison of images across multiple aspect ratio scales.
A computer-implemented geological modeling method is disclosed. Hydraulic fracturing includes pumping fluids through a wellbore/casing and into a formation through perforations, creating fractures that can improve well productivity. Geological modeling may be used to model pumping of fluids into the subsurface to achieve a desired fracturing result. However, the grid used may affect the fracture propagation calculations used for geological modeling. Thus, a methodology is disclosed which reduces the grid dependence when determining various aspects of fracturing, such as pressure and/or aperture. The methodology uses a first correction factor that is based on the grid used to determine fracture propagation and a second correction factor that is not based on the grid used to determine fracture propagation (such as based on an ideal grid). In this way, the two correction factors are derived from different aspects, which when combined, may be used to reduce grid dependence when determining fracture propagation.
A method for classifying a microseismic event, including: analyzing microseismic event files through a combination of two fault tolerant machine learning pipelines, an acoustic machine learning pipeline and a visual machine learning pipeline; and generating a classification prediction for the microseismic event files by combining predictions from the acoustic machine learning pipeline and the visual machine learning pipeline.
Gravel packing particles like sand are commonly used in sand control operations to form gravel packs for controlling the migration of formation particulates into a wellbore and wellbore production equipment. Gravel packing fluids and methods of sand control operations may also use petroleum coke gravel packing particles composed of fluid coke and/or flexicoke material. Such petroleum coke gravel packing particles may have improved transport into wellbores because of their lower density compared to traditional gravel packing material and may produce fewer fines that can plug gravel packs.
A computer-implemented method for analyzing geophysical data is disclosed. Interpretation of geophysical data, such as seismic data, can be performed in multiple stages, such as at an information extraction stage and an information analysis stage. Typically, the information analysis stage is performed by geologists or interpreters, which may be laborious and inconsistent. The disclosed method includes using an information extractor that extracts information indicative of geo-features in a subsurface and an inference engine that analyzes the information indicative of geo-features in a subsurface to generate an output, with the information extractor and the inference engine being integrated and acting in combination. For example, the information extractor may generate summaries of the geo-features or answers to questions. In this way, the information extractor and the inference engine in combination may act synergistically, such as in the context of reasoning, natural language processing, and the outputs generated.
Proppant particulates like sand are commonly used in hydraulic fracturing operations to maintain one or more fractures in an opened state following the release of hydraulic pressure. Fracturing fluids and methods of hydraulic fracturing may also use proppant particulates composed of high-flow polyolefin coated mineral particles (referred to as high-flow polyolefin coated mineral proppant particulates). In some instances, the high-flow polyolefin-coated mineral proppant particulates have a particle density of equal to or less than about 1.35 grams per cubic centimeter, and further may be prepared using a one-pot hot melt process.
A method and apparatus for performing geological reasoning, A method includes: obtaining subsurface data for a subsurface region; obtaining a knowledge model; extracting a structured representation from the subsurface data using the knowledge model; and performing geological reasoning with a graph network based on the knowledge model and the structured representation. A method includes performing geological reasoning with a knowledge model that includes a set of geoscience rules or a geoscience ontology. A method includes performing geological reasoning with a structured representation that includes a graph. A method includes performing geological reasoning by one or more of the following: question answering; decision making; assigning ranking; and assessing probability.
G01V 99/00 - Matière non prévue dans les autres groupes de la présente sous-classe
G06F 30/27 - Optimisation, vérification ou simulation de l’objet conçu utilisant l’apprentissage automatique, p.ex. l’intelligence artificielle, les réseaux neuronaux, les machines à support de vecteur [MSV] ou l’apprentissage d’un modèle
13.
STRUCTURED REPRESENTATIONS OF SUBSURFACE FEATURES FOR HYDROCARBON SYSTEM AND GEOLOGICAL REASONING
A method and apparatus for utilizing a structured representation of a subsurface region. A method includes obtaining subsurface data for the subsurface region; and extracting the structured representation from the seismic data by: identifying geologic and fluid objects in the seismic images, wherein each object corresponds to a node of the structured representation; and identifying relationships among the identified geologic and fluid objects, wherein each relationship corresponds to an edge of the structured representation. A method further includes determining object attributes, edge attributes, and/or global attributes from the subsurface data. A method further includes inferring information from the structured representation.
Methods include providing a natural gas stream; directing a first fraction of the natural gas stream to a bioreactor including a propagating culture of hydrocarbon degrading microbes; directing a second fraction of the gas stream to a local power generator and converting the natural gas stream to electricity and heat; using a dynamic control system to balance of the gas stream to the first fraction and the second fraction based on one or more of the availability of electricity from an electricity grid and the price of electricity from the electricity grid; powering, at least in part, the bioreactor with the electricity generated by the local power generator; and harvesting the hydrocarbon degrading microbes from the bioreactor as a biomass. Related systems are also provided.
Methods and systems for measuring cluster efficiency for stages of wellbores are provided herein. One method includes selecting a frequency band for generating broadband tube waves within the fluid column of the wellbore and generating the broadband tube waves within the fluid column of the wellbore using a pressure pulse generator that is hydraulically coupled to the wellbore. The method also includes recording data corresponding to the broadband tube waves and reflected broadband tube waves using pressure receivers that are hydraulically coupled to the wellbore. The pressure receivers are arranged into arrays with two or more pressure receivers in each array. The data recorded by the pressure receivers relate to characteristics of reflectors (including perforation cluster/fracture interfaces) within the wellbore. The method further includes processing the recorded data using interferometry and performing full waveform inversion(s) on the processed data to determine frequency-dependent, complex-valued reflection coefficients at each perforation cluster/fracture interface.
E21B 49/00 - Test pour déterminer la nature des parois des trous de forage; Essais de couches; Procédés ou appareils pour prélever des échantillons du terrain ou de fluides en provenance des puits, spécialement adaptés au forage du sol ou aux puits
E21B 47/26 - Stockage des données en fond de puits, p.ex. dans une mémoire ou sur un support d'enregistrement
G01V 1/137 - Production d'énergie sismique en utilisant des fluides comme moyens d'entraînement hydrauliques, p.ex. en utilisant des fluides à haute pression dont les fluides s'échappent du générateur d'une manière pulsée, p.ex. pour produire des explosions
16.
RESIN-COATED PETROLEUM COKE AS PROPPANT PARTICULATE MATERIAL AND METHODS RELATED THERETO
Proppant particulates like sand are commonly used in hydraulic fracturing operations to maintain one or more fractures in an opened state following the release of hydraulic pressure. Fracturing fluids and methods of hydraulic fracturing may also use proppant particulates composed of resin-coated petroleum coke (referred to as resin-coated petroleum coke proppant particulates). In some instances, the resin-coated petroleum coke proppant particulates have a particle density of equal to or less than about 1.7 grams per cubic centimeter and better resistance to creating fines when exposed to uniaxial stress.
Methods for completing hydrocarbon wells using variable rate fracturing are provided herein. One method includes positioning a perforation device within a tubular conduit of a downhole tubular, where the downhole tubular extends within a wellbore, and where the wellbore extends within a subsurface region, as well as perforating the downhole tubular using the perforation device to define perforations within the downhole tubular. The method also includes pumping a slurry including fracturing fluid and a lightweight proppant into the tubular conduit according to a variable pumping rate schedule to fracture zones of the subsurface region that are proximate to the perforations, forming corresponding fractures within the subsurface region. The method further includes flowing the slurry into the fractures, via the perforations, to prop the fractures with the lightweight proppant, where the lightweight proppant includes granules formed from a polyolefin, petroleum coke, and/or a polyaromatic hydrocarbon resin.
E21B 43/119 - Perforateurs; Perméators - Parties constitutives, p.ex. pour localiser l'emplacement ou la direction de la perforation
C09K 8/80 - Compositions pour renforcer les fractures, p.ex. compositions pour agents de soutènement utilisés pour maintenir les fractures ouvertes
18.
METHOD FOR DETERMINING AND IMPLEMENTING A DATA COLLECTION PROGRAM FOR ONE OR MORE PHASES OF HYDROCARBON EXTRACTION BASED ON SEQUENTIAL SUBSURFACE UNCERTAINTY CHARACTERIZATION
A method for determining and implementing a data collection program is disclosed. Data is typically collected in order to develop a subsurface model that can characterize a subsurface to assist in hydrocarbon management. However, it may be difficult to determine how much, or what type of data, to obtain so that the subsurface model is of sufficient certainty. In particular, parameters that define the model and outputs of the model (defined as quantities of interest (QoIs)) are subject to uncertainty. In order to reduce the uncertainty of the QoIs to an acceptable level, data collection programs are iteratively selected based on sequential subsurface uncertainty characterization. In this way, the data collection programs, when implemented, may collect a sufficient amount of data to reduce uncertainty of the subsurface model for subsequent use in hydrocarbon management.
G01V 99/00 - Matière non prévue dans les autres groupes de la présente sous-classe
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 47/00 - Relevés dans les trous de forage ou dans les puits
19.
Device and Method for Weld Root Hardening Determination Compensated for Variations in Distance Between Sensor and Sample
A device and method for weld root hardening determination compensated for variations in distance between sensor and sample are disclosed. A sensor is used to determine hardness of a weld for weld fabrication quality control. Because of irregular weld protrusion geometry, there may be variations in the tip of the sensor and the surface, resulting in inconsistent measurements. To compensate, one or both of a positional compensation or a software compensation are performed. Positional compensation mechanically moves the tip of the sensor to within a predetermined range of the surface. Software compensation may at least partly compensate for the variation by using one part of the generated sensor data (such as the 1st harmonic signal) in order to modify another part of the generated sensor data (such as the 3rd harmonic signal). In this way, the sensor determination of hardness of the weld may be less dependent on the variations.
G01N 27/80 - Recherche ou analyse des matériaux par l'emploi de moyens électriques, électrochimiques ou magnétiques en recherchant des variables magnétiques pour rechercher la dureté mécanique, p.ex. en recherchant la saturation ou la rémanence d'un matériau ferromagnétique
A hierarchical conditioning methodology for building and conditioning a geological model is disclosed. In particular, the hierarchical conditioning may include separate levels of conditioning of template instances using larger-scale data (such as conditioning using large-scale data and conditioning using medium-scale data) and using smaller-scale data (such as fine-scale data). Further, one or more templates, to be instantiated to generate the geological bodies in the model, may be selected from currently available templates and/or machine-learned templates. For example, the templates may be generated using unsupervised or supervised learning to re-parameterize the functional form parameters, or may be generated using statistical generative modeling.
G06F 30/13 - Conception architecturale, p.ex. conception architecturale assistée par ordinateur [CAAO] relative à la conception de bâtiments, de ponts, de paysages, d’usines ou de routes
21.
METHODS OF CHARACTERIZING ACOUSTIC OUTPUT FROM HYDROCARBON WELLS
Methods of characterizing acoustic output from a hydrocarbon well and hydrocarbon wells that include controllers that perform the methods are disclosed herein. The methods include receiving the acoustic output, determining a plurality of acoustic fingerprints, and electronically clustering the plurality of acoustic fingerprints. The acoustic output includes information regarding a plurality of sound events, and each sound event of the plurality of sound events includes at least one corresponding sound detected at the hydrocarbon well. The plurality of acoustic fingerprints includes a corresponding acoustic fingerprint for each sound event of the plurality of sound events. The electronically clustering includes utilizing a clustering algorithm to generate a plurality of acoustic event clusters. Each acoustic event cluster of the plurality of acoustic event clusters includes a corresponding fingerprint subset of the plurality of acoustic fingerprints, and each acoustic fingerprint in the corresponding fingerprint subset includes at least one similar acoustic property.
G01V 1/40 - Séismologie; Prospection ou détection sismique ou acoustique spécialement adaptées au carottage
E21B 47/095 - Localisation ou détermination de la position d'objets dans les trous de forage ou dans les puits; Identification des parties libres ou bloquées des tubes par détection d'anomalies acoustiques, p.ex. à l'aide de pulsations de pression de boue
22.
METHOD AND SYSTEM FOR AUGMENTED INVERSION AND UNCERTAINTY QUANTIFICATION FOR CHARACTERIZING GEOPHYSICAL BODIES
A computer-implemented method for augmented inversion and uncertainty quantification for characterizing geophysical bodies is disclosed. The method includes machine-learning-augmented inversion that also facilitates the characterization of uncertainties in geophysical bodies. The method may further estimate wavelets without a well-log calibration, thereby enabling a pre-discovery exploration phase when well log data is unavailable. The machine learning component incorporates a priori knowledge about the subsurface and physics, such as distributions of expected rock types and rock properties, geological structures, and wavelets, through learning from examples. The methodology also allows for conditioning the characterization with the information extracted a priori about the geobodies, such as probabilities of rock types, using other analysis tools. Thus, the conditioning strategy may make the inversion more robust even when a priori distributions are not well balanced. Using the method, a scenario testing workflow may evaluate different candidate subsurface models, facilitating the management of uncertainty in decision-making processes.
An intrinsically-safe sensor system, as well as a method for assembling the intrinsically-safe sensor system and a method for monitoring sound corresponding to a source using the intrinsically-safe sensor system, are provided herein. The intrinsically-safe sensor system includes a number of sensors, including a microphone, as well as a processor for processing sensor data obtained from the sensors. The intrinsically-safe sensor system also includes a memory component for storing the sensor data obtained from the sensors, a power source, a communication connection for communicably coupling the intrinsically-safe sensor system to a remote computing system, and a connector including internal and external connection regions for internally and/or externally connecting one or more additional devices to the intrinsically-safe sensor system on demand. The intrinsically-safe sensor system further includes an enclosure, as well as potting material for encapsulating an internal region of the intrinsically-safe sensor system that resides within the enclosure.
G01M 3/28 - Examen de l'étanchéité des structures ou ouvrages vis-à-vis d'un fluide par utilisation d'un fluide ou en faisant le vide par mesure du taux de perte ou de gain d'un fluide, p.ex. avec des dispositifs réagissant à la pression, avec des indicateurs de débit pour soupapes
G01M 3/24 - Examen de l'étanchéité des structures ou ouvrages vis-à-vis d'un fluide par utilisation d'un fluide ou en faisant le vide par détection de la présence du fluide à l'emplacement de la fuite en utilisant des vibrations infrasonores, sonores ou ultrasonores
24.
Cable Guides for Supporting a Fiber Optic Cable with a Sensing Region Relative to a Tube, Hydrocarbon Conveyance Systems Including the Cable Guides, and Methods of Acoustically Probing an Elongate Region with a Hydrocarbon Conveyance System
Cable guides that support a fiber optic cable relative to a tube, hydrocarbon conveyance systems including the cable guides, and methods of acoustically probing an elongate region. The cable guides include a cable retention structure with a first retention region configured to align a first diffraction grating along a first sensing axis and a second retention region configured to align a second diffraction grating along a second sensing axis that is nonparallel to the first sensing axis. The tube defines a tubular conduit configured to convey a hydrocarbon. The hydrocarbon conveyance systems include a tube, a distributed acoustic sensor, and a cable guide. The methods include transmitting an initiated optical signal and receiving a reflected optical signal that includes reflected portions that are reflected by a first diffraction grating and a second diffraction grating. The methods further include analyzing the reflected optical signal to detect an applied mechanical strain.
A modular floating platform system includes a detachable floating buoy providing a body tethered to a seafloor with a plurality of mooring lines and coupled to a subsea production system via one or more communication lines, and a plurality of floating surface facilities, each floating surface facility providing a standardized bottom interface matable with the detachable floating buoy. A latching mechanism individually couples each floating surface facility to the detachable floating buoy when each floating surface facility is individually mated to the detachable floating buoy. One or more communication couplings place each floating surface facility in communication with the subsea production system via the one or more communication lines when each floating surface facility is individually mated to the detachable floating buoy.
B63B 22/02 - Coffres d'amarrage ou bouées spécialement adaptés pour l'amarrage d'un navire
B63B 21/50 - Dispositifs d'ancrage pour navires spéciaux, p.ex. pour plates-formes flottantes de forage ou dragues
E21B 43/01 - 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 spécialement adaptés à l'extraction à partir d'installations sous l'eau
26.
Methods of Increasing Efficiency of Plunger Lift Operations
Methods of increasing efficiency of plunger lift operations and hydrocarbon wells that perform the methods are disclosed herein. The methods include monitoring an acoustic output from the hydrocarbon well. The methods also include calculating a plunger speed of a plunger of the hydrocarbon well as the plunger travels toward a surface region and calculating a discharge duration of a liquid discharge time period during which liquid is discharged from the hydrocarbon well. The methods further include correlating the plunger speed and the discharge duration to a discharge volume of liquid discharged from the hydrocarbon well
Solvent mixtures for downhole elemental sulfur removal and formation stimulation, and methods for utilizing such solvent mixtures, are described herein. One method includes providing a solvent mixture that includes an elemental sulfur solvent fraction and an odorant fraction that includes a lactate ester solvent. The method also includes injecting the solvent mixture into a hydrocarbon well such that the elemental sulfur solvent fraction of the solvent mixture dissolves elemental sulfur deposited on well components, and contacting the solvent mixture with water such that the lactate ester solvent within the odorant fraction reacts with the water to generate lactic acid. The method further includes stimulating a formation through which the hydrocarbon well extends by flowing the solvent mixture including the lactic acid through the hydrocarbon well and into the formation.
Superterranean acoustic networks, methods of forming superterranean acoustic networks, and methods of operating superterranean acoustic networks are disclosed herein. The superterranean acoustic networks include superterranean hydrocarbon infrastructure that extends above a ground surface, defines a waveguide, and contains a fluid. The infrastructure also includes a plurality of acoustic communication nodes spaced-apart along the superterranean hydrocarbon infrastructure. Each acoustic communication node of the plurality of acoustic communication nodes includes an acoustic transmitter and an acoustic receiver. The acoustic transmitter is configured to generate a generated acoustic signal and to supply the generated acoustic signal to the waveguide. Responsive to receipt of the generated acoustic signal, the waveguide is configured to propagate a propagated acoustic signal there through. The acoustic receiver is configured to receive another propagated acoustic signal, which is generated by another acoustic communication node of the plurality of acoustic communication nodes, from the waveguide as a received acoustic signal.
A method of conveying a production fluid from an offshore subsea well to an offshore vessel includes deploying an inflatable bladder from the offshore vessel, the inflatable bladder including a bladder valve, and fluidly connecting the inflatable bladder to an offloading port positioned at a seafloor, wherein the offloading port includes a port valve and is in fluid communication with one or more subterranean hydrocarbon-bearing formations. The method further includes opening the bladder and port valves to discharge the production fluid from the offloading port into the inflatable bladder, and thereby resulting in a substantially filled bladder, closing the bladder and port valves, and fluidly disconnecting the substantially filled bladder from the offloading port.
E21B 43/01 - 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 spécialement adaptés à l'extraction à partir d'installations sous l'eau
30.
Method And System For Generating A Surprisingness Score For Sentences Within Geoscience Text
The invention is a data processing method and system for suggesting insightful and surprising sentences to geoscientists from unstructured text. The data processing system makes the necessary calculations to assign a surprisingness score to detect sentences containing several signals which when combined exponentially, have tendencies to give rise to surprise. In particularly, the data processing system operates on any digital unstructured text derived from academic literature, company reports, web pages and other sources. Detected sentences can be used to stimulate ideation and learning events for geoscientists in industries such as oil and gas, economic mining, space exploration and Geo-health.
A capacitive cable, as well as a method for operating a downhole electro-hydraulic (EH) tool using the capacitive cable, are described herein. The capacitive cable includes at least one standard conductor and at least one capacitive conductor including integrated wire-shaped capacitors. The method includes inserting a tool string including the capacitive cable and an attached downhole EH tool into a wellbore and conducting power from the surface to the downhole EH tool via the standard conductor(s) of the capacitive cable. The method also includes storing electrical energy downhole within the capacitive conductor(s) of the capacitive cable, and activating the downhole EH tool to provide for the rapid release of the electrical energy from the capacitive conductor(s) into the downhole EH tool, initiating an electro-hydraulic event within the wellbore.
A waveform energy generation system, the system including at least one joint of production casing, and one or more energy generators residing along the joint of production casing. The energy generators are configured to be in substantial mechanical contact with a subsurface formation within a wellbore. The energy generators may include either explosive devices or a piezo-electric material. The system also includes a signal transmission system. The signal transmission system is used to send control signals from the surface down to the energy generators for activation at the formation's resonant frequency. Methods of enhancing the permeability of a rock matrix within a subsurface formation using the wellbore as an energy generator are also provided.
An electric submersible pump (ESP) monitoring system is described herein. The ESP monitoring system includes a base monitoring unit and a discharge monitoring unit that are communicably coupled via a ground path. The discharge monitoring unit is hydraulically coupled to the pump discharge and is configured to measure a discharge parameter relating to the pump discharge and transmit data corresponding to the discharge parameter to the base monitoring unit via the ground path. The base monitoring unit is electrically connected to the motor of the ESP system and is configured to measure a base parameter relating to the motor and/or the pump intake, receive the transmitted data corresponding to the discharge parameter from the discharge monitoring unit, combine the data corresponding to the discharge parameter and the data corresponding to the base parameter, and transmit the combined data to an ESP surface unit via an ESP power cable.
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 43/12 - Procédés ou appareils pour commander l'écoulement du fluide extrait vers ou dans les puits
F04B 17/03 - Pompes caractérisées par leur combinaison avec des machines motrices ou moteurs particuliers qui les entraînent ou par leur adaptation à ceux-ci entraînées par des moteurs électriques
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
34.
Apparatus and Method for Non-Intrusive Pressure Measurement and Early Identification of Solids Formation using Selected Guided Ultrasonic Wave Modes
A method of measuring a pressure of a fluid adjacent a wall of a pipe or vessel. A transducer is attached to the wall of the pipe or vessel. A signal is transmitted by the transducer at a characteristic frequency via a plurality of guided wave modes. The characteristic frequency is a frequency at which the guided wave modes are separated in time from each other when received. The signal is received after the plurality of guided wave modes travel in or through the wall a predetermined number of times. The signal has a signal receipt time after the predetermined number of times. The pressure of the fluid is calculated using the signal receipt time.
G01L 9/00 - Mesure de la pression permanente, ou quasi permanente d’un fluide ou d’un matériau solide fluent par des éléments électriques ou magnétiques sensibles à la pression; Transmission ou indication par des moyens électriques ou magnétiques du déplacement des éléments mécaniques sensibles à la pression, utilisés pour mesurer la pression permanente ou quasi permanente d’un fluide ou d’un matériau solide fluent
35.
Method and system of producing hydrocarbons using data-driven inferred production
A method of predicting hydrocarbon production from one or more artificial lift wells is disclosed. Test data is obtained from the artificial lift well. A decline curve model, representing well performance, is generated for one or more fluids in the artificial lift well. Measurement values are obtained from an artificial lift operation. For each of the obtained measurement values, a measurement model is generated that correlates the measurement values to the decline curve. A Kalman filter is used to predict production outputs of at least one of oil, gas, and water for the well, and to generate an uncertainty range for the predicted production outputs. The Kalman filter uses the decline curves to predict the production outputs, and uses the measurement models to correct and/or update the predicted production outputs. Hydrocarbon production activities are modified using the corrected and/or updated predicted production outputs.
The present techniques are directed to a multiphase separation system. The system includes a liquid-liquid separator configured to receive a separated liquid that is further separated into a separated oil and a separated water within the liquid-liquid separator. An oil pump and a water pump, both with adjustable speeds, are configured to pump the separated oil and the separated water, respectively, from the liquid-liquid separator. An interface level in the liquid-liquid separator is regulated by adjusting the speed of the oil pump and the speed of the water pump.
B01D 17/12 - Dispositifs auxiliaires spécialement adaptés pour être utilisés avec les appareils pour séparer des liquides, p.ex. circuits de commande
C02F 1/00 - Traitement de l'eau, des eaux résiduaires ou des eaux d'égout
C02F 1/40 - Dispositifs pour séparer ou enlever les substances grasses ou huileuses, ou les matières flottantes similaires
37.
METHODS OF MONITORING A GEOMETRIC PROPERTY OF A HYDRAULIC FRACTURE WITHIN A SUBSURFACE REGION, WELLS THAT PERFORM THE METHODS, AND STORAGE MEDIA THAT DIRECT COMPUTING DEVICES TO PERFORM THE METHODS
Methods of monitoring a geometric property of a hydraulic fracture within a subsurface region, wells that perform the methods, and storage media that direct computing devices to perform the methods provided. The methods include repeatedly measuring, at a plurality of measurement times, fiber strain as a function of position along a length of an optical fiber. The optical fiber is positioned within a wellbore that extends within a subsurface region and the repeatedly measuring is performed during a change in the geometric property of the hydraulic fracture. For a given measurement time of the plurality of measurement times, the methods also include differentiating the fiber strain as the function of position to generate a strain differential as a function of position along the length of the optical fiber. The methods further include determining the geometric property of the hydraulic fracture based, at least in part, on the strain differential.
E21B 47/002 - Relevés dans les trous de forage ou dans les puits par inspection visuelle
E21B 47/135 - Moyens pour la transmission de signaux de mesure ou signaux de commande du puits vers la surface, ou de la surface vers le puits, p.ex. pour la diagraphie pendant le forage par énergie électromagnétique, p.ex. gammes de fréquence radio utilisant des ondes lumineuses, p.ex. ondes infrarouges ou ultraviolettes
E21B 47/007 - Mesure des contraintes dans le cuvelage ou la tige de forage
Methods of stimulating a hydrocarbon well are disclosed herein. The hydrocarbon well includes a wellbore that extends within a subterranean formation and a tubular that extends within the wellbore and defines a tubular conduit. The methods include retaining a sealing structure within the tubular conduit and, during the retaining, stimulating a zone of the subterranean formation. Subsequent to the stimulating, the methods include fluidly isolating the zone of the subterranean formation from the uphole region by at least partially sealing the plurality of perforations. Subsequent to the fluidly isolating, the methods include moving the sealing structure in a downhole direction within the tubular conduit. The methods also include repeating the retaining, the stimulating, the fluidly isolating, and the moving a plurality of times to stimulate a plurality of corresponding zones of the subterranean formation.
A method for learning and applying a similarity measure between geophysical objects is provided. Similarity measures may be used for a variety of geophysics applications, including inverse problems. For example, an inverse problem may seek to minimize or maximize an associated objective function, which summarizes the degree of similarity between observed data and simulated data. However, when comparing between two or more geophysical objects in the context of the inverse problem, it is difficult to determine whether the observed difference between the two or more geophysical objects is due to noise or intrinsic dissimilarity between the objects. In this regard, an application-specific similarity measure, which may be tailored to the specific application, such as the specific inverse problem, may be generated and applied in order to better solve the inverse problem.
G06N 5/04 - Modèles d’inférence ou de raisonnement
40.
Chelating acid blends for stimulation of a subterranean formation, methods of utilizing the chelating acid blends, and hydrocarbon wells that include the chelating acid blends
Chelating acid blends for stimulation of a subterranean formation, methods of utilizing the chelating acid blends, and hydrocarbon wells that include the chelating acid blends are disclosed herein. The chelating acid blends include an acid mixture and a chelating agent or set of chelating agents. The acid mixture includes hydrochloric acid and hydrofluoric acid. The methods include providing the chelating acid blends to a wellbore of a hydrocarbon well, flowing the chelating acid blends into a subterranean formation, dissolving a fraction of a formation mineralogy of the subterranean formation with the acid mixture, and chelating poly-valent metal ions with the chelating agent. The hydrocarbon wells include a wellbore that extends within a subterranean formation, a downhole tubular that extends within the wellbore, a fracture that extends into the subterranean formation, and a chelating acid blend positioned within the fracture.
A lock mandrel is described herein. The lock mandrel includes an upper connector and a lower connector. The upper connector includes locking keys configured to attach the lock mandrel to a landing nipple on a tubing within a hydrocarbon well. The upper connector also includes a spring-loaded locking collar configured to prevent the locking keys from disengaging from the landing nipple by pressing radially against the locking keys from the inside when in a seated position, and allow the locking keys to disengage from the landing nipple by retracting away from the locking keys when in an unseated position. The lower connector includes a tool adaptor configured to attach a downhole tool to the lock mandrel.
E21B 23/03 - Appareils pour déplacer, mettre en place, verrouiller, libérer ou retirer, les outils, les packers ou autres éléments dans les trous de forage pour mettre en place des outils sur les supports ou dans les retraits ou poches excentrées ou pour les en retirer
E21B 4/06 - Moyens de percussion mis en œuvre au fond du trou, p.ex. marteaux
E21B 23/01 - Appareils pour déplacer, mettre en place, verrouiller, libérer ou retirer, les outils, les packers ou autres éléments dans les trous de forage pour ancrer les outils ou similaires
E21B 23/02 - Appareils pour déplacer, mettre en place, verrouiller, libérer ou retirer, les outils, les packers ou autres éléments dans les trous de forage pour verrouiller les outils ou autres éléments sur des supports ou dans des retraits entre sections adjacentes du tubage
E21B 43/12 - Procédés ou appareils pour commander l'écoulement du fluide extrait vers ou dans les puits
42.
Self-destructible frac ball enclosed within a destructible ball retainer
A self-destructible frac ball is described herein. The self-destructible frac ball is configured to seal a hydraulic flow path through a fluid conduit of a frac plug when engaged on a ball seat of the frac plug. The self-destructible frac ball includes an activation mechanism configured to activate a destructive medium in response to the satisfaction of at least one predetermined condition. The self-destructible frac ball also includes the destructive medium, which is configured to destroy the self-destructible frac ball and a corresponding destructible ball retainer when activated by the activation mechanism. The destruction of the self-destructible frac ball and the corresponding destructible ball retainer reestablishes the hydraulic flow path through the fluid conduit of the frac plug.
E21B 29/00 - Découpage ou destruction de tubes, packers, bouchons ou câbles, situés dans les trous de forage ou dans les puits, p.ex. découpage de tubes endommagés, de fenêtres; Déformation des tubes dans les trous de forage; Remise en état des tubages de puits sans les retirer du sol
E21B 33/128 - Packers; Bouchons avec un organe dilaté radialement par pression axiale
E21B 34/14 - Aménagements des vannes pour les trous de forage ou pour les puits dans les puits actionnés par le mouvement des outils, p.ex. obturateurs à manchons actionnés par des pistons ou par des outils à câble
E21B 34/06 - Aménagements des vannes pour les trous de forage ou pour les puits dans les puits
E21B 33/13 - Procédés ou dispositifs de cimentation, de bouchage des trous, des fissures ou analogues
E21B 43/26 - Procédés pour activer la production par formation de crevasses ou de fractures
E21B 47/06 - Mesure de la température ou de la pression
E21B 33/124 - Unités à bouchons espacés longitudinalement pour isoler les espaces intermédiaires
43.
Assessing wellbore characteristics using high frequency tube waves
A hydrocarbon well includes a wellbore with a surface casing string that couples the wellbore to a wellhead located at the surface and a production casing string that extends through a reservoir within the subsurface. A fluid column is present within the wellbore. The hydrocarbon well also includes a high-frequency tube wave generator that is hydraulically coupled to the wellbore and is configured to generate high-frequency tube waves that propagate within the fluid column. The high-frequency tube waves include a selected waveform containing a specific bandwidth of high-frequency components. The hydrocarbon well further includes a receiver that is hydraulically coupled to the wellbore and is configured to record data corresponding to the generated and reflected high-frequency tube waves propagating within the fluid column, wherein the recorded data relate to characteristics of the wellbore. Moreover, such techniques may also be applied to a pipeline.
E21B 47/16 - Moyens pour la transmission de signaux de mesure ou signaux de commande du puits vers la surface, ou de la surface vers le puits, p.ex. pour la diagraphie pendant le forage utilisant des ondes acoustiques le long du train de tiges ou du tubage
E21B 43/26 - Procédés pour activer la production par formation de crevasses ou de fractures
44.
Method for attenuation compensation utilizing non-stationary matching filters
A method and apparatus for generating attenuation-compensated images of subsurface region, including: computing an image of the region utilizing elastic wave propagation, based on field data and subsurface model; generating forward-modeled data utilizing forward viscoelastic wave propagation, based on the image; computing secondary image by migration; computing NMF based on the images; and applying the NMF to the image to generate the attenuation-compensated image. A method and apparatus includes: iteratively computing attenuation-compensated gradient of the region utilizing an elastic wave propagation operator in the back-propagation and a viscoelastic wave propagation operator in the forward modelling, based on field data and subsurface model; computing search direction based on the attenuation-compensated gradient, searching for an improved model, and checking the improved model for convergence.
A method and apparatus for generating a high-resolution seismic image, including extracting a reflectivity distribution from a geological model; utilizing the reflectivity distribution to label features of the model; generating forward-modeled data from the model; migrating the forward-modeled data to create a migrated image; and training a deep neural network with the labeled synthetic geological model and the migrated image to create a reflectivity prediction network. A method and apparatus includes: selecting a first subset of the field data; applying a low-pass filter to the first subset to generate a first filtered dataset; migrating the first filtered dataset to create a first migrated image; applying a high-pass filter to the first subset to generate a second filtered dataset; migrating the second filtered dataset to create a second migrated image; and training a deep neural network to predict a target distribution of high-frequency signal.
A method and system are described for communicating within a system, which may be along tubular members and used during cementing installation operations. The method includes constructing a communication network and installing the communication nodes along a wellbore. The communication nodes are used to monitor the fluids adjacent to the communication nodes during the cementing installation operations. Once the cement is installed, the cementing installation operations may be used for hydrocarbon operations, such as hydrocarbon exploration, hydrocarbon development, and/or hydrocarbon production.
E21B 47/005 - Surveillance ou contrôle de la qualité ou du niveau de cimentation
E21B 33/13 - Procédés ou dispositifs de cimentation, de bouchage des trous, des fissures ou analogues
E21B 33/14 - Procédés ou dispositifs de cimentation, de bouchage des trous, des fissures ou analogues pour la cimentation des tubes dans les trous de forage ou de sondage
E21B 47/16 - Moyens pour la transmission de signaux de mesure ou signaux de commande du puits vers la surface, ou de la surface vers le puits, p.ex. pour la diagraphie pendant le forage utilisant des ondes acoustiques le long du train de tiges ou du tubage
E21B 47/18 - Moyens pour la transmission de signaux de mesure ou signaux de commande du puits vers la surface, ou de la surface vers le puits, p.ex. pour la diagraphie pendant le forage utilisant des ondes acoustiques à travers le fluide du puits
47.
Discontinuous Interpolation Using Continuous Formulation, C1 or C0 FEM Discretization, and Scalable Solver
A methodology for discontinuous smooth interpolation in order to generate a curve of a discontinuous volume due to one or more faults in a subsurface is disclosed. Faults in a subsurface result in discontinuities in the subsurface. Hydrocarbon management may seek to determine various surfaces in the subsurface, including across the faults in the subsurface. To generate the various surfaces, a continuous formulation of the interpolation method is followed in which discontinuous smooth interpolation is viewed as a variational optimization problem (such as an energy optimization problem) for the surface curvature function. In this way, the methodology does not require that the input data be located at grid points and discretized with a structured regular grid. Rather, because a continuous function is used, an unstructured grid may also be used to discretize the resulting equation.
G06F 30/23 - Optimisation, vérification ou simulation de l’objet conçu utilisant les méthodes des éléments finis [MEF] ou les méthodes à différences finies [MDF]
G06F 17/17 - Opérations mathématiques complexes Évaluation de fonctions par des procédés d'approximation, p.ex. par interpolation ou extrapolation, par lissage ou par le procédé des moindres carrés
G06F 17/11 - Opérations mathématiques complexes pour la résolution d'équations
48.
Method for Approximating An Inverse Hessian Using Non-Stationary Regression
A method for approximating an inverse Hessian is provided. One methodology to generate the inverse Hessian is to precondition the gradient, such as by using point-spread function deconvolution, T-power, or source-illumination compensation, prior to using non-stationary matching filters (NMF) to generate the inverse Hessian. Various types of NMF are contemplated, including using filters for different windows in the subsurface or using filters assigned to specific locations in the subsurface. Further, the number of filters for NMF may vary from iteration to iteration. For example, the filters assigned to the specific locations in the subsurface may be generated in a multi-scale manner, in which an initial iteration uses longer scale/longer wavelength features for inversion and subsequent iterations use finer scale/smaller wavelength features for inversion.
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
G06F 30/20 - Optimisation, vérification ou simulation de l’objet conçu
A methodology for extending bandwidth of geophysical data is disclosed. Geophysical data, obtained via a towed streamer, may have significant noise in a certain band (such as less than 4 Hz), rendering the data in the certain band unreliable. To remedy this, geophysical data, from a band that is reliable, may be extended to the certain band, resulting in bandwidth extension. One manner of bandwidth extension comprises using machine learning to generate a machine learning model. Specifically, because bandwidth may be viewed as a sequence, machine learning configured to identify sequences, such as recurrent neural networks, may be used to generate the machine learning model. In particular, machine learning may use a training dataset acquired via ocean bottom nodes in order to generate the machine learning model. After which, the machine learning model may be used to extend the bandwidth of a test dataset acquired via a towed streamer.
G01V 1/38 - Séismologie; Prospection ou détection sismique ou acoustique spécialement adaptées aux zones recouvertes d'eau
G01V 1/34 - Représentation des enregistrements sismiques
E21B 49/00 - Test pour déterminer la nature des parois des trous de forage; Essais de couches; Procédés ou appareils pour prélever des échantillons du terrain ou de fluides en provenance des puits, spécialement adaptés au forage du sol ou aux puits
E21B 47/002 - Relevés dans les trous de forage ou dans les puits par inspection visuelle
50.
Downhole completion assemblies and methods of completing a hydrocarbon well
Methods include positioning a downhole completion assembly in a tubular conduit of a downhole tubular of a hydrocarbon well. The downhole completion assembly includes a downhole sub-assembly and an uphole sub-assembly. The methods also include forming a fluid seal within the tubular conduit with the downhole sub-assembly, decoupling the uphole sub-assembly from the downhole sub-assembly, translating the uphole sub-assembly in an uphole direction, perforating the downhole tubular with the uphole sub-assembly, translating the uphole sub-assembly in a downhole direction, coupling the uphole sub-assembly to the downhole sub-assembly, ceasing the fluid seal, and translating the downhole completion assembly in the uphole direction.
E21B 43/119 - Perforateurs; Perméators - Parties constitutives, p.ex. pour localiser l'emplacement ou la direction de la perforation
E21B 43/14 - Extraction d'un puits à horizons multiples
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
An oil-water fractionation system is positioned within a wellbore on a subsurface end of a production tubing proximate to a production region. The fractionation system includes a permeable hydrophobic media for preferentially conveying an oil-enriched stream (reduced water-cut presence) from the production region into the production tubing, and a permeable oleophobic media for preferentially conveying a water-enriched stream (reduced oil-cut presence) into a second flow path. The permeable hydrophobic media and the permeable oleophobic media are in simultaneous hydraulic communication with the production region. The permeable hydrophobic media is manufactured with a relatively high effective permeability to oil, allowing the oil-enriched stream to flow through the permeable hydrophobic media into the production tubing. In contrast, the permeable oleophobic media is manufactured with a relatively high effective permeability to water, allowing the water-enriched stream to flow through the permeable oleophobic media into the second flow path.
A semi-elimination methodology for simulating high flow features in a reservoir and wells is disclosed. The reservoir and wells may be divided into a plurality of cells, including small cells in wells and the reservoir and bulk cells in the bulk of the reservoir, where the small cells are smaller (e.g., by pore volume) than the bulk cells. Processing of all of the cells, including all of the small cells, may be too computationally expensive, particularly when processing is iterative. In that regard, at least some of the small cells are partly processed in an iteration, such as for flow rates, compositions, or flow derivatives. After which, some or all of the small cells are eliminated from further processing in the iteration. In that way, high flow features in a reservoir and wells may be simulated effectively.
G06F 30/28 - Optimisation, vérification ou simulation de l’objet conçu utilisant la dynamique des fluides, p.ex. les équations de Navier-Stokes ou la dynamique des fluides numérique [DFN]
53.
Engineered production liner for a hydrocarbon well
Techniques described herein relate to a well completion including an engineered production liner extending into a reservoir. The engineered production liner includes limited-entry liner (LEL) valves configured to open to allow an acid solution to jet into the reservoir during an acid stimulation process, and close to prevent production fluid from flowing through the LEL valves when the well completion is put into production. The engineered production liner also includes pre-packed chemically-infused material (CIM) cartridges including production chemicals, and openings that align with the pre-packed CIM cartridges. The openings are plugged during the acid stimulation process to force the acid solution to flow through the LEL valves. The pre-packed CIM cartridges and the openings are configured to allow the production fluid to absorb a portion of the production chemicals as it flows from the reservoir into the engineered production liner when the well completion is put into production.
E21B 34/10 - Aménagements des vannes pour les trous de forage ou pour les puits dans les puits actionnés par un fluide de commande provenant de l'extérieur du trou de forage
A method for regasification of liquefied natural gas (LNG) and an LNG regasification terminal employing said method. An LNG carrier is filled with LNG at an LNG hub and transports the LNG to a receiving terminal. The LNG is offloaded to LNG storage at the receiving terminal. The LNG storage has less storage capacity than the storage capacity of the carrier. The LNG is regasified at a regasification rate at the receiving terminal. The carrier is maintained at the receiving terminal until the carrier is empty, and then returns to the LNG hub to be filled with more LNG. The process is then repeated. The storage capacity of the LNG storage is sufficient to supply LNG for regasifying the LNG at the regasification rate until the carrier returns with additional LNG from the LNG hub. The carrier is the sole source of LNG for the receiving terminal.
F17C 6/00 - Procédés ou appareils pour remplir des récipients non sous pression de gaz liquéfiés ou solidifiés
F17C 9/00 - Procédés ou appareils pour vider les gaz liquéfiés ou solidifiés contenus dans des récipients non sous pression
B67D 7/78 - Aménagements des réservoirs de stockage ou des systèmes de canalisations
B67D 9/00 - Appareils ou dispositifs pour transférer des liquides lors du chargement ou du déchargement des navires
55.
Hydrocarbon wells and associated methods that utilize radio frequency identification tags and flowable interrogators to interrogate the hydrocarbon wells
Hydrocarbon wells and associated methods that utilize radio frequency identification (RFID) tags and flowable interrogators to interrogate the hydrocarbon wells are provided. The hydrocarbon wells include a wellbore, a downhole tubular that defines a tubular conduit and extends within the wellbore, and a plurality of RFID tags. The hydrocarbon wells also include a downhole interrogator storage structure that includes a plurality of flowable interrogators and a well-side communication device. Methods of operating the hydrocarbon wells are also provided.
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
56.
Estimating Pore and Fluid Characteristic Properties in Rock Samples Using Nuclear Magnetic Resonance Analyses
A method for deriving at least one pore or fluid relaxation parameter and endpoint selected from the group consisting of a longitudinal T1 pore surface relaxivity constant (ρ1), a transverse T2 pore surface relaxivity constant (ρ2), a pore surface-to-volume ratio (A/V), an equivalent pore-throat radius (req), and a bulk fluid relaxation time (TB) comprising: identifying modes in NMR T1-T2 data; assigning the modes to a poro-fluid class; clustering the modes based on poro-fluid class; estimating TB based on an asymptote fit of the clusters using T1 and T2 relaxation mechanisms in a bulk fluid relaxation-dominated limit; estimating ρ2/ρ1 based on an asymptote fit of the clusters using T1 and T2 relaxation mechanisms in a surface relaxation-dominated limit; fitting the T1 and T2 relaxation mechanisms to the clusters using the estimated TB; and deriving the pore or fluid relaxation parameter and endpoint for the poro-fluid classes from the fit.
G01V 3/32 - Prospection ou détection électrique ou magnétique; Mesure des caractéristiques du champ magnétique de la terre, p.ex. de la déclinaison ou de la déviation spécialement adaptée au carottage fonctionnant par résonance magnétique électronique ou nucléaire
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 33/50 - Systèmes d'imagerie RMN basés sur la détermination des temps de relaxation
E21B 49/02 - Test pour déterminer la nature des parois des trous de forage; Essais de couches; Procédés ou appareils pour prélever des échantillons du terrain ou de fluides en provenance des puits, spécialement adaptés au forage du sol ou aux puits par prélèvements mécaniques d'échantillons du terrain
A self-adjusting gas lift system and corresponding self-adjusting gas lift valve (GLV) are described herein. The self-adjusting gas lift system includes a number of self-adjusting GLVs that fluidically couple an annulus of a well to an interior of a production tubing of the well. Each of the self-adjusting GLVs is configured to open to allow a compressed gas to flow from the annulus to the interior of the production tubing when a pressure differential between an injection pressure of the compressed gas within the annulus and a production pressure of fluids within the production tubing is within an engineered range. Each of the self-adjusting GLVs is also configured to close when the pressure differential is outside the engineered range.
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 43/12 - Procédés ou appareils pour commander l'écoulement du fluide extrait vers ou dans les puits
Methods of completing a hydrocarbon well. The methods include establishing a first fluid seal with an isolation device, forming a first perforation with a perforation device, and fracturing a first zone of a subsurface region with a pressurizing fluid stream. The methods also include moving the isolation device and the perforation device in an uphole direction within a tubular conduit of a downhole tubular that extends within a wellbore of the hydrocarbon well. Subsequent to the moving, the methods further include repeating the establishing to establish a second fluid seal, repeating the forming to form a second perforation with the perforation device, and repeating the fracturing to fracture a second zone of the subsurface region.
Disclosed are processes and systems for the removal of water from a feed stream utilizing swing adsorption processes including an adsorbent bed comprising an adsorbent material which is a cationic zeolite RHO. The cationic zeolite RHO comprises at least one, preferably two, metal cations selected from Group 1 and 2 elements (new Group 1-18 IUPAC numbering). The swing adsorption processes and systems utilizing the cationic zeolite RHO have an adsorption selectivity for water and are useful in selective dehydration of commercial feed streams. The cationic zeolite RHO additionally has an exceptionally high water adsorption stability for use in feed streams with wet acid gas environments operating under cyclic swing adsorption conditions.
B01D 53/00 - SÉPARATION Épuration chimique ou biologique des gaz résiduaires, p.ex. gaz d'échappement des moteurs à combustion, fumées, vapeurs, gaz de combustion ou aérosols
B01D 53/04 - SÉPARATION Épuration chimique ou biologique des gaz résiduaires, p.ex. gaz d'échappement des moteurs à combustion, fumées, vapeurs, gaz de combustion ou aérosols par adsorption, p.ex. chromatographie préparatoire en phase gazeuse avec adsorbants fixes
A gas processing system is described herein. The gas processing system includes a number of co-current contacting systems configured to contact a sour feed gas stream including an acid gas with a solvent stream to produce a partially-sweetened gas stream and a rich solvent stream including an absorbed acid gas. At least one of the co-current contacting systems is configured to send the rich solvent stream to a regenerator. The regenerator is configured to remove the absorbed acid gas from the rich solvent stream to produce a lean solvent stream. The gas processing system also includes a solvent treater configured to treat at least a portion of the lean solvent stream to produce an enhanced solvent stream, and a final co-current contacting system configured to contact the partially-sweetened gas stream with the enhanced solvent stream to produce a partially-loaded solvent stream and a final gas stream.
B01D 53/14 - SÉPARATION Épuration chimique ou biologique des gaz résiduaires, p.ex. gaz d'échappement des moteurs à combustion, fumées, vapeurs, gaz de combustion ou aérosols par absorption
Detection of hydrocarbon bubbles in water using Light Detection and Ranging (LIDAR) to survey shallow water environments for the detection of surface hydrocarbon bubbles therein using LIDAR for the purposes of hydrocarbon exploration and/or brownfield remediation. Embodiments include a method of deploying an airborne LIDAR system configured to detect surface hydrocarbon bubbles in a shallow water environment, the LIDAR system accounting for a bubble volume scattering coefficient; and surveying, using the LIDAR system, the shallow water environment to detect surface hydrocarbon bubbles therein.
Provided is a method for determining convergence in full wavefield inversion (FWI) of 4D seismic (time-lapse seismic: 3D seismic surveys acquired at different times with the first survey termed as the baseline and subsequent surveys termed as monitors). FWI applied to field seismic data includes iteratively solving for subsurface property models and model difference between monitor and baseline. Iteration occurs until the model difference is sufficiently converged. Rather than determining convergence by examining an entire subsurface region of the models and/or the model difference, subparts of the subsurface region models and/or the model difference are examined in order to determine convergence. For example, different regions behave differently, include the target reservoir region (where hydrocarbon is present) and the background region that is outside the target reservoir region. Thus, transforming the subregions of the models and/or the model difference and analyzing the transformations may indicate convergence of the overall model difference.
Systems and a method for resisting a fluctuation in a value of a parameter relating to well equipment using a magnetorheological dampener system are described herein. The method includes continuously determining the value of the parameter relating to the well equipment, determining a fluctuation in the value of the parameter, and comparing the fluctuation in the value of the parameter to a preset limit. The method also includes energizing an electromagnet to increase a viscosity of a magnetorheological fluid (MRF) if the fluctuation exceeds the preset limit.
F16F 9/53 - Moyens pour le réglage des caractéristiques des amortisseurs en faisant varier la viscosité du fluide, p.ex. électromagnétiques
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 47/06 - Mesure de la température ou de la pression
E21B 47/10 - Localisation des fuites, intrusions ou mouvements du fluide
F16F 15/00 - Suppression des vibrations dans les systèmes; Moyens ou dispositions pour éviter ou réduire les forces de déséquilibre, p.ex. dues au mouvement
F16F 9/10 - Ressorts, amortisseurs de vibrations, amortisseurs de chocs ou amortisseurs de mouvement de structure similaire, utilisant un fluide ou moyen équivalent comme agent d'amortissement utilisant un fluide dont la nature est sans importance
F16F 9/32 - Ressorts, amortisseurs de vibrations, amortisseurs de chocs ou amortisseurs de mouvement de structure similaire, utilisant un fluide ou moyen équivalent comme agent d'amortissement - Parties constitutives
64.
Model for Coupled Porous Flow and Geomechanics for Subsurface Simulation
A method for generating a three-dimensional geomechanical model of a subsurface volume is provided. The geomechanical model may be used to predict changes in geomechanical stress in the grid (such as a three-dimensional unstructured grid), which may be caused by extraction from or injection into the reservoir. The geomechanical model may be generated by solving, in combination, the finite element method at the vertices of a respective cell in the grid for momentum balance and the finite volume method at the center of the respective cell for mass balance. In this way, one or both of rock displacement or pore flow may be solved using the geomechanical model.
G01V 99/00 - Matière non prévue dans les autres groupes de la présente sous-classe
G06F 30/23 - Optimisation, vérification ou simulation de l’objet conçu utilisant les méthodes des éléments finis [MEF] ou les méthodes à différences finies [MDF]
G06F 30/28 - Optimisation, vérification ou simulation de l’objet conçu utilisant la dynamique des fluides, p.ex. les équations de Navier-Stokes ou la dynamique des fluides numérique [DFN]
65.
Pretreatment, Pre-Cooling, and Condensate Recovery of Natural Gas By High Pressure Compression and Expansion
A method and apparatus for producing liquefied natural gas (LNG) from a natural gas stream. Heavy hydrocarbons are removed from the natural gas stream in a separator to generate a bottom stream and a separated natural gas stream, which is used as a coolant in a heat exchanger to generate a pretreated natural gas stream. The pretreated natural gas stream is compressed and cooled to form a chilled pretreated natural gas stream, part of which forms a recycle stream to exchange heat with the separated natural gas stream in the heat exchanger, thereby generating a cooled recycle stream. The temperature and pressure of the cooled recycle stream are reduced. The cooled recycle stream is then separated into an overhead stream and a reflux stream, which is directed to the separator. The chilled pretreated gas stream is liquefied to form LNG.
F25J 1/00 - Procédés ou appareils de liquéfaction ou de solidification des gaz ou des mélanges gazeux
F25J 1/02 - Procédés ou appareils de liquéfaction ou de solidification des gaz ou des mélanges gazeux nécessitant l'emploi d'une réfrigération, p.ex. de l'hélium, de l'hydrogène
66.
Removal of acid gases from a gas stream, with O2 enrichment for acid gas capture and sequestration
A method and apparatus for processing a hydrocarbon gas stream including sulfurous components and carbon dioxide. The hydrocarbon gas stream is separated into a sweetened gas stream and an acid gas stream. The acid gas stream and an air stream, enriched with oxygen such that the air stream comprises between 22% and 100% oxygen, are combusted in a sulfur recovery unit to separate the acid gas stream into a liquid stream of elemental sulfur and a tail gas stream comprising acid gas impurities. The tail gas stream and an air flow are sub-stoichiometrically combusted to produce an outlet stream comprising hydrogen sulfide and carbon monoxide. The outlet stream is hydrogenated to convert sulfur species to a gaseous catalytic output stream comprising hydrogen sulfide. Water is removed from the gaseous catalytic output stream to produce a partially-dehydrated acid gas stream, which is pressurized and injected into a subsurface reservoir.
B01D 53/00 - SÉPARATION Épuration chimique ou biologique des gaz résiduaires, p.ex. gaz d'échappement des moteurs à combustion, fumées, vapeurs, gaz de combustion ou aérosols
B01D 53/14 - SÉPARATION Épuration chimique ou biologique des gaz résiduaires, p.ex. gaz d'échappement des moteurs à combustion, fumées, vapeurs, gaz de combustion ou aérosols par absorption
An instrumented coupling for pipe joints is described herein. The instrumented coupling includes a first threaded end configured to thread to a first pipe joint and a second threaded end configured to thread to a second pipe joint. The instrumented coupling also includes a sensor configured to obtain a measurement of a parameter of a well and a communications device configured to communicate to a receiving device outside of the well. The instrumented coupling further includes a processor configured to execute instructions in a data store. The instructions direct the processor to read the measurement from the sensor, compare the measurement from the sensor to a preset limit, and generate a signal within the communications device based, at least in part, on the measurement.
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
G01N 23/22 - 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
E21B 17/042 - Accouplements; Joints entre tige et trépan, ou entre tiges filetés
E21B 47/11 - Localisation des fuites, intrusions ou mouvements du fluide utilisant la radioactivité
E21B 47/14 - Moyens pour la transmission de signaux de mesure ou signaux de commande du puits vers la surface, ou de la surface vers le puits, p.ex. pour la diagraphie pendant le forage utilisant des ondes acoustiques
E21B 49/08 - Prélèvement d'échantillons de fluides ou test des fluides dans les trous de forage ou dans les puits
E21B 47/06 - Mesure de la température ou de la pression
G01N 21/77 - Systèmes dans lesquels le matériau est soumis à une réaction chimique, le progrès ou le résultat de la réaction étant analysé en observant l'effet sur un réactif chimique
F16L 15/08 - Raccords avec filetage; Formes des filetages pour ces raccords avec des éléments supplémentaires
A method for regenerating liquid desiccant is described herein. The method includes co-currently contacting a rich desiccant stream including water with a stripping gas within a co-current contacting system such that the stripping gas removes at least a portion of the water from the rich desiccant stream, producing a wet stripping gas and a lean desiccant stream. The method also includes removing the water from the wet stripping gas within a stripping gas separation system, regenerating the stripping gas, and recirculating the stripping gas to the co-current contacting system.
B01D 53/14 - SÉPARATION Épuration chimique ou biologique des gaz résiduaires, p.ex. gaz d'échappement des moteurs à combustion, fumées, vapeurs, gaz de combustion ou aérosols par absorption
A co-axial co-current contactor (CA-CCC) is described herein. The CA-CCC includes an outer annular support ring and an inner annular support ring configured to maintain the CA-CCC within an outer pipe and an inner pipe, respectively. The CA-CCC includes rich liquid flow channels located between the outer annular support ring and the inner annular support ring that are configured to allow a rich liquid stream to flow through the CA-CCC, and a central gas entry cone and gas flow channels configured to allow a gas stream to flow through the CA-CCC. The CA-CCC further includes radial blades configured to secure the central gas entry cone to the inner annular support ring and allow a lean liquid stream to flow into the central gas entry cone and the gas flow channels. The CA-CCC provides for efficient incorporation of liquid droplets formed from the lean liquid stream into the gas stream.
B01D 53/14 - SÉPARATION Épuration chimique ou biologique des gaz résiduaires, p.ex. gaz d'échappement des moteurs à combustion, fumées, vapeurs, gaz de combustion ou aérosols par absorption
B01D 53/18 - Unités d'absorption; Distributeurs de liquides
Hydrocarbon wells and methods that utilize a plug with an included tracer material. The hydrocarbon wells include a wellbore that extends within a subsurface region and a downhole tubular that extends within the wellbore and defines a tubular conduit. The hydrocarbon wells also include a plug positioned within the wellbore and a tracer detection structure. The plug forms a fluid seal and includes a tracer material. The tracer detection structure is configured to detect the tracer material within a produced fluid stream that is produced from the hydrocarbon well. The methods include releasing the tracer material from the plug and producing the produced fluid stream. The methods also include detecting the tracer material within the produced fluid stream.
E21B 47/09 - Localisation ou détermination de la position d'objets dans les trous de forage ou dans les puits; Identification des parties libres ou bloquées des tubes
71.
Drill strings with probe deployment structures, hydrocarbon wells that include the drill strings, and methods of utilizing the drill strings
Drill strings with probe deployment structures, hydrocarbon wells that include the drill strings, and methods of utilizing the drill strings are disclosed herein. The drill strings include a pipe string and a drill bit attached to the pipe string. The drill strings also include a probe deployment structure attached to the pipe string and a downhole communication device attached to the pipe string. The probe deployment structure includes a probe and is configured to selectively insert the probe into a subterranean formation via a wellbore of the hydrocarbon well. The probe is configured to measure at least one property of the subterranean formation. The downhole communication device is configured to communicate with the probe. The hydrocarbon wells include a drill string support structure, which supports the drill string, a wellbore extending within a subsurface region, and the drill string extending within the wellbore.
E21B 47/06 - Mesure de la température ou de la pression
E21B 47/18 - Moyens pour la transmission de signaux de mesure ou signaux de commande du puits vers la surface, ou de la surface vers le puits, p.ex. pour la diagraphie pendant le forage utilisant des ondes acoustiques à travers le fluide du puits
E21B 47/007 - Mesure des contraintes dans le cuvelage ou la tige de forage
A method and apparatus for separating a separation component from a gas stream. One exemplary method includes: flowing the gas stream across a process surface of a compliant composite heat transfer wall, wherein: the gas stream has an initial concentration of the separation component, and the gas stream has a gas temperature; flowing a cooling fluid across a cooling surface of the wall, wherein: the cooling fluid has a fluid temperature, and the fluid temperature is less than the gas temperature; and producing an output gas stream, wherein: the output gas stream has an output concentration of the separation component, and the output concentration is less than the initial concentration. Another exemplary method includes separating at least a portion of the separation component from the gas stream by: accumulating the portion proximate the process surface; and delaminating the portion from the process surface with a flow of the gas stream.
B01D 53/00 - SÉPARATION Épuration chimique ou biologique des gaz résiduaires, p.ex. gaz d'échappement des moteurs à combustion, fumées, vapeurs, gaz de combustion ou aérosols
F28F 23/00 - Caractéristiques relatives à l'utilisation de matériaux servant pour échange intermédiaire de chaleur, p.ex. emploi de compositions spécifiées
B01D 5/00 - Condensation de vapeurs; Récupération de solvants volatils par condensation
Highly crosslinked polymer particulate. The highly crosslinked polymer particulate includes a plurality of crosslinked polymer granules. The crosslinked polymer granules include a highly crosslinked polymeric material. A characteristic dimension of each crosslinked polymer granule of the plurality of crosslinked polymer granules is at least 10 micrometers and at most 5 millimeters.
Hydrocarbon wells including crosslinked polymer granules as lost circulation material and methods of drilling the hydrocarbon wells. The hydrocarbon wells include a wellbore that extends within a subsurface region, a drilling rig, a drilling mud supply system, a lost circulation detection structure, and a lost circulation material supply system that includes a lost circulation material. The lost circulation material includes a plurality of crosslinked polymer granules, and a characteristic dimension of each crosslinked polymer granule is at least 20 micrometers and at most 1 millimeter. Each crosslinked polymer granule contains a highly crosslinked polymeric material that includes a plurality of polyethylene polymer chains. The methods include rotating a drill string to extend a length of a wellbore and, during the rotating, flowing a drilling mud stream. The methods also include detecting a lost circulation event and, responsive to the detecting, providing a lost circulation material to the wellbore.
Hydrocarbon wells including crosslinked polymer granules in sand control structures and/or methods of completing the hydrocarbon wells. The hydrocarbon wells include a wellbore that extends within a subsurface region and a downhole tubular that extends within the wellbore, defines a tubular conduit, and includes a fluid-permeable segment. The hydrocarbon wells also include a sand control structure that is positioned within an annular space that extends between the wellbore and the fluid-permeable segment of the downhole tubular. The sand control structure is configured to restrict migration of formation sands from the subsurface region and into the tubular conduit via the fluid-permeable segment and includes a plurality of crosslinked polymer granules. The methods include positioning a downhole tubular within a wellbore and providing a plurality of crosslinked polymer granules to an annular space that extends between the wellbore and a fluid-permeable segment of the downhole tubular.
C09K 8/58 - Compositions pour les méthodes de récupération assistée pour l'extraction d'hydrocarbures, c. à d. pour améliorer la mobilité de l'huile, p.ex. fluides de déplacement
C09K 8/575 - Compositions à base d'eau ou de solvants polaires contenant des composés organiques
E21B 43/10 - Mise en place de tubages, filtres ou crépines dans les puits
76.
Method for drilling wellbores utilizing drilling parameters optimized for stick-slip vibration conditions
The present disclosure relates generally to the field of drilling operations. More particularly, the present disclosure relates to methods for drilling wells utilizing drilling equipment, more particularly drill string assemblies, and making adjustments to drilling parameters during the drilling operation based on analysis of the drilling data. Included are methods for the selection of modified drilling parameters to mitigate torsional vibration dysfunction.
Methods of manufacturing highly crosslinked polymer particulate. The methods include positioning a granular polymeric material within a crosslinking apparatus and crosslinking the granular polymeric material with the crosslinking apparatus to form a highly crosslinked polymeric material. The methods also include forming a plurality of crosslinked polymer granules from the highly crosslinked polymeric material.
Hydrocarbon wells including crosslinked polymer granules as a proppant, methods of forming the hydrocarbon wells, and methods of operating the hydrocarbon wells. The hydrocarbon wells include a wellbore that extends within a subsurface region and a downhole tubular that extends within the wellbore and defines a tubular conduit. The hydrocarbon wells also include a plurality of perforations formed within the downhole tubular and a plurality of fractures formed within the subsurface region. The hydrocarbon wells further include the proppant positioned within the plurality of fractures. The proppant includes a plurality of crosslinked polymer granules, and each crosslinked polymer granule has a characteristic dimension of at least 100 micrometers and at most 2 millimeters.
Seismic data processing may include computing the travel time shift between two seismic signals or the depth shift between two seismic images. In Full Waveform Inversion (FWI), the travel time difference between an observed trace and a simulated trace may be computed such that the two traces match after the travel time shift is applied to the observed trace. The travel time shift may be computed based on a constrained optimization that maximizes the windowed cross-correlation between the two seismic traces by constraining the time derivative of the travel time shift to be less than a constant while maximizing the windowed cross-correlation. Further, the travel time shift may be computed during the model line search in FWI by computing a plurality of travel time shifts where a first travel time shift is dependent on the observed trace and a second travel time shift is independent of the observed trace.
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
Hydrocarbon wells that include interrogation devices positioned within a fracture and methods of monitoring at least one property of a fracture. The hydrocarbon wells include a wellbore that extends within a subsurface region and a fracture that extends from the wellbore. The hydrocarbon wells also include a plurality of interrogation devices entrained within a carrier fluid and positioned within the fracture and a downhole communication device positioned within the wellbore and proximal the fracture. The methods include flowing the interrogation devices into the fracture and conveying the excitation signal into the fracture. The methods also include receiving the excitation signal with the interrogation devices and generating a plurality of corresponding resultant signals with the interrogation devices. The methods further include receiving at least a subset of the corresponding resultant signals with a downhole communication device and determining at least one property of the fracture based upon the corresponding resultant signals.
E21B 47/06 - Mesure de la température ou de la pression
E21B 47/09 - Localisation ou détermination de la position d'objets dans les trous de forage ou dans les puits; Identification des parties libres ou bloquées des tubes
81.
Methods and systems for generating simulation grids via zone by zone mapping from design space
An illustrative geologic modeling method may comprise: obtaining a geologic model representing a subsurface region in physical space, the subsurface region being divided into multiple zones; sequentially generating a physical space simulation mesh for each of said multiple zones by: (a) mapping a current zone of the physical space geologic model to a current zone of a design space model representing a current zone of an unfaulted subsurface region; (b) gridding the design space model to obtain a design space mesh; (c) partitioning cells in the current zone of the design space mesh with faults mapped from the current zone of the physical space geologic model, thereby obtaining a partitioned design space mesh for the current zone; and (d) reverse mapping the partitioned design space mesh for the current zone to the physical space for the current zone.
G06F 30/23 - Optimisation, vérification ou simulation de l’objet conçu utilisant les méthodes des éléments finis [MEF] ou les méthodes à différences finies [MDF]
G01V 99/00 - Matière non prévue dans les autres groupes de la présente sous-classe
G06T 17/20 - Description filaire, p.ex. polygonalisation ou tessellation
Systems and a method for braking an object are provided. An example method, includes determining the expected speed of the object, monitoring the expected speed of the object, and determining if the actual speed of the object is within a preset tolerance of the expected speed. If the speed is not within the preset tolerance of the expected speed, a magnetorheological brake is activated to slow the object.
F16D 57/00 - Freins à résistance liquide; Freins à résistance à l'air
E21B 17/20 - Tubes de forage flexibles ou articulés
F16D 63/00 - Freins non prévus ailleurs; Freins combinant plusieurs des types mentionnés dans les groupes
E21B 19/08 - Appareils pour faire avancer les tiges ou les câbles; Appareils pour augmenter ou diminuer la pression sur l'outil de forage; Appareils pour compenser le poids des tiges
F16L 55/46 - Lancement ou récupération des hérissons ou des chariots
E21B 40/00 - Accrocheurs de tubes, arrêtant automatiquement la chute des tubes de puits de pétrole
Although high-manganese steels may have desirable mechanical strength and corrosion resistance, machining and casting can be difficult. Alternatively, high-manganese steel parts may be fabricated to near-net shape parts using powder metallurgical processing, such as hot pressing and powder injection molding, thereby significantly minimizing or eliminating the need for further machining of fabricated parts. Hot pressing processes may comprise: loading a container with a plurality of particulates comprising a high-manganese steel; establishing a reduced pressure state in the container after loading the container with the plurality of particulates, and sealing the container to maintain the reduced pressure state therein and to afford a sealed container; placing the sealed container in a pressure vessel; heating the pressure vessel at a predetermined temperature while applying a predetermined pressure isostatically to an exterior surface of the sealed container with a pressurizing gas to consolidate the plurality of particulates into a densified part having a near-net shape; and removing the sealed container to expose a surface of the densified part.
B22F 3/22 - Fabrication de pièces ou d'objets à partir de poudres métalliques, caractérisée par le mode de compactage ou de frittage; Appareils spécialement adaptés à cet effet pour la fabrication de pièces par coulée en moule poreux ou absorbant, c. à d. par coulée d'une suspension de poudre métallique dans un moule poreux, d'une façon analogue au coulage de la barbotine
B22F 5/10 - Fabrication de pièces ou d'objets à partir de poudres métalliques caractérisée par la forme particulière du produit à réaliser d'articles avec des cavités ou des trous, non prévue dans les sous-groupes précédents
C22C 38/58 - Alliages ferreux, p.ex. aciers alliés contenant du chrome et du nickel et plus de 1,5% en poids de manganèse
C22C 38/44 - Alliages ferreux, p.ex. aciers alliés contenant du chrome et du nickel et du molybdène ou du tungstène
A vacuum insulated tubing including an inner pipe, an outer pipe concentrically arranged about the inner pipe such that an annulus is defined between the inner and outer pipes. A vacuum is drawn within the annulus, and a hydrocarbon-based coating is applied to at least one of the surfaces of the inner pipe or one of the surfaces of the outer pipe to reduce a rate of hydrogen migration into the annulus.
E21B 36/00 - 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
E21B 43/24 - Procédés de récupération assistée pour l'extraction d'hydrocarbures utilisant la chaleur, p.ex. injection de vapeur
E21B 17/00 - Tiges ou tubes de forage; Trains de tiges souples; Tiges d'entraînement; Masses-tiges; Tiges de pompage; Tubages; Colonnes de production
85.
Hydrocarbon wells including gas lift valves and methods of providing gas lift in a hydrocarbon well
Hydrocarbon wells including gas lift valves and methods of providing gas lift in a hydrocarbon well. The hydrocarbon wells include a wellbore extending within a subsurface region and a downhole tubular extending within the wellbore. The downhole tubular defines a tubular conduit, and the wellbore and the downhole tubular define an annular space therebetween. The hydrocarbon wells also include a lift gas supply system configured to provide a lift gas stream to the annular space and a closure material supply system configured to provide a closure material stream to the annular space. The hydrocarbon wells further includes a gas lift valve operatively attached to the downhole tubular. The gas lift valve includes a lift gas injection conduit and an actuation mechanism. The actuation mechanism selectively transitions to a closed state responsive to contact with the closure material. The methods include methods of operating the hydrocarbon wells.
E21B 43/12 - Procédés ou appareils pour commander l'écoulement du fluide extrait vers ou dans les puits
E21B 34/10 - Aménagements des vannes pour les trous de forage ou pour les puits dans les puits actionnés par un fluide de commande provenant de l'extérieur du trou de forage
E21B 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
86.
Downhole plugs including a sensor, hydrocarbon wells including the downhole plugs, and methods of operating hydrocarbon wells
Downhole plugs including a sensor, hydrocarbon wells including the downhole plugs, and methods of operating the hydrocarbon wells. The downhole plugs include a sealing structure, an actuation mechanism, and the sensor. The actuation mechanism is configured to selectively transition the sealing structure between a disengaged state, in which the downhole plug is free to move within a tubular conduit of a downhole tubular of the hydrocarbon well, and an engaged state, in which the sealing structure operatively engages with the downhole tubular, forms a fluid seal with the downhole tubular, and resists motion of the downhole plug within the tubular conduit. The sensor is configured to detect a sensed parameter within the tubular conduit and to generate a sensor signal indicative of the sensed parameter.
E21B 47/09 - Localisation ou détermination de la position d'objets dans les trous de forage ou dans les puits; Identification des parties libres ou bloquées des tubes
E21B 47/095 - Localisation ou détermination de la position d'objets dans les trous de forage ou dans les puits; Identification des parties libres ou bloquées des tubes par détection d'anomalies acoustiques, p.ex. à l'aide de pulsations de pression de boue
E21B 47/11 - Localisation des fuites, intrusions ou mouvements du fluide utilisant la radioactivité
E21B 47/10 - Localisation des fuites, intrusions ou mouvements du fluide
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 47/06 - Mesure de la température ou de la pression
A method and systems for sand control in wells are described in examples. An example uses a prepack screen assembly comprising an inner screen comprising openings having an inner size and an outer screen comprising openings having an outer size. Packing material is disposed between the inner screen and the outer screen comprising pores with a pore size that is selected based, at least in part, on the outer size, the inner size, or both.
Wellbore plugs that include an interrogation device, hydrocarbon wells that include the wellbore plugs, and methods of operating the hydrocarbon wells are disclosed herein. The wellbore plugs include a plug body, an interrogation device, and a sealing structure. The interrogation device is contained within the plug body and includes a sensor configured to detect at least one parameter of the hydrocarbon well. The hydrocarbon wells include a wellbore, a downhole tubular, the plug, and a communication device configured to receive communication data from the interrogation device. The methods include releasing an interrogation device from a plug, detecting at least one parameter within the hydrocarbon well with the interrogation device, transmitting communication data from the interrogation device, and receiving the communication data with a communication device.
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
89.
Test system and methods for evaluating erosion of a test sample
Test systems and methods for evaluating erosion of a test sample. The test systems include a particulate distribution structure configured to receive a supplied particulate stream and to discharge a distributed particulate stream. The test systems also include a particulate acceleration structure configured to receive the distributed particulate stream and to generate an accelerated particulate stream. The test systems further include a test sample fixture configured to hold the test sample at a test sample location positioned such that the accelerated particulate stream is incident upon the test sample location. The methods include methods of operating the test systems.
The invention is a data processing method and system for suggesting insightful and surprising sentences to geoscientists from unstructured text. The data processing system makes the necessary calculations to assign a surprisingness score to detect sentences containing several signals which when combined exponentially, have tendencies to give rise to surprise. In particular, the data processing system operates on any digital unstructured text derived from academic literature, company reports, web pages and other sources. Detected sentences can be used to stimulate ideation and learning events for geoscientists in industries such as oil and gas, economic mining, space exploration and Geo-health.
A method determining a volume of a pore type of a core sample can include: determining a porosity of a core sample, wherein the core sample has a permeability of 100 milliDarcy (mD) or less; saturating the core sample with a nuclear magnetic resonance (NMR) saturation fluid to achieve a saturated core sample; taking a NMR measurement of fluids in the saturated core sample; and deriving a volume for a pore type based on the porosity based on a correlation between the NMR measurement and a NMR signal to fluid volume calibration, wherein the pore type is selected from the group consisting of a nanopore, a micropore, a macropore, and any combination thereof.
G01N 24/08 - Recherche ou analyse des matériaux par l'utilisation de la résonance magnétique nucléaire, de la résonance paramagnétique électronique ou d'autres effets de spin en utilisant la résonance magnétique nucléaire
G01V 3/14 - Prospection ou détection électrique ou magnétique; Mesure des caractéristiques du champ magnétique de la terre, p.ex. de la déclinaison ou de la déviation fonctionnant par résonance magnétique électronique ou nucléaire
G01V 3/38 - Traitement de données, p.ex. pour l'analyse, pour l'interprétation ou pour la correction
G01R 33/44 - Dispositions ou appareils pour la mesure des grandeurs magnétiques faisant intervenir la résonance magnétique utilisant la résonance magnétique nucléaire [RMN]
G01R 33/34 - Systèmes d'excitation ou de détection, p.ex. utilisant des signaux radiofréquence - Détails de structure, p.ex. résonateurs
92.
Methods using advanced NMR analysis for core samples
A method for determining a core sample property selected from the group consisting of a recoverable oil volume, an irreducible hydrocarbon volume, a recoverable water volume, an irreducible water volume, and any combination thereof can include: determining a porosity of a core sample, wherein the core sample has a permeability of 100 milliDarcy (mD) or less; saturating the core sample with a NMR saturation fluid; taking a first nuclear magnetic resonance (NMR) measurement of fluids in the core sample; hydraulically exchanging a hydrophobic fluid or a hydrophilic fluid in the core sample in a hydrophilic NMR exchange fluid or a hydrophobic NMR exchange fluid, respectively; taking a second NMR measurement of the fluids in the core sample after hydraulic exchange; and deriving the property of the core sample based on the porosity, a NMR signal to fluid volume calibration, and a comparison between the first and second NMR measurements.
G01N 24/08 - Recherche ou analyse des matériaux par l'utilisation de la résonance magnétique nucléaire, de la résonance paramagnétique électronique ou d'autres effets de spin en utilisant la résonance magnétique nucléaire
G01V 3/14 - Prospection ou détection électrique ou magnétique; Mesure des caractéristiques du champ magnétique de la terre, p.ex. de la déclinaison ou de la déviation fonctionnant par résonance magnétique électronique ou nucléaire
G01V 3/38 - Traitement de données, p.ex. pour l'analyse, pour l'interprétation ou pour la correction
G01R 33/44 - Dispositions ou appareils pour la mesure des grandeurs magnétiques faisant intervenir la résonance magnétique utilisant la résonance magnétique nucléaire [RMN]
G01R 33/34 - Systèmes d'excitation ou de détection, p.ex. utilisant des signaux radiofréquence - Détails de structure, p.ex. résonateurs
93.
Methods for measuring the porosity of core samples using NMR analysis
A method for determining the porosity of a core sample can include: submerging a core sample in a NMR saturation fluid, wherein the core sample has a permeability of 10 mD or less; exposing the fluid to a vacuum while the core sample is submerged the NMR saturation fluid for a sufficient period of time to saturate the core sample; removing the vacuum while maintaining the core sample submerged the NMR saturation fluid; taking a NMR measurement of fluids in the core sample; and determining a porosity of the core sample based on a correlation between the NMR measurement and a NMR signal to fluid volume calibration.
G01N 24/08 - Recherche ou analyse des matériaux par l'utilisation de la résonance magnétique nucléaire, de la résonance paramagnétique électronique ou d'autres effets de spin en utilisant la résonance magnétique nucléaire
G01V 3/14 - Prospection ou détection électrique ou magnétique; Mesure des caractéristiques du champ magnétique de la terre, p.ex. de la déclinaison ou de la déviation fonctionnant par résonance magnétique électronique ou nucléaire
G01V 3/38 - Traitement de données, p.ex. pour l'analyse, pour l'interprétation ou pour la correction
G01R 33/44 - Dispositions ou appareils pour la mesure des grandeurs magnétiques faisant intervenir la résonance magnétique utilisant la résonance magnétique nucléaire [RMN]
G01R 33/34 - Systèmes d'excitation ou de détection, p.ex. utilisant des signaux radiofréquence - Détails de structure, p.ex. résonateurs
94.
Methods using advanced NMR analysis for core samples
A method for determining the fluid mobility of a core sample can include: determining a porosity of a core sample having a permeability of 10 mD or less; saturating the core sample with a NMR saturation fluid; taking a first NMR measurement of fluids in the core sample; diffusionally exchanging a hydrophobic fluid or a hydrophilic fluid in the core sample in a hydrophobic NMR exchange fluid or a hydrophilic NMR exchange fluid, respectively; taking a second NMR measurement of the fluid in the core sample after diffusional exchange; and deriving a property of the core sample based on the porosity, a NMR signal to fluid volume calibration, and a comparison between the first and the second NMR measurements, the property being selected from the group consisting of a mobile oil volume, an immobile hydrocarbon volume, a mobile water volume, an immobile water volume, and a combination thereof.
G01N 24/08 - Recherche ou analyse des matériaux par l'utilisation de la résonance magnétique nucléaire, de la résonance paramagnétique électronique ou d'autres effets de spin en utilisant la résonance magnétique nucléaire
G01V 3/14 - Prospection ou détection électrique ou magnétique; Mesure des caractéristiques du champ magnétique de la terre, p.ex. de la déclinaison ou de la déviation fonctionnant par résonance magnétique électronique ou nucléaire
G01V 3/38 - Traitement de données, p.ex. pour l'analyse, pour l'interprétation ou pour la correction
G01R 33/44 - Dispositions ou appareils pour la mesure des grandeurs magnétiques faisant intervenir la résonance magnétique utilisant la résonance magnétique nucléaire [RMN]
G01R 33/34 - Systèmes d'excitation ou de détection, p.ex. utilisant des signaux radiofréquence - Détails de structure, p.ex. résonateurs
95.
Hydrocarbon wells and methods of interrogating fluid flow within hydrocarbon wells
Hydrocarbon wells and methods of interrogating fluid flow within hydrocarbon wells. The hydrocarbon wells include a wellbore and downhole tubing that defines a tubing conduit and extends within the wellbore. The hydrocarbon wells also include an interrogation device. The interrogation device is configured to indicate at least one property of fluid flow within the hydrocarbon wells. The hydrocarbon wells also include a downhole location at which the interrogation device is released into the tubing conduit and a detection structure configured to query the interrogation device to determine the at least one property of fluid flow within the hydrocarbon wells. The methods include releasing an interrogation device at a downhole location within a hydrocarbon well and flowing the interrogation device from the downhole location to a surface region. The methods also include querying the interrogation device to determine at least one property of fluid flow within the hydrocarbon well.
E21B 47/10 - Localisation des fuites, intrusions ou mouvements du fluide
G01V 9/00 - Prospection ou détection par des procédés non prévus dans les groupes
G01V 11/00 - Prospection ou détection par des méthodes combinant des techniques spécifiées dans les groupes
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
The disclosure provides for an adsorbent bed assembly for separation of gaseous mixtures. The assembly includes a body defining an interior cavity. The body includes an outer shell, and first and second ends engaged with the outer shell that include inputs/outputs. A central support structure is positioned within the interior cavity and is engaged with the body or forms a portion thereof. Anti-telescoping devices are positioned about the central support structure, at least one of which is affixed to the central support structure. Each anti-telescoping device includes a plurality of spokes extending within the interior cavity from or proximate the central support structure towards the outer shell.
B01J 20/28 - Compositions absorbantes ou adsorbantes solides ou compositions facilitant la filtration; Absorbants ou adsorbants pour la chromatographie; Procédés pour leur préparation, régénération ou réactivation caractérisées par leur forme ou leurs propriétés physiques
B01D 53/04 - SÉPARATION Épuration chimique ou biologique des gaz résiduaires, p.ex. gaz d'échappement des moteurs à combustion, fumées, vapeurs, gaz de combustion ou aérosols par adsorption, p.ex. chromatographie préparatoire en phase gazeuse avec adsorbants fixes
A method and apparatus for identifying features of a subsurface region, including: obtaining an initial physical property model and survey data for the subsurface region; identifying a current model to be the initial physical property model; and executing one or more iterations of: generating synthetic data and forward wavefields with the current model and the survey data by forward modeling with forward wave equations representing isotropic wave-mode-independent attenuation; generating adjoint wavefields with the synthetic data and the survey data by adjoint modeling with adjoint wave equations representing isotropic wave-mode-independent attenuation; computing an objective function gradient with the forward wavefields and the adjoint wavefields by solving gradient equations with the corresponding wave equations representing isotropic wave-mode-independent attenuation; computing a search direction of the objective function; searching for a possible improved model along the search direction; and updating the current model to be the possible improved model.
Various embodiments described herein provide methods of hydrocarbon management and associated systems and/or computer readable media including executable instructions. Such methods (and by extension their associated systems and/or computer readable media for implementing such methods) may include obtaining geophysical data (e.g., seismic or other geophysical data) from a prospective subsurface formation (that is, a potential formation or other subsurface region of interest for any of various reasons, but in particular due to potential for production of hydrocarbons) and using a trained machine learning (ML) system for direct hydrocarbon indicators (DHI) analysis of the obtained geophysical data. Hydrocarbon management decisions may be guided by the DHI analysis.
G06F 16/9038 - Présentation des résultats des requêtes
G06F 16/9035 - Filtrage basé sur des données supplémentaires, p.ex. sur des profils d'utilisateurs ou de groupes
E21B 43/16 - Procédés de récupération assistée pour l'extraction d'hydrocarbures
G06K 9/62 - Méthodes ou dispositions pour la reconnaissance utilisant des moyens électroniques
E21B 49/08 - Prélèvement d'échantillons de fluides ou test des fluides dans les trous de forage ou dans les puits
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
99.
Direct hydrocarbon indicators analysis informed by machine learning processes
Various embodiments described herein provide methods of hydrocarbon management and associated systems and/or computer readable media including executable instructions. Such methods (and by extension their associated systems and/or computer readable media for implementing such methods) may include obtaining geophysical data (e.g., seismic or other geophysical data) from a prospective subsurface formation (that is, a potential formation or other subsurface region of interest for any of various reasons, but in particular due to potential for production of hydrocarbons) and using a trained machine learning (ML) system for direct hydrocarbon indicators (DHI) analysis of the obtained geophysical data. Hydrocarbon management decisions may be guided by the DHI analysis.
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
G06F 16/9038 - Présentation des résultats des requêtes
G06F 16/9035 - Filtrage basé sur des données supplémentaires, p.ex. sur des profils d'utilisateurs ou de groupes
E21B 43/16 - Procédés de récupération assistée pour l'extraction d'hydrocarbures
G06K 9/62 - Méthodes ou dispositions pour la reconnaissance utilisant des moyens électroniques
A method and apparatus for estimating RMO error, including obtaining input data comprising a domain of picking locations; running a plurality of residual moveout (RMO) error-picking algorithms with the input data; for each of the plurality of RMO error-picking algorithms, flattening gathers based on the respective RMO error-picking algorithms to generate a resultant error pick; comparing the resultant error picks from the plurality of RMO error-picking algorithms at each picking location in the domain of picking locations; and assembling a set of final RMO error picks from the resultant error picks from the plurality of RMO error-picking algorithms at each picking location.
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