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
4.
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
6.
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
7.
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
9.
System and Methods for Estimating Subsurface Horizontal Principal Stresses in Anisotropic Formations
A method for predicting a total minimum horizontal stress (σh) and a total maximum horizontal stress (σH) for an anisotropic formation may comprise: measuring Young's moduli parallel ±15° and perpendicular ±15° to a transverse isotropy plane of a horizontal core sample from the anisotropic subterranean formation; measuring Poisson's ratios parallel ±15° and perpendicular ±15° to the transverse isotropy plane of the horizontal core sample; inputting the measured Young's moduli and Poisson's ratios of the horizontal core sample into a 1-dimensional mechanical earth model (1-D MEM); and calculating, using the 1-D MEM, a predicted total minimum horizontal stress (σh) and a predicted total maximum horizontal stress (σH).
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 43/26 - Procédés pour activer la production par formation de crevasses ou de fractures
E21B 49/06 - Test pour déterminer la nature des parois des trous de forage; Essais de couches; Procédés ou appareils pour prélever des échantillons du terrain ou de fluides en provenance des puits, spécialement adaptés au forage du sol ou aux puits par prélèvements mécaniques d'échantillons du terrain au moyen d'outils de forage latéral ou de dispositifs de raclage
E21B 21/08 - Commande ou surveillance de la pression ou de l'écoulement du fluide de forage, p.ex. remplissage automatique des trous de forage, commande automatique de la pression au fond
10.
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
11.
Methods for In-Situ Application of a Coating Agent to Production Tubing Using a Plunger Lift System
Methods for the in-situ application of coating agent to production tubing within wellbores using plunger lift systems are provided herein. One method includes shutting in the wellbore, pressurizing the production tubing to displace fluids from the production tubing, and dropping a plunger from the surface into the production tubing such that the plunger travels toward the bottom of the production tubing until landing on a bumper spring. The method also includes pumping a predetermined amount of the coating agent from the surface into the production tubing such that the coating agent flows to the bottom of the production tubing and settles on top of the plunger and utilizing the differential pressure between the production tubing and the annulus to return the plunger and the coating agent to the surface, where the coating agent is applied to the inner diameter of the production tubing as it flows toward the surface.
E21B 37/06 - Procédés ou appareils pour nettoyer les trous de forage ou les puits utilisant des moyens chimiques pour empêcher ou limiter le dépôt de paraffine ou de substances analogues
E21B 43/12 - Procédés ou appareils pour commander l'écoulement du fluide extrait vers ou dans les puits
E21B 34/00 - Aménagements des vannes pour les trous de forage ou pour les puits
12.
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.
A plunger lift system, as well as a method for monitoring plunger parameters within a wellbore using such a plunger lift system, are provided. The plunger lift system includes a lubricator attached to a wellhead at the surface and a plunger dimensioned to travel through the production tubing upon being released from the lubricator. The plunger lift system also includes magnetic sensor systems installed along the production tubing, where each magnetic sensor system includes a magnetic sensor for detecting the passage of the plunger as it travels through the production tubing, as well a communication device for transmitting communication signals between the magnetic sensor systems and a computing system located at the surface, where the computing system includes a processor and a non-transitory, computer-readable storage medium including computer-executable instructions that direct the processor to dynamically determine the plunger position and/or velocity based on the received communication signals.
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 47/09 - Localisation ou détermination de la position d'objets dans les trous de forage ou dans les puits; Identification des parties libres ou bloquées des tubes
E21B 47/008 - Surveillance des systèmes de pompe de fond de trou, p.ex. pour la détection de conditions appelées "cognement sur le fluide"
E21B 43/12 - Procédés ou appareils pour commander l'écoulement du fluide extrait vers ou dans les puits
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.
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.
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
17.
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.
The hydrocarbon wells include a radioactive tracer system, a production conduit, a lift gas supply conduit, a lift gas supply system configured to provide a lift gas stream to the lift gas supply conduit, and one or more gas lift valves each being configured to selectively permit lift gas to enter the production conduit and mix with reservoir liquid therein to generate a produced fluid stream. The radioactive tracer system is configured to inject a radioactive tracer into the lift gas stream and to detect the radioactive tracer within the produced fluid stream. The methods include injecting the radioactive tracer into the lift gas stream, flowing the radioactive tracer through an open gas lift valve into the production conduit, mixing the radioactive tracer with the reservoir liquid to generate a tracer-marked liquid band within the produced fluid stream, and detecting radiation from the tracer-marked liquid band.
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
20.
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 system is provided with a turbine combustor having a first diffusion fuel nozzle, wherein the first diffusion fuel nozzle is configured to produce a diffusion flame. The system includes a turbine driven by combustion products from the diffusion flame in the turbine combustor. The system also includes an exhaust gas compressor, wherein the exhaust gas compressor is configured to compress and route an exhaust gas from the turbine to the turbine combustor along an exhaust recirculation path. In addition, the system includes a control system configured to control flow rates of at least one oxidant and at least one fuel to the turbine combustor in a stoichiometric control mode and a non-stoichiometric control mode, wherein the stoichiometric control mode is configured to change the flow rates and provide a substantially stoichiometric ratio of the at least one fuel with the at least one oxidant, and the non-stoichiometric control mode is configured to change the flow rates and provide a non-stoichiometric ratio of the at least one fuel with the at least one oxidant.
F02C 3/34 - Ensembles fonctionnels de turbines à gaz caractérisés par l'utilisation de produits de combustion comme fluide de travail avec recyclage d'une partie du fluide de travail, c. à d. cycles semi-fermés comportant des produits de combustion dans la partie fermée du cycle
F02C 3/30 - Addition d'eau, de vapeur ou d'autres fluides aux composants combustibles ou au fluide de travail avant l'échappement de la turbine
F23R 3/34 - Alimentation de différentes zones de combustion
F02C 7/228 - Division du fluide entre plusieurs brûleurs
F02C 9/34 - Commande combinée des débits des alimentations séparées des brûleurs principaux et secondaires
F23R 3/28 - Chambres de combustion à combustion continue utilisant des combustibles liquides ou gazeux caractérisées par l'alimentation en combustible
24.
Riserless offshore production and storage system and related methods
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
25.
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.
Provided are apparatus and systems for performing a swing adsorption process. This swing adsorption process may involve performing dampening for fluctuations in the streams conducted away from the adsorbent bed unit. The process may be utilized for swing adsorption processes, such as rapid cycle TSA and/or rapid cycle PSA, which are utilized to remove one or more contaminants from a gaseous feed stream.
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
C10L 3/10 - Post-traitement de gaz naturel ou de gaz naturel de synthèse
B01D 53/02 - 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
27.
Method and System for Efficient Nonsynchronous LNG Production using Large Scale Multi-Shaft Gas Turbines
A drive system for liquefied natural gas (LNG) refrigeration compressors in a LNG liquefaction plant. Each of three refrigeration compression strings include refrigeration compressors and a multi-shaft gas turbine capable of non-synchronous operation. The multi-shaft gas turbine is operationally connected to the refrigeration compressors and is configured to drive the one or more refrigeration compressors. The multi-shaft gas turbine uses its inherent speed turndown range to start the one or more refrigeration compressors from rest, bring the one or more refrigeration compressors up to an operating rotational speed, and adjust compressor operating points to maximize efficiency of the one or more refrigeration compressors, without assistance from electrical motors with drive-through capability and variable frequency drives.
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
F02C 7/277 - Entraînement du rotor pour le démarrage mécanique par une turbine
F25J 1/00 - Procédés ou appareils de liquéfaction ou de solidification des gaz ou des mélanges gazeux
A method and apparatus for liquefying a feed gas stream comprising natural gas and carbon dioxide. A method includes compressing an input fluid stream to generate a first intermediary fluid stream; cooling the first intermediary fluid stream with a first heat exchanger to generate a second intermediary fluid stream, wherein a temperature of the second intermediary fluid stream is higher than a carbon dioxide-freezing temperature for the second intermediary fluid stream; expanding the second intermediary fluid stream to generate a third intermediary fluid stream, wherein the third intermediary fluid stream comprises solid carbon dioxide; separating the third intermediary fluid stream into a fourth intermediary fluid stream and an output fluid stream, wherein the output fluid stream comprises a liquefied natural gas (LNG) liquid; and utilizing the fourth intermediary fluid stream as a cooling fluid stream for the first heat exchanger.
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
F25J 3/02 - Procédés ou appareils pour séparer les constituants des mélanges gazeux impliquant l'emploi d'une liquéfaction ou d'une solidification par rectification, c. à d. par échange continuel de chaleur et de matière entre un courant de vapeur et un courant de liquide
29.
Identifying Downhole Conditions During A Drilling Operation Using A Vibratory Separator
Techniques described herein relate to a method for identifying downhole conditions during a drilling operation using a vibratory separator. The method includes calibrating a sensor system attached to the vibratory separator by periodically measuring the G-force acting on the vibratory separator functioning under steady-state operating parameters. The method also includes determining the relationship between the G-force acting on the vibratory separator and the flow rate and rate of penetration (ROP) for the drilling operation by measuring the G-force acting on the vibratory separator functioning under different non-steady-state operating parameters. The method further includes determining an expected total basket weight for each G-force measurement using the G-force/flow rate/ROP relationship, monitoring a current total basket weight of the vibratory separator functioning under current operating parameters, and identifying a downhole condition if the current total basket weight is greater or less than the expected total basket weight for the current operating parameters.
E21B 21/08 - Commande ou surveillance de la pression ou de l'écoulement du fluide de forage, p.ex. remplissage automatique des trous de forage, commande automatique de la pression au fond
E21B 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 21/00 - Procédés ou appareils pour nettoyer les trous de forage par jet de fluide, p.ex. en utilisant l'air d'échappement du moteur
E21B 27/00 - Récipients pour ramasser ou déposer des substances dans les trous de forage ou les puits, p.ex. cuillers pour ramasser de la boue ou du sable; Trépans comportant des moyens pour ramasser des substances, p.ex trépans à clapet
30.
Capacitive Cable for a Downhole Electro-Hydraulic Tool
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.
A method and system for liquefying a methane-rich high-pressure feed gas stream using a first heat exchanger zone and a second heat exchanger zone. The feed gas stream is mixed with a refrigerant stream to form a second gas stream, which is compressed, cooled, and directed to a second heat exchanger zone to be additionally cooled below ambient temperature. It is then expanded to a pressure less than 2,000 psia and no greater than the pressure to which the second gas stream was compressed, and then separated into a first expanded refrigerant stream and a chilled gas stream. The first expanded refrigerant stream is expanded and then passed through the first heat exchanger zone such that it has a temperature that is cooler, by at least 5° F., than the highest fluid temperature within the first heat exchanger zone.
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
33.
Methods and Systems of Creating Fractures in a Subsurface Formation
Methods and systems for creating fractures in rock are disclosed herein. In an exemplary method, reactive fluid is delivered into a wellbore. Formation fracture pressure is added to the reactive fluid in the wellbore sufficient to create a fracture network in a formation. The reaction pressure rubblizes the portion of a rock face of the fracture wall face to generate propping rubble that props the fracture open.
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
35.
Systems and Methods for Predicting the Composition of Petroleum Hydrocarbons
A quantitative simulation process for producing quantitative model predictions of hydrocarbon composition may comprise: measuring a chemical and isotopic composition of a hydrocarbon sample from a hydrocarbon reservoir; measuring geochemical data, geophysical data, and/or geological data for the hydrocarbon reservoir and/or source rock; deriving temperature versus time relationships from a basin model for the hydrocarbon reservoir and/or source rock based on the geochemical data, geophysical data, and/or geological data; generating estimated source-rock maturity parameters based on the temperature versus time relationships; generating an estimated compositional yield for hydrocarbon fractions based on the temperature versus time relationships and the chemical composition of the hydrocarbon sample; and generating, using a mass-conserving isotopic fraction (MCIF) simulator, an estimated isotopic composition of the hydrocarbon fractions based on the estimated compositional yield and the isotopic composition of the hydrocarbon sample.
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
37.
Non-Intrusive Detection of Pipe Parameters Using Selected Guided Acoustic Wave Modes
Methods and systems for measuring pipe parameters using guided acoustic wave modes are provided. The method includes receiving data corresponding to an acoustic signal, wherein the data are obtained by transmitting an excitation pulse at a specified frequency and detecting the resulting acoustic signal using an acoustic transducer attached to the outer surface of the pipe wall. The method includes analyzing the data to identify guided acoustic wave modes including at least two of: a C-SH acoustic wave mode that travels within the pipe wall; a C-LT acoustic wave mode that travels within the near-surface region of the pipe wall; and/or a CA acoustic wave mode that travels within the pipe cavity. The method includes calibrating the parameter measurement using the C-SH acoustic wave mode and determining the parameter measurement based on the phase velocity and/or the amplitude of the C-LT acoustic wave mode and/or the CA acoustic wave mode.
G01N 29/22 - Recherche ou analyse des matériaux par l'emploi d'ondes ultrasonores, sonores ou infrasonores; Visualisation de l'intérieur d'objets par transmission d'ondes ultrasonores ou sonores à travers l'objet - Détails
G01F 1/74 - Dispositifs pour la mesure du débit d'un matériau fluide ou du débit d'un matériau solide fluent en suspension dans un autre fluide
G01F 1/66 - Mesure du débit volumétrique ou du débit massique d'un fluide ou d'un matériau solide fluent, dans laquelle le fluide passe à travers un compteur par un écoulement continu en mesurant la fréquence, le déphasage, le temps de propagation d'ondes électromagnétiques ou d'autres types d'ondes, p.ex. en utilisant des débitmètres à ultrasons
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.
A system and method for producing liquefied natural gas (LNG) from a natural gas stream. Each of a plurality of LNG trains liquefies a portion of the natural gas stream to generate a warm LNG stream in a first operating mode, and a cold LNG stream in a second operating mode. A sub-cooling unit is configured to, in the first operating mode, sub-cool the warm LNG streams to thereby generate a combined cold LNG stream. The warm LNG streams have a higher temperature than a temperature of the cold LNG streams in the second operating mode and the combined cold LNG stream. The combined cold LNG stream has, in the first operating mode, a higher flow rate than the flow rate of the cold LNG streams in the second operating mode.
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
Methods for identifying hydrocarbon contamination sources may include fingerprinting hydrocarbons using isotopocule analyses for BTEX compounds. For example, methods for identifying hydrocarbon contamination sources may comprise: extracting BTEX compounds from a sample; measuring the isotopocule composition of the BTEX compounds; and determining a characteristic of the sample based on the isotopocule composition. Such characteristics may include, but are not limited to, the characteristic of the sample comprises one or more selected from the group consisting of: a source of the sample, a condition at which the sample formed or was last equilibrated, a migration time from a source to a sample location, weathering of the sample, and degree to which the sample is anthropogenic and naturally-occurring.
G01N 21/39 - Couleur; Propriétés spectrales, c. à d. comparaison de l'effet du matériau sur la lumière pour plusieurs longueurs d'ondes ou plusieurs bandes de longueurs d'ondes différentes en recherchant l'effet relatif du matériau pour les longueurs d'ondes caractéristiques d'éléments ou de molécules spécifiques, p.ex. spectrométrie d'absorption atomique en utilisant des lasers à longueur d'onde réglable
G01N 27/62 - Recherche ou analyse des matériaux par l'emploi de moyens électriques, électrochimiques ou magnétiques en recherchant les décharges électriques, p.ex. l'émission cathodique
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
42.
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.
Described herein are systems and processes of removing contaminants in a liquid nitrogen (LIN) stream used to produce liquefied natural gas (LNG). Greenhouse gas contaminants are removed from the LIN using a greenhouse gas removal unit. The LNG is compressed prior to being cooled by the LIN.
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
F25J 3/02 - Procédés ou appareils pour séparer les constituants des mélanges gazeux impliquant l'emploi d'une liquéfaction ou d'une solidification par rectification, c. à d. par échange continuel de chaleur et de matière entre un courant de vapeur et un courant de liquide
F25J 3/08 - Séparation des impuretés gazeuses des gaz ou des mélanges gazeux
46.
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
48.
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
49.
Methodology for Enhancing Properties of Geophysical Data with Deep Learning Networks
A method for enhancing properties of geophysical data with deep learning networks. Geophysical data may be acquired by positioning a source of sound waves at a chosen shot location, and measuring back-scattered energy generated by the source using receivers placed at selected locations. For example, seismic data may be collected using towed streamer acquisition in order to derive subsurface properties or to form images of the subsurface. However, towed streamer data may be deficient in one or more properties (e.g., at low frequencies). To compensate for the deficiencies, another survey (such as an Ocean Bottom Nodes (OBN) survey) may be sparsely acquired in order to train a neural network. The trained neural network may then be used to compensate for the towed streamer deficient properties, such as by using the trained neural network to extend the towed streamer data to the low frequencies.
G01V 1/36 - Exécution de corrections statiques ou dynamiques sur des enregistrements, p.ex. correction de l'étalement; Etablissement d'une corrélation entre signaux sismiques; Elimination des effets produits par un excès d'énergie
G01V 1/38 - Séismologie; Prospection ou détection sismique ou acoustique spécialement adaptées aux zones recouvertes d'eau
A method of attenuating annular pressure buildup within a wellbore. The method includes accessing a wellbore, with the wellbore having an annulus disposed between first and second strings of casing. The method also includes placing a column of cement around the second string of casing generally below the first string of casing. The method further includes pumping a fluid mixture into the annulus, forming a fluid column. The fluid mixture comprises a carrier fluid, and a plurality of compressible particles dispersed in the carrier fluid. Each of the compressible particles is fabricated to partially collapse in response to thermal expansion of the fluid mixture. The method also includes placing a wellhead over the wellbore, thereby forming a trapped annulus in the wellbore. The method additionally includes at least partially sealing the annular region along at least one depth above the column of cement to inhibit vertical migration of the compressible particles.
F16F 9/00 - Ressorts, amortisseurs de vibrations, amortisseurs de chocs ou amortisseurs de mouvement de structure similaire, utilisant un fluide ou moyen équivalent comme agent d'amortissement
F16L 57/02 - Protection des tuyaux ou d'objets de forme similaire contre les dommages ou les usures internes ou externes contre la fissuration ou le flambement
51.
GENERATING TUBE WAVES WITHIN A WELLBORE USING AN ELECTROHYDRAULIC DISCHARGE SOURCE
Techniques described herein relate to a hydrocarbon well, a system, and a method for collecting data relating to characteristics of a wellbore by generating tube waves within the wellbore using an electro-hydraulic discharge (EHD) source. The method includes generating tube waves that propagate within a fluid column of a wellbore using an EHD source, wherein the fluid column is defined by a casing string within the wellbore. The method also includes allowing at least a portion of the generated tube waves to interact with acoustic impedance boundaries that act as reflectors within the wellbore, creating reflected tube waves that propagate within the fluid column. The method further includes recording data corresponding to the generated tube waves and the reflected tube waves using a receiver, wherein the recorded data relate to characteristics of the reflectors within the wellbore.
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 43/26 - Procédés pour activer la production par formation de crevasses ou de fractures
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
53.
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.
Velocity tomography using time lags of wave equation migration is disclosed. Seismic tomography is a technique for imaging the subsurface of the Earth with seismic waves by generated a migration velocity model from a multitude of observations using combinations of source and receiver locations. The migration velocity model may be updated in order to reduce depth differences of reflection events (also called residual depth errors (RDE)). Direct measurement of RDE may be difficult in certain complex subsurface areas. In such areas, the RDE may be reconstructed based on time lags of wave equation migration and then used to update the migration velocity model. In particular, the RDE may be directly reconstructed from the time lags of wave equation migration, such as based on a direct relation between RDE and the time lags.
G01V 1/36 - Exécution de corrections statiques ou dynamiques sur des enregistrements, p.ex. correction de l'étalement; Etablissement d'une corrélation entre signaux sismiques; Elimination des effets produits par un excès d'énergie
G01V 1/34 - 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
56.
Method and System for Performing Communications During Cementing Operations
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
57.
Method For Partitioning A Search Direction When Using Least Squares Reverse Time Migration
A method for partitioning a search direction when using least squares reverse time migration (LSRTM) is provided. LSRTM may be used iteratively in order to improve imaging accuracy. As part of LSRTM, multiple local line searches may be performed. In particular, image space may be partitioned, such as by using a set of masks. The search direction, such as the gradient, may be partitioned using the set of masks. Local line searches may be performed for each partition of the search direction, resulting in finding respective line search constants. The respective line search constants may then be used for iterating the model in order to improve imaging accuracy.
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
59.
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
61.
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]
64.
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
Geologic modeling methods and systems may use design-space to design-space mapping to facilitate simulation grid generation for multiple interpretations of a subsurface region. As one example, one or more embodiments of a geologic modeling method may comprise: obtaining first and second geologic models having different structural interpretations of a subsurface region; mapping each of the geologic models to associated design space models representing an unfaulted subsurface region; determining a design-to-design space mapping from the first design space model to the second design space model; using said mapping to copy parameter values from the first design space model to the second of the design space model; gridding each of the design space models to obtain design space meshes; partitioning cells in the first and second design space meshes along faults; reverse mapping the partitioned design space meshes to the physical space to obtain first and second physical space simulation meshes.
A method for partitioning NMR T1-T2 data may comprise: identifying modes in NMR T1-T2 data from a plurality of samples with a multimodal deconvolution or decomposition with regularized nonlinear inversion; deriving a modal properties vector comprising modal properties for each of the modes; performing a cluster analysis of the modes to identify clusters; assigning a poro-fluid class to the clusters based on one or more of the modal properties of the modes in each of the clusters; and deriving partitioned representations for the clusters based on the cluster analysis.
E21B 49/08 - Prélèvement d'échantillons de fluides ou test des fluides dans les trous de forage ou dans les puits
G01N 24/08 - Recherche ou analyse des matériaux par l'utilisation de la résonance magnétique nucléaire, de la résonance paramagnétique électronique ou d'autres effets de spin en utilisant la résonance magnétique nucléaire
G01V 3/32 - Prospection ou détection électrique ou magnétique; Mesure des caractéristiques du champ magnétique de la terre, p.ex. de la déclinaison ou de la déviation spécialement adaptée au carottage fonctionnant par résonance magnétique électronique ou nucléaire
G01V 3/38 - Traitement de données, p.ex. pour l'analyse, pour l'interprétation ou pour la correction
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
67.
Method of Supplying LNG From A Supply Hub Using A Dual Purpose LNG Carrier And A Smaller-Volume Storage At A Receiving Terminal
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.
Methods and systems for cryogenically separating contaminants and regasification of LNG utilizing common refrigeration equipment and/or fuel. An integrated system includes: a component for separating contaminants from an input feed stream; a heat exchanger coupled to a first line, wherein: the first line is coupled to the component for separating contaminants, and the heat exchanger cools a first feed stream of the first line; and a LNG regasification system comprising a vaporizer, wherein: the vaporizer heats a LNG stream of the LNG regasification system, and the heat exchanger functions as the vaporizer. A process includes: separating contaminants from an input feed stream with a component for separating contaminants; cooling a first feed stream with a heat exchanger, wherein the heat exchanger is coupled to the component for separating contaminants; and heating a LNG stream with a vaporizer of a LNG regasification system, wherein the heat exchanger functions as the vaporizer.
F25J 1/00 - Procédés ou appareils de liquéfaction ou de solidification des gaz ou des mélanges gazeux
69.
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
70.
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.
Hydrocarbon wells and methods of probing a subsurface region of the hydrocarbon wells. The hydrocarbon wells include a wellbore, a downhole sensor storage structure, and a detection structure. The wellbore may extend within a subsurface region and between a surface region and a downhole end region. The downhole sensor storage structure is configured to release a flowable sensor into a wellbore fluid that extends within the wellbore, and the flowable sensor may be configured to collect sensor data indicative of at least one property of the subsurface region. The detection structure may be configured to query the flowable sensor to determine the at least one property of the subsurface region. The methods include releasing a flowable sensor, collecting sensor data with the flowable sensor, and querying the flowable sensor.
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 47/01 - 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
E21B 49/08 - Prélèvement d'échantillons de fluides ou test des fluides dans les trous de forage ou dans les puits
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.
A remote survey system includes an unmanned surface vehicle that includes a body, a propulsion system coupled to the body to provide mobility to the unmanned surface vehicle to traverse a surface of a waterbody, and a thickness detection assembly mounted to a hull of the body and including one or more thickness detection cameras. A central computer system is located at a command center and in wireless communication with the unmanned surface vehicle via a communication module. The one or more thickness detection cameras are positioned to obtain one or more images or videos of an air-oil-water interface on the surface of the waterbody, and a thickness of a released substance present on the surface of the waterbody is determined based on the one or more images or videos of the air-oil-water interface.
B63B 35/32 - Embarcations ou structures flottantes similaires spécialement adaptées à des finalités spécifiques et non prévues ailleurs pour le ramassage des matières polluantes au large
B64C 39/02 - Aéronefs non prévus ailleurs caractérisés par un emploi spécial
H04W 4/40 - Services spécialement adaptés à des environnements, à des situations ou à des fins spécifiques pour les véhicules, p.ex. communication véhicule-piétons
79.
Magnetorheological Dampener System for Protecting Well Equipment
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
80.
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]
81.
Pretreatment and Pre-Cooling of Natural Gas by High Pressure Compression and Expansion
A method and apparatus for producing liquefied natural gas. A portion of a natural gas stream is cooled in a heat exchanger and combined with the natural gas stream. Heavy hydrocarbons are removed from the combined natural gas stream, and the resulting separated natural gas stream is partially condensed in the first heat exchanger, with a liquid stream separated therefrom. The natural gas stream is warmed in the first heat exchanger and then is compressed and cooled. The resultant cooled compressed natural gas stream is expanded, thereby forming a chilled natural gas stream that is separated into a refrigerant stream and a non-refrigerant stream. The refrigerant stream recycled to the heat exchanger to be warmed through heat exchange with one or more process streams associated with pretreating the natural gas stream, thereby generating a warmed refrigerant stream. The warmed refrigerant stream and the non-refrigerant stream are liquefied.
B01D 1/28 - SÉPARATION Évaporation avec compression de vapeur
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
82.
CARGO STRIPPING FEATURES FOR DUAL-PURPOSE CRYOGENIC TANKS ON SHIPS OR FLOATING STORAGE UNITS FOR LNG AND LIQUID NITROGEN
An apparatus and method of storing and transporting, in a dual-use cryogenic storage tank, a cryogenic liquid having a liquefaction temperature. A first pump empties the tank of a first portion of the cryogenic liquid, thereby leaving a second portion of the cryogenic liquid in the cryogenic storage tank. A second portion of the cryogenic liquid is focused at a location on a bottom of the cryogenic storage tank. Using a second pump located at the location, the cryogenic storage tank is emptied of the second portion of the cryogenic liquid, whereby a residual portion of the cryogenic liquid is left therein. Using a focused heating structure, heat may be delivered to the location to raise the temperature of the residual portion above the liquefaction temperature, thereby vaporizing all of the residual portion.
F17C 7/04 - Vidage des gaz liquéfiés avec changement d'état, p.ex. vaporisation
F04B 15/08 - Pompes adaptées pour travailler avec des fluides particuliers, p.ex. grâce à l'emploi de matériaux spécifiés pour la pompe elle-même ou certaines de ses parties avec des liquides près de leur point d'ébullition, p.ex. à une pression anormalement basse les liquides ayant une température d'ébullition peu élevée
F17C 6/00 - Procédés ou appareils pour remplir des récipients non sous pression de gaz liquéfiés ou solidifiés
83.
Hydrocarbon Wells and Methods for Monitoring Fracture Morphology of a Fracture that Exends from a Wellbore of the Hydrocarbon Wells
Hydrocarbon wells and methods for monitoring fracture morphology of a fracture that extends from a wellbore of the hydrocarbon wells are disclosed herein. The hydrocarbon wells include a wellbore, a fracture that extends from the wellbore, and an electromagnetic contrast material positioned within the fracture. The hydrocarbon wells also include a downhole electromagnetic transmitter, which is configured to direct an electromagnetic probe signal incident upon the electromagnetic contrast material, and a downhole electromagnetic receiver, which is configured to receive an electromagnetic resultant signal from the electromagnetic contrast material. The methods include flowing an electromagnetic contrast material into a fracture and generating an electromagnetic probe signal. The methods also include modifying the electromagnetic probe signal with the electromagnetic contrast material to generate an electromagnetic resultant signal. The methods further include receiving the electromagnetic resultant signal and determining the morphology of the fracture.
G01V 3/30 - Prospection ou détection électrique ou magnétique; Mesure des caractéristiques du champ magnétique de la terre, p.ex. de la déclinaison ou de la déviation spécialement adaptée au carottage fonctionnant au moyen d'ondes électromagnétiques
E21B 43/26 - Procédés pour activer la production par formation de crevasses ou de fractures
E21B 47/002 - Relevés dans les trous de forage ou dans les puits par inspection visuelle
E21B 43/14 - Extraction d'un puits à horizons multiples
84.
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
85.
Pretreatment and Pre-Cooling of Natural Gas by High Pressure Compression and Expansion
A method and apparatus for producing liquefied natural gas. A portion of a natural gas stream is cooled in a first heat exchanger and re-combined with the natural gas stream, and heavy hydrocarbons are removed therefrom to generate a separated natural gas stream and a separator bottom stream. Liquids are separated from the separator bottom stream to form an overhead stream, which is cooled and separated to form a recycle gas stream. The recycle gas stream is compressed. A first portion of the compressed recycle gas stream is directed through the first heat exchanger and directed to the separator as a column reflux stream. The separated to natural gas stream is used as a coolant in the first heat exchanger to thereby generate a pretreated natural gas stream, which is compressed and liquefied.
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
86.
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
Methods and systems for optimizing timing for drilling and tripping operation. An example method may include receiving a plurality of sensor data characterizing rig equipment and tripping status. The method may include identifying a plurality of multi-thread rig states based on the plurality of sensor data. The method calculates a plurality of optimal rig state characteristics (RSCs), wherein the plurality of optimal RSCs are calculated based on the plurality of sensor data as it relates to the plurality of multi-thread rig states. The method also performs a tripping operation with the rig equipment after applying the plurality of optimal RSCs. The method may also gather a plurality of updated sensor data from the rig equipment during the tripping operation for a recalculation of the plurality of optimal RSCs.
E21B 3/02 - Moyens d'entraînement de surface pour forage par rotation
E21B 19/14 - Râteliers, rampes, gouttières ou casiers pour contenir les éléments de tige isolés ou assemblés; Manipulation entre l'aire de stockage et le trou de forage
E21B 19/16 - Branchement ou débranchement des accouplements de tubes ou de joints
91.
Age Differentiation of Late Cretaceous-Tertiary Sourced Oils
An angiosperm index-1 and an angiosperm index-2 are correlated to an age of a liquid hydrocarbon sample and can be used to distinguish oil age of Late Cretaceous (100-65 million years before present, or 100-65 Ma BP) vs. Paleogene (65-55 Ma BP) vs. Eocene or younger (<55 Ma BP). This method improves over existing methods that cannot distinguish oil age between Late Cretaceous and Miocene (ca. 100-5 Ma BP).
G06Q 10/06 - Ressources, gestion de tâches, des ressources humaines ou de projets; Planification d’entreprise ou d’organisation; Modélisation d’entreprise ou d’organisation
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
93.
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
95.
APPARATUS AND METHOD FOR DETECTING AND SAMPLING DISSOLVED HYDROCARBONS
Detection and sampling of dissolved hydrocarbons of interest in an environment expected to have hydrocarbon molecules, such as a water column or interstitial water in sediment. An apparatus comprising at least one oleophilic film frame is deployed into the environment and the at least one oleophilic film frame is exposed thereto for a defined period of time, and thereafter isolated from the environment to cease exposure thereto. Hydrocarbon molecules scavenged by the oleophilic film may be analyzed to determine their type and/or concentration.
C12P 3/00 - Préparation d'éléments ou de composés inorganiques à l'exception du dioxyde de carbone
C10L 3/10 - Post-traitement de gaz naturel ou de gaz naturel de synthèse
C01B 17/05 - Préparation du soufre; Purification à partir de composés sulfurés gazeux, y compris les sulfures gazeux par des procédés humides
C01B 17/04 - Préparation du soufre; Purification à partir de composés sulfurés gazeux, y compris les sulfures gazeux
B01D 53/14 - SÉPARATION Épuration chimique ou biologique des gaz résiduaires, p.ex. gaz d'échappement des moteurs à combustion, fumées, vapeurs, gaz de combustion ou aérosols par absorption
B01D 53/18 - Unités d'absorption; Distributeurs de liquides
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
100.
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.
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