A wellhead is associated with and fluidly connected to a density sensor and a fluid directing manifold. The manifold is configured to direct the production fluids from a wellhead to one of a plurality of production lines in order to reduce mixing of solvent-rich and solvent-lean streams and, therefore, decrease the likelihood of production fluid phase splitting. In some embodiments, a density of the production fluid is measured by the density sensor and the fluid directing manifold directs the production fluid to a particular production line based on the measured density which may be correlated to the solvent fraction of the production fluid.
An outlet nozzle for a fluid-solid processing unit, the outlet nozzle comprising: a mouth base for attachment to a wall of the unit at an outlet of the unit; and a mouth extending from the mouth base into the unit, wherein at least a portion of the mouth is flared such that an inner diameter of the mouth increases into the unit. In one application, the outlet nozzle may be used to withdraw coarse sand tailings (CST) from a gravity separation vessel for separating a bitumen slurry.
A valve assembly (100) that provides for reduced pressure loss in a downhole positive displacement pump comprises: a cylindrical body (110) comprising a cage, with the cage having an upper end (112), a lower end (114) and a tubular side wall (111) forming an axial bore; a ball (115) residing within the cage; two or more ball guides (113) configured to keep the ball generally along a centerline of the cage; a cone (116) concentrically residing within the cage above a position where the ball stops in an open position; a ball stop (117) residing within the cage and preventing the ball from rising to an upper end of the cone when the ball moves to an open position; and a seat (118) residing below the cage, wherein the seat sealingly receives the ball when the ball falls to the bottom of the cage, but permits fluids to flow through the seat and around the ball when the ball floats off the seat and into its open position.
A method and system are described for monitoring post-stimulation operations using a plurality of communication nodes disposed along tubular members in a wellbore. The method includes constructing a communication network and installing the communication nodes along the tubular members. The communication nodes are used to monitor for the presence and/or quantity of solids and/or fluids associated with post-stimulation operations in the tubular members by analyzing how the contents of the tubular members acoustically affect the signals transmitted between the communication nodes. Hydrocarbon operations may be modified based on the analysis.
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 47/00 - Relevés dans les trous de forage ou dans les puits
A method and system are described for communicating within a system, which includes a plurality of communication nodes disposed along tubular members in a wellbore. The method includes constructing a communication network and installing the communication nodes along the tubular members. The communication nodes are used to monitor for the presence and/or quantity of sand in the tubular members by analyzing how the contents of the tubular members acoustically affect the signals transmitted between the communication nodes.
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 47/00 - Relevés dans les trous de forage ou dans les puits
6.
CARBON DIOXIDE REMOVAL FROM PRODUCED GASES OF HEAVY OIL IN SITU RECOVERY PROCESSES USING AMINE EXTRACTION
A method for carbon dioxide removal from produced gas in heavy oil in situ (HOIS) recovery processes may comprise: performing the HOIS recovery process on a heavy oil to yield water, heavy oil, fines, and produced gas, wherein the produced gas comprises light hydrocarbons, carbon dioxide, and optionally hydrogen sulfide; separating the produced gas from the water, the heavy oil, and the fines; and exposing the produced gas to an amine to yield a hydrocarbon-enriched gas and a spent amine.
A method for carbon dioxide removal, and optionally additionally hydrogen sulfide removal, from produced gas in heavy oil in situ (HOIS) recovery processes using the produced water may comprise: performing the HOIS recovery process on a heavy oil to yield water, heavy oil, fines, and produced gas, wherein the produced gas comprises light hydrocarbons, carbon dioxide, and optionally hydrogen sulfide; separating the produced gas from the water, the heavy oil, and the fines; compressing the produced gas to yield a compressed produced gas; mixing the compressed produced gas with an absorption water to yield a mixture; cooling the mixture to yield a cooled mixture; separating the cooled mixture into (a) a carbonated water stream comprising the carbon dioxide and optionally the hydrogen sulfide dissolved in the absorption water each at a higher concentration than in the absorption water and (b) one or more hydrocarbon streams.
E21B 43/34 - Aménagements pour séparer les matériaux produits par le puits
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
Disclosed is a method comprising: (a) providing a slurry comprising a fluid and solids; (b) removing a slip stream from the slurry, wherein the slip stream is a non-representative sample; (c) measuring, directly or indirectly, a fluid flow rate in the slip stream; (d) measuring, directly or indirectly, a fluid flow rate in the slurry; (e) measuring, directly or indirectly, a flow rate of a particle of interest in the slip stream; and (f) converting, using (c), (d) and (e), the flow rate of the particle of interest in the slip stream to a flow rate of a particle of interest in the slurry.
A side pocket mandrel, including defining a tubular body having opposing ends and a bore formed within the tubular body. The tubular body comprises an eccentric portion such that a first inner diameter (ID1) is formed at the opposing upper and lower ends, and a second larger inner diameter (ID2) is formed along an eccentric portion. The mandrel includes a movable curtain disposed along the eccentric portion, wherein in a first position the movable curtain covers a portion of the eccentric portion above the pocket to provide a reduced inner diameter that approximates (ID1), and in a second position the curtain is movable to a larger inner diameter (ID2) that enables access by a kick-over tool to install a gas lift valve in or to retrieve the gas lift from the pocket. A method of producing hydrocarbon fluids is also provided.
E21B 43/12 - Procédés ou appareils pour commander l'écoulement du fluide extrait vers ou dans les puits
F04B 47/12 - Pompes ou installations de pompage spécialement adaptées pour élever un fluide à partir d'une grande profondeur, p.ex. pompes de puits élevant le fluide à pomper jusqu'à la surface au moyen d'un piston libre
A pump includes a solid state pump including a solid state actuator actuatable to pressurize a hydraulic fluid, and a secondary pump in fluid communication with the solid state pump via a fluid circuit. The secondary pump is actuatable with the hydraulic fluid received from the solid state pump, and actuating the secondary pump draws in an external fluid into the secondary pump, pressurizes the external fluid within the secondary pump, and discharges a pressurized external fluid.
F04B 47/00 - Pompes ou installations de pompage spécialement adaptées pour élever un fluide à partir d'une grande profondeur, p.ex. pompes de puits
E21B 43/12 - Procédés ou appareils pour commander l'écoulement du fluide extrait vers ou dans les puits
F04B 17/00 - Pompes caractérisées par leur combinaison avec des machines motrices ou moteurs particuliers qui les entraînent ou par leur adaptation à ceux-ci
F04B 35/02 - Pompes à piston spécialement adaptées aux fluides compressibles et caractérisées par les moyens d'entraînement de leurs organes de travail ou par leur combinaison avec les machines motrices ou moteurs qui les entraînent ou bien par leurs adaptations les moyens étant fluides
F04B 35/04 - Pompes à piston spécialement adaptées aux fluides compressibles et caractérisées par les moyens d'entraînement de leurs organes de travail ou par leur combinaison avec les machines motrices ou moteurs qui les entraînent ou bien par leurs adaptations les moyens étant 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
Methods and systems for monitoring operation integrity during hydrocarbon production or fluid injection operations by receiving microseismic data; processing the microseismic data to obtain a plurality of data panels corresponding to microseismic data measured over a predetermined time interval; calculating, for each data panel, trigger values for data traces corresponding to sensor receivers of the microseismic monitoring system; selecting, as a triggered data panel, at least one data panel that satisfies predetermined triggering criteria; selecting, as a non-trivial data panel, at least one triggered data panel that satisfies spectral density criteria; calculating a value for each of at least two event attributes of a plurality of event attributes of the event; determining an event score based on the values of the plurality of event attributes; and classifying the event into at least one event category of a plurality of event categories based on the event score.
A method for producing liquefied natural gas (LNG) from a natural gas stream having a nitrogen concentration of greater than 1 mol%. At least one liquid nitrogen (LIN) stream is received at an LNG liquefaction facility. The LIN streams may be produced at a different geographic location from the LNG liquefaction facility. A natural gas stream is liquefied by indirect heat exchange with a nitrogen vent stream to form a pressurized LNG stream. The pressurized LNG stream has a nitrogen concentration of greater than 1 mol%. The pressurized LNG stream is directed to one or more stages of a column to produce an LNG stream and the nitrogen vent stream. The column has upper stages and lower stages. The LIN streams are directed to one or more upper stages of the column.
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
13.
SUPPLEMENTARY CHEMICAL ADDITIVE DOSAGE OPTIMIZATION FOR BITUMEN RECOVERY
A method comprising: a) providing an oil sand slurry stream, comprising bituminous ore, to a water based extraction process; b) measuring one or more bitumen ore property; c) adding a primary chemical additive (PCA) and a supplementary chemical additive (SCA) to the oil sand slurry stream; d) processing the oil sand slurry stream into bitumen froth, middlings, flotation tailings (FT), and coarse sand tailings (CST), including using a primary separation cell (PSC); e) measuring one or more slurry property of at least one of the oil sand slurry stream, a hydrotransport line feeding the PSC, a middlings layer inside the PSC, the middlings from the PSC, the FT, and the CST; f) based on the one or more measured bitumen ore property, adjusting, in a feed forward control, at least one of the following in the water-based extraction process: a dosage of the supplementary chemical additive (SCA) added to the oil sand slurry stream, process temperature, a mixing condition, and water addition prior to the PSC; and g) based on the one or more measured slurry property, adjusting, in a feed-back control, at least one of the following in the water- based extraction process: the dosage of the supplementary chemical additive (SCA) added to the oil sand slurry stream, process temperature, a mixing condition, and water addition prior to the PSC.
C10G 1/04 - Production de mélanges liquides d'hydrocarbures à partir de schiste bitumineux, de sable pétrolifère ou de matières carbonées solides non fusibles ou similaires, p.ex. bois, charbon par extraction
C10C 3/08 - Traitement du brai, de l'asphalte, du bitume par extraction sélective
In conjunction with a communication network, for example, a downhole wireless network for transmission of data along a tubular body, disclosed herein are: (1) a variety of hardware interfacing methods with sensors and downhole tools; (2) sensing concepts that are enabled by the unique interfaces; (3) physical implementation of the integrated sensor/communication node structures; (4) related software communication protocols. The interfaces may support both data communication and power transfer.
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 47/14 - 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
15.
METHODS AND SYSTEMS FOR OPERATING AND MAINTAINING A DOWNHOLE WIRELESS NETWORK
Disclosed herein are methods and systems for operating and maintaining downhole wireless networks. The methods and systems use a downhole tool, such as a hydrophone, as part of the downhole wireless network. The downhole tool may be used, for example, to perform maintenance on the downhole wireless network, to overcome and/or correct communications errors along the network, to update and reprogram communication nodes in the downhole wireless network, to determine characteristics of nearby geologic formations, reservoirs, fluids, and tubulars, and/or to act as a substitute or topside node for the downhole wireless network.
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 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
16.
METHODS AND SYSTEMS FOR MONITORING AND OPTIMIZING RESERVOIR STIMULATION OPERATIONS
A method for monitoring and optimizing stimulation operations in a reservoir. In particular, the method utilizes a downhole telemetry system, such as a network of sensors and downhole wireless communication nodes, to monitor various stimulation operations. Data signals are transmitted acoustically through the tubular. Communication nodes comprise an elongated body that supports one or more power sources (230) and an electro-acoustic transducer (242).
E21B 43/26 - Procédés pour activer la production par formation de crevasses ou de fractures
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 47/10 - Localisation des fuites, intrusions ou mouvements du fluide
G01V 1/28 - Traitement des données sismiques, p.ex. pour analyse, pour interprétation, pour correction
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 stream to thereby generate a combined cold LNG stream. The warm LNG stream has a higher temperature than a temperature of the cold LNG stream and the combined cold LNG stream. The combined cold LNG stream has, in the first operating mode, a higher flow rate than a flow rate of the cold LNG stream 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
18.
ENERGY EFFICIENT METHOD OF RETRIEVING WIRELESS NETWORKED SENSOR DATA
A method of communicating in a wireless network. Devices are positioned such that each device communicates with one or more other devices. Some of the devices include one or more sensors. Each device is a node in the wireless network. At one of the devices, values are recorded from the sensors associated therewith. At least some of the devices, one or more recorded values from the sensors associated with said each device, and/or a sensor associated with at least one other device, are processed in accordance with a variable instruction set, to thereby generate a processed dataset. At each device, at least one of recorded values, a processed dataset associated with another device, or a revision to the variable instruction set are received from another device. At least one of the one or more recorded values, and one or more processed datasets, are transmitted at each device to another device.
H04W 4/38 - Services spécialement adaptés à des environnements, à des situations ou à des fins spécifiques pour la collecte d’informations de capteurs
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
19.
SYSTEM TO ESTIMATE CHAMBER CONFORMANCE IN A THERMAL GRAVITY DRAINAGE PROCESS USING PRESSURE TRANSIENT ANALYSIS
Systems and methods of estimating chamber conformance of a drainage chamber in a subterranean reservoir during a thermal gravity drainage process are disclosed herein. The system includes a plurality of pressure sensors distributed along an injector well, each sensor positioned outside a steel casing of the injector well and configured to measure a local pressure of a respective portion of the reservoir adjacent to the injector well. The system also includes one or more processors operatively coupled to each pressure sensor. The one or more processors is configured to receive the pressure of the portion of the chamber measured by each pressure sensor; determine a time to achieve pseudo steady state for each portion of the chamber when both the injector well and a producer well are shut-in; and, based on the time to achieve pseudo steady state for each portion of the chamber, estimate the chamber conformance along the injector well.
A method and system are described for wirelessly communicating along tubular members. The method includes determining, constructing and installing a communication network, which communicates using one or more communication coupling devices (114) along one or more tubular members (110). The communication network is used to perform operations for a system, such as hydrocarbon operations, which may involve hydrocarbon exploration, hydrocarbon development, and/or hydrocarbon production.
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
21.
METHOD AND SYSTEM FOR PERFORMING OPERATIONS USING COMMUNICATIONS FOR A HYDROCARBON SYSTEM
A method and system are described for communicating within a system, which may be along tubular members. The method includes constructing a communication network for a hydrocarbon system, which includes one or more wellbores accessing a subsurface region or a pipeline, and using the communication network in hydrocarbon operations, such as hydrocarbon exploration, hydrocarbon development, and/or hydrocarbon production.
E21B 47/13 - Moyens pour la transmission de signaux de mesure ou signaux de commande du puits vers la surface, ou de la surface vers le puits, p.ex. pour la diagraphie pendant le forage par énergie électromagnétique, p.ex. gammes de fréquence radio
E21B 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
H04B 11/00 - Systèmes de transmission utilisant des ondes ultrasonores, sonores ou infrasonores
22.
METHOD AND SYSTEM FOR PERFORMING HYDROCARBON OPERATIONS USING COMMUNICATIONS ASSOCIATED WITH COMPLETIONS
A method and system are described for communicating within a system, which may be along tubular members and used during gravel pack operations. The method includes constructing a communication network and installing the communication nodes along the gravel pack system. The communication nodes are used to monitor the formation of the gravel pack for voids or gaps during the gravel pack operations. Once the gravel pack is installed, the gravel pack operations may be used for hydrocarbon operations, such as hydrocarbon exploration, hydrocarbon development, and/or hydrocarbon production.
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
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 47/12 - 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 47/005 - Surveillance ou contrôle de la qualité ou du niveau de cimentation
E21B 47/13 - Moyens pour la transmission de signaux de mesure ou signaux de commande du puits vers la surface, ou de la surface vers le puits, p.ex. pour la diagraphie pendant le forage par énergie électromagnétique, p.ex. gammes de fréquence radio
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 47/09 - 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
H04B 11/00 - Systèmes de transmission utilisant des ondes ultrasonores, sonores ou infrasonores
Methods of recovering bitumen from an underground reservoir are described herein. The methods include injecting a first mobilizing fluid into the underground reservoir through a first well, producing a first produced fluid from the underground reservoir through the first well, the first produced fluid including bitumen and at least a portion of the first mobilizing fluid injected into the underground reservoir, mixing at least a portion of the first produced fluid with a make-up fluid to form a second mobilizing fluid, injecting the second mobilizing fluid into the underground reservoir through a second well and producing a second produced fluid from the underground reservoir through the second well, the second produced fluid including bitumen and at least a portion of the second mobilizing fluid injected into the underground reservoir.
A method and system for liquefying a feed gas stream including natural gas. The feed gas stream is provided at a pressure less than 1,200 psia. A refrigerant stream having a pressure of at least 1,500 psia is cooled and then expanded in a first expander to an intermediate pressure. The first expander is mechanically coupled to a first coupled compressor to together form a first turboexpander-compressor. The refrigerant stream is expanded in a second expander, which is mechanically coupled to a second coupled compressor to together form a second turboexpander-compressor. The refrigerant stream cools the feed gas stream in one or more heat exchangers. Using the second coupled compressor and a first driven compressor, the refrigerant stream is compressed to a discharge pressure within 300 psia of the intermediate pressure. The refrigerant stream is compressed using the first coupled compressor and is further compressed to provide the refrigerant stream.
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
26.
SELECTIVE GAS SEPARATION OF PRODUCED GAS FROM HYDROCARBON RECOVERY FROM UNDERGROUND RESERVOIRS
Produced gas streams from in-situ viscous oil recovery processes may comprise H2S and/or CO 2, which would desirably be removed. One method comprises: a) providing a produced gas stream comprising 20-60 mol.% CO 2, 30-70 mol.% CH 4, 0-0.4 mol.% H2S and 0.1- 2 mol.% C2+ hydrocarbons from an in-situ viscous oil recovery process; b) providing a graphene-based material; and c) passing the produced gas stream through the graphene-based material for selectively adsorbing H2S and/or CO 2 from the produced gas stream with the graphene-based material, and forming a flue gas stream comprising greater than 50 mol.% combined H2S and CO 2 and a treated gas stream comprising 75-95 mol.% CH 4.
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
B01J 20/20 - Compositions absorbantes ou adsorbantes solides ou compositions facilitant la filtration; Absorbants ou adsorbants pour la chromatographie; Procédés pour leur préparation, régénération ou réactivation contenant une substance inorganique contenant du carbone obtenu par des procédés de carbonisation
27.
METHOD AND SYSTEM FOR PERFORMING OPERATIONS USING COMMUNICATIONS
A method and system are described for communicating within a system, which may be along tubular members. The method includes constructing a communication network for tubular member, such as a wellbore accessing a subsurface region or a pipeline, and using the communication network in hydrocarbon operations, such as hydrocarbon exploration, hydrocarbon development, and/or hydrocarbon production.
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
H04L 27/10 - Systèmes à courant porteur à modulation de fréquence, p.ex. utilisant une manipulation à décalage de fréquence
A controller system, comprising: a controller configured to control toward a desired process value, an arrangement to repetitively measure a value of the desired process value; wherein the controller is configured to execute a routine that: determines a moving average of the measured values, determines a moving standard deviation of the measured values, defines an outer zone of measured values with the determined moving average and a first plurality of the determined moving standard deviation, defines an inner zone of measured values with the determined moving average and a second plurality of the determined moving standard deviation, monitors the measured values for the occurrence of a first statistical event with respect to the outer zone and adjusting a gain of the controller by a first factor upon detection of the first statistical event, monitors the measured values for the occurrence of a second statistical event with respect to the inner zone and adjusting a gain of the controller by a second factor upon detection of the second statistical event.
E21B 44/02 - Commande automatique de l'avance de l'outil
G05B 13/02 - Systèmes de commande adaptatifs, c. à d. systèmes se réglant eux-mêmes automatiquement pour obtenir un rendement optimal suivant un critère prédéterminé électriques
G05B 13/04 - Systèmes de commande adaptatifs, c. à d. systèmes se réglant eux-mêmes automatiquement pour obtenir un rendement optimal suivant un critère prédéterminé électriques impliquant l'usage de modèles ou de simulateurs
29.
METHOD AND SYSTEM FOR PERFORMING HYDROCARBON OPERATIONS WITH MIXED COMMUNICATION NETWORKS
A method and system are described for using different types of communication networks along one or more tubular members. The method includes constructing a communication network along one or more tubular members, which may access a subsurface region and using the communication network in hydrocarbon operations, such as hydrocarbon exploration, hydrocarbon development, and/or hydrocarbon production.
H04B 11/00 - Systèmes de transmission utilisant des ondes ultrasonores, sonores ou infrasonores
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
H04B 13/00 - Systèmes de transmission caractérisés par le milieu utilisé pour la transmission, non prévus dans les groupes
30.
METHOD AND SYSTEM FOR PERFORMING OPERATIONS WITH COMMUNICATIONS
A method and system are described for wirelessly communicating within a wellbore. The method includes constructing a communication network for a wellbore accessing a subsurface region and using the communication network in hydrocarbon operations, such as hydrocarbon exploration, hydrocarbon development, and/or hydrocarbon production.
H04B 11/00 - Systèmes de transmission utilisant des ondes ultrasonores, sonores ou infrasonores
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
31.
METHOD AND SYSTEM FOR PERFORMING COMMUNICATIONS USING ALIASING
A method and system are described for wirelessly communicating within a wellbore. The method includes constructing a communication network (e.g., which uses aliased signals as part of the configuration) for a wellbore accessing a subsurface region and using the communication network in hydrocarbon operations, such as hydrocarbon exploration, hydrocarbon development, and/or hydrocarbon production.
H04B 11/00 - Systèmes de transmission utilisant des ondes ultrasonores, sonores ou infrasonores
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
32.
METHOD AND SYSTEM FOR PERFORMING WIRELESS ULTRASONIC COMMUNICATIONS ALONG A DRILLING STRING
A method and system are described for wirelessly communicating within a wellbore. The method includes constructing a communication network, which communicates during drilling operations along one or more drilling strings. The communication network is used to perform drilling operations for hydrocarbon operations, such as hydrocarbon exploration, hydrocarbon development, and/or hydrocarbon production.
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 44/00 - Systèmes de commande automatique spécialement adaptés aux opérations de forage, c. à d. systèmes à fonctionnement autonome ayant pour rôle d'exécuter ou de modifier une opération de forage sans l'intervention d'un opérateur humain, p.ex. systèmes de ; Systèmes spécialement adaptés à la surveillance de plusieurs variables ou conditions de forage
G10K 11/26 - Procédés ou dispositifs pour transmettre, conduire ou diriger le son pour focaliser ou pour diriger le son, p.ex. balayage
H04B 11/00 - Systèmes de transmission utilisant des ondes ultrasonores, sonores ou infrasonores
An apparatus and method for securing a piezoelectric element in an electroacoustic communications node used in a downhole wireless telemetry system. An end mass is secured to the piezoelectric element. At least one fastener attaches a pre-tensioning support plate to a housing of the node. The pre-tensioning support plate and the at least one fastener impart a tensioning force to the end mass and/or the piezoelectric element when the pre- tensioning support plate and the end mass and/or the piezoelectric element are secured to the housing.
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 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
34.
WELLBORE PLUNGERS WITH NON-METALLIC TUBING-CONTACTING SURFACES AND WELLS INCLUDING THE WELLBORE PLUNGERS
Wellbore plungers 100 with non-metallic tubing-contacting surfaces 132 and wells 10 including the wellbore plungers. The wellbore plungers are configured to be utilized within a tubing conduit of the downhole tubing. The downhole tubing includes a non-metallic tubing material 34 that defines a non-metallic tubing surface 36. The non-metallic tubing surface at least partially defines the tubing conduit. The wellbore plungers include an uphole region, which defines an uphole bumper-contacting surface, a downhole region, which defines a downhole bumper-contacting surface, and a plunger body. The plunger body extends between the uphole region and the downhole region and defines a downhole tubing-contacting surface. The downhole tubing-contacting surface is configured for sliding contact with the non-metallic tubing surface, defines a sealing structure configured to form an at least partial fluid seal with the downhole tubing, and is at least partially defined by a non-metallic tubing-contacting material.
Methods and systems for starting-up a solvent-based operation for recovering hydrocarbons from an underground reservoir are disclosed. Methods include injecting a startup mobilizing fluid comprising a mixture of vapour solvent and steam into the reservoir via startup tubing strings provided in horizontal segments of injection and production wellbores, removing the startup tubing string from the production wellbore, and providing a production tubing string comprising an artificial lift system in the production wellbore. In some methods, the startup mobilizing fluid comprises a substantially azeotropic mixture of vapour solvent and steam.
E21B 43/241 - Procédés de récupération assistée pour l'extraction d'hydrocarbures utilisant la chaleur, p.ex. injection de vapeur combinés avec une exploitation au moyen de solvants de matières minérales autres que des hydrocarbures, p.ex. pyrolyse de schistes bitumineux au moyen de solvants
C09K 8/592 - Compositions utilisées en combinaison avec de la chaleur générée, p.ex. par injection de vapeur
36.
NATURAL GAS LIQUEFACTION BY A HIGH PRESSURE EXPANSION PROCESS
A method and system for liquefying a methane-rich high-pressure feed gas stream using a system having first and second heat exchanger zones and a compressed refrigerant stream. The compressed refrigerant stream is cooled and directed to the second heat exchanger zone to additionally cool it below ambient temperature. It is then expanded and passed through the first heat exchanger zone such that it has a temperature that is cooler, by at least 2,8 °C, than the highest fluid temperature within the first heat exchanger zone. The feed gas stream is passed through the first heat exchanger zone to cool at least part of it by indirect heat exchange with the refrigerant stream, thereby forming a liquefied gas stream. At least a portion of the first warm refrigerant stream is directed to the second heat exchanger zone to cool the refrigerant stream, which is compressed.
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
37.
METHOD AND SYSTEM FOR LNG PRODUCTION USING STANDARDIZED MULTI-SHAFT GAS TURBINES, COMPRESSORS AND REFRIGERANT SYSTEMS
A drive system for liquefied natural gas (LNG) production. A standardized machinery string consisting of a multi-shaft gas turbine with no more than three compressor bodies, where the compressor bodies are applied to one or more refrigerant compressors employed in one or more refrigerant cycles (e.g., single mixed refrigerant, propane precooled mixed refrigerant, dual mixed refrigerant). The standardized machinery strings and associated standardized refrigerators are designed for a generic range of feed gas composition and ambient temperature conditions and are installed in opportunistic liquefaction plants without substantial reengineering and modifications. The approach captures DIBM ("Design 1 Build Many) cost and schedule efficiencies by allowing for broader variability in liquefaction efficiency with location and feed gas composition.
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
A method of separating impurities from a natural gas stream. CO2 and H2S are separated from the natural gas stream in a membrane separation system, thereby creating a partially -treated gas stream and a permeate gas stream, both of which are at a lower temperature than the natural gas stream. The partially-treated gas stream is contacted with a first lean solvent stream in a first contactor to separate H2S from the partially -treated gas stream, thereby producing a first rich solvent stream and a fully -treated gas stream. The permeate gas stream is contacted with a second lean solvent stream in a second contactor to separate H2S therefrom to produce a second rich solvent stream and a CO2 gas stream. H2S and CO2 are removed from the first and second rich solvent streams, thereby producing the first and second lean solvent streams.
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
B01D 53/22 - SÉPARATION Épuration chimique ou biologique des gaz résiduaires, p.ex. gaz d'échappement des moteurs à combustion, fumées, vapeurs, gaz de combustion ou aérosols par diffusion
C07C 7/11 - Purification, séparation ou stabilisation d'hydrocarbures; Emploi d'additifs par absorption, c. à d. purification ou séparation d'hydrocarbures gazeux à l'aide de liquides
C10L 3/10 - Post-traitement de gaz naturel ou de gaz naturel de synthèse
39.
RESERVOIR MATERIALITY BOUNDS FROM SEISMIC INVERSION
The disclosure provides a method for accurate imaging of subsurface structures. The method models subsurface properties of a subsurface region based on geophysical data. Generating the models is achieved by performing an inversion that minimizes a misfit between the geophysical data and forward simulated data subject to one or more constraints. The inversion includes generating updates of the models for different scenarios that fit the geophysical data with a same likelihood but have different values for model materiality. The model materiality depends on model parameters that characterize hydrocarbon potential of the subsurface region. The method includes analyzing a geophysical data misfit curve or geophysical data misfit likelihood curve to quantify uncertainties in the subsurface properties. Prospecting for hydrocarbons in the subsurface region is performed in accordance with the models that correspond to the high- side and the low-side for each of the subsurface properties.
Methods of drilling a wellbore within a subsurface region and drilling control systems that perform the methods. The methods include accessing an objective map and calculating a plurality of critical points of the objective map. The methods also include scoring each critical point and selecting a selected critical point of the plurality of critical points. The selected critical point describes an estimated value of at least one drilling performance indicator for a selected value of at least one independent operational parameter. The methods further include operating the drilling rig at the selected value of the at least one independent operational parameter and, during the operating, determining an actual value of the at least one drilling performance indicator. The methods also include updating the objective map to generate an updated objective map and repeating at least a portion of the methods.
A method of controlled deposition for increasing deposition rate, the method comprising providing a first fines dominated stream having a first sand to fines ratio (SFR) of less than 0.6 and having first solids content; providing a second fines dominated stream having a second SFR of between 0.6 and 3.0 and having a second solids content; wherein the first solids content and the second solids content differ by at least 5%, by mass; and depositing the first and second dominated streams into a common deposition cell.
A method comprises providing a thickener, an underflow pipeline, and a deposition cell, arranged in series, such that flotation tailings (FT) can be introduced into the thickener, formed into thickened tailings, and introduced into the deposition cell; introducing fluid fine tailings (FFT) downstream of the thickener as a bypass; and settling out at least a portion of the FFT in the deposition cell.
A method comprises introducing oil sand tailings into a thickener; and effecting a shear loop comprising removing thickened tailings (TT) from the thickener, combining at least a portion of the TT with fluid fine tailings (FFT) to form a recycle stream, and recycling the recycle stream back into the thickener.
Methods and systems for managing solvent used in Cyclic Solvent Process (CSP) operations are disclosed. Methods include injecting fluid comprising solvent into a first underground reservoir, the first underground reservoir comprising a voidage formed during a thermal recovery process; producing fluid from the first underground reservoir, the produced fluid primarily comprising solvent from the injected fluid; and injecting at least a portion of the produced fluid into a second underground reservoir during a CSP operation.
E21B 43/241 - Procédés de récupération assistée pour l'extraction d'hydrocarbures utilisant la chaleur, p.ex. injection de vapeur combinés avec une exploitation au moyen de solvants de matières minérales autres que des hydrocarbures, p.ex. pyrolyse de schistes bitumineux au moyen de solvants
C09K 8/592 - Compositions utilisées en combinaison avec de la chaleur générée, p.ex. par injection de vapeur
E21B 43/22 - Emploi de produits chimiques ou à activité bactérienne
Disclosed is a method comprising measuring a sulfur content in a bitumen containing stream using X-Ray Fluorescence (XRF), optionally estimating a bitumen content in the bitumen containing stream using generated data, comparing the sulfur content or the bitumen content to a predetermined reference range, and adjusting a process parameter, if necessary, based on the sulfur content or the bitumen content as compared to the predetermined reference range.
G01N 23/223 - Recherche ou analyse des matériaux par l'utilisation de rayonnement [ondes ou particules], p.ex. rayons X ou neutrons, non couvertes par les groupes , ou en mesurant l'émission secondaire de matériaux en irradiant l'échantillon avec des rayons X ou des rayons gamma et en mesurant la fluorescence X
C10C 3/08 - Traitement du brai, de l'asphalte, du bitume par extraction sélective
C10G 1/04 - Production de mélanges liquides d'hydrocarbures à partir de schiste bitumineux, de sable pétrolifère ou de matières carbonées solides non fusibles ou similaires, p.ex. bois, charbon par extraction
46.
SYSTEMS AND METHODS FOR ESTIMATING AND CONTROLLING LIQUID LEVEL USING PERIODIC SHUT-INS
Methods and systems for determining a liquid level in a formation between a horizontal segment of an injection wellbore and a horizontal segment of a production wellbore are disclosed. Under shut-in conditions, local temperatures and pressures are determined for each of a plurality of inflow zones along the production wellbore segment. Local profile values are determined based on local shut-in subcool values and local shut-in liquid levels. After flow has resumed, a local liquid level is determined based on the local operating subcool value and the local profile value for that inflow zone. The local profile values may be updated during subsequent shut-ins.
Method and systems are provided for building a structural model of the subsurface. The method may comprise obtaining discretized data that includes surfaces, polylines, points, or combinations thereof. The surfaces in the discretized data are segmented by other surfaces to form a number of segments. Each of the segments are fit to an implicit function. The implicit function for each of the segments is thresholded to create a number of implicit surfaces. The implicit surfaces are intersected to create a number of model surfaces. The structural model is then constructed from the model surfaces.
Methods of recovering hydrocarbons from a subsurface zone are disclosed herein. The methods include removing an overburden from the subsurface zone to generate an excavated region and positioning a flow barrier over the subsurface zone and within the excavated region. The methods also include covering the flow barrier with a fill material such that the flow barrier restricts fluid flow between the subsurface zone and the fill material. The methods further include injecting a mobilizing fluid into the subsurface zone to reduce a viscosity of the hydrocarbons within the subsurface zone and/or to generate mobilized hydrocarbons. The methods also include producing the mobilized hydrocarbons from the subsurface zone.
E21B 43/16 - Procédés de récupération assistée pour l'extraction d'hydrocarbures
E02D 37/00 - Réparation des fondations endommagées
E21B 43/22 - Emploi de produits chimiques ou à activité bactérienne
E21B 43/24 - Procédés de récupération assistée pour l'extraction d'hydrocarbures utilisant la chaleur, p.ex. injection de vapeur
E21B 43/241 - Procédés de récupération assistée pour l'extraction d'hydrocarbures utilisant la chaleur, p.ex. injection de vapeur combinés avec une exploitation au moyen de solvants de matières minérales autres que des hydrocarbures, p.ex. pyrolyse de schistes bitumineux au moyen de solvants
49.
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 1/00 - 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
50.
METHODS FOR USING ISOTOPIC SIGNATURES TO DETERMINE CHARACTERISTICS OF HYDROCARBON SOURCES
Described herein are methods and techniques for determining one or more characteristics of a hydrocarbon source. The method comprises obtaining a hydrocarbon fluid sample, determining at least one measured clumped isotope signature or measured position specific isotope signature for at least one hydrocarbon species of interest in the hydrocarbon fluid sample, determining at least one expected clumped isotope signature or expected position specific isotope signature for the hydrocarbon species of interest, comparing the measured clumped isotope signature or measured position specific isotope signature with the expected clumped isotope signature or expected position specific isotope signature, and determining at least one characteristic of the source of the hydrocarbon sample based on the comparison.
A feedwell system for delivering a slurry to a separation vessel, the system comprising: a feedwell barrel for containing and controlling the slurry; one or more inlet pipes leading into the feedwell barrel for tangentially introducing the slurry into the feedwell barrel to cause the slurry to swirl around the feedwell barrel; and a series of spaced-apart baffles disposed around an inner perimeter of the feedwell barrel for dissipating inflow energy and limiting an internal circulation field within the feedwell barrel, wherein the series of spaced- apart baffles comprises one or more inlet baffles configured to direct the slurry downwardly in the feedwell barrel and against a direction of introduction of the slurry; the feedwell barrel having a bottom with an outlet therein to allow discharge of the slurry.
B01D 21/26 - Séparation du sédiment avec emploi de la force centrifuge
B01D 45/08 - Séparation de particules dispersées dans des gaz ou des vapeurs par gravité, inertie ou force centrifuge par inertie par projection contre les diaphragmes séparateurs
B01D 45/12 - Séparation de particules dispersées dans des gaz ou des vapeurs par gravité, inertie ou force centrifuge en utilisant la force centrifuge
52.
METHOD FOR DRILLING WELLBORES UTILIZING A DRILL STRING ASSEMBLY 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 predicting modified drilling operation conditions based on proposed changes to the drill string configuration and/or the drilling parameters. Included are methods for drilling wells utilizing a method for the selection of modified drill string assemblies and/or modified drilling parameters.
E21B 44/00 - Systèmes de commande automatique spécialement adaptés aux opérations de forage, c. à d. systèmes à fonctionnement autonome ayant pour rôle d'exécuter ou de modifier une opération de forage sans l'intervention d'un opérateur humain, p.ex. systèmes de ; Systèmes spécialement adaptés à la surveillance de plusieurs variables ou conditions de forage
53.
METHOD AND SYSTEM FOR ENHANCING HYDROCARBON OPERATIONS
A method and system are described for imaging core samples associated with a subsurface region. The imaging results may be used to create or update a subsurface model and using the subsurface model and/or imaging results in hydrocarbon operations. The imaging techniques may include NMR imaging and CT imaging. Further, the imaging techniques may also include exposing the core sample to the imaging gas.
G01V 3/14 - Prospection ou détection électrique ou magnétique; Mesure des caractéristiques du champ magnétique de la terre, p.ex. de la déclinaison ou de la déviation fonctionnant par résonance magnétique électronique ou nucléaire
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
54.
METHOD AND SYSTEM FOR ENHANCING HYDROCARBON OPERATIONS
A method and system are described for imaging core samples associated with a subsurface region. The imaging results may be used to create or update a subsurface model and using the subsurface model and/or imaging results in hydrocarbon operations. The imaging techniques may include NMR imaging and CT imaging. Further, the imaging techniques may also include exposing the core sample to the imaging gas.
G01V 3/14 - Prospection ou détection électrique ou magnétique; Mesure des caractéristiques du champ magnétique de la terre, p.ex. de la déclinaison ou de la déviation fonctionnant par résonance magnétique électronique ou nucléaire
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
55.
METAL ISOTOPE APPLICATIONS IN HYDROCARBON EXPLORATION, DEVELOPMENT, AND PRODUCTION
Described herein are methods and techniques for utilizing a multiple metal isotope signature as an internal tracers for hydrocarbon source, alteration, and mixing. The multiple metal isotope signature may comprise a ratio of a at least two isotopes of a first metal, a ratio of at least two isotopes of a second metal, and a ratio of at least two isotopes of a third metal from a sample. The isotope ratios of the first, second, and third metal may be integrated to form the multiple metal isotope signature.
E21B 47/10 - Localisation des fuites, intrusions ou mouvements du fluide
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
Disclosed is a method comprising providing an oil sand slurry stream stemming from an oil sand ore; processing the oil sand slurry stream into bitumen froth, middlings, and coarse sand tailings (CST), including using a primary separation cell (PSC); and adding an acidic process aid beneath a froth layer in the PSC or to the middlings, for reducing a pH level beneath the froth layer in the PSC or of the middlings, for assisting bitumen and air attachment and for reducing solids in the bitumen froth or a froth recycle stream.
C10G 1/04 - Production de mélanges liquides d'hydrocarbures à partir de schiste bitumineux, de sable pétrolifère ou de matières carbonées solides non fusibles ou similaires, p.ex. bois, charbon par extraction
A method comprises introducing an oil sand slurry stream to a primary separation cell (PSC) and forming a bitumen froth, a middlings stream, and a coarse sand tailings stream (CST); introducing the middlings stream to a flotation process and forming a recycle froth and a flotation tailings stream; and introducing CO2 into one or more of: i) the PSC, beneath a froth layer; ii) the middlings stream; and iii) the flotation process, for increasing bitumen recovery, sequestering carbon dioxide in the CST and/or the flotation tailings stream, increasing fines capture in the CST, or a combination thereof.
C10G 1/04 - Production de mélanges liquides d'hydrocarbures à partir de schiste bitumineux, de sable pétrolifère ou de matières carbonées solides non fusibles ou similaires, p.ex. bois, charbon par extraction
Use of graphene oxide for adsorbing asphaltene hetero-compounds in a bitumen- rich stream within a bitumen froth treatment process. A method includes providing a bitumen froth, forming an overflow and an underflow by gravity separating the bitumen froth, and adding a graphene oxide to the bitumen froth or to the underflow, for adsorbing asphaltene hetero-compounds.
C10G 1/04 - Production de mélanges liquides d'hydrocarbures à partir de schiste bitumineux, de sable pétrolifère ou de matières carbonées solides non fusibles ou similaires, p.ex. bois, charbon par extraction
59.
INCREASING EFFICIENCY IN AN LNG PRODUCTION SYSTEM BY PRE-COOLING A NATURAL GAS FEED STREAM
Described herein are systems and processes to produce liquefied natural gas (LNG) using liquefied nitrogen (LIN) as the refrigerant. 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
60.
PRE-COOLING OF NATURAL GAS BY HIGH PRESSURE COMPRESSION AND EXPANSION
A method of producing liquefied natural gas (LNG) is disclosed. A natural gas is compressed in at least two serially arranged compressors to a pressure of at least 2,000 psia and cooled to form a cooled compressed natural gas stream. The cooled compressed natural gas stream is additionally cooled to a temperature below an ambient temperature to form an additionally cooled compressed natural gas stream, which is expanded in at least one work producing natural gas expander to a pressure that is less than 3,000 psia and no greater than the pressure to which the at least two serially arranged compressors compress the natural gas stream, to thereby form a chilled natural gas stream. The chilled natural gas stream is liquefied by indirect heat exchange with a refrigerant to form liquefied natural gas and a warm refrigerant. The cooled compressed natural gas stream is additionally cooled using the warm refrigerant.
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
61.
METHOD AND SYSTEM FOR REGRESSION AND CLASSIFICATION IN SUBSURFACE MODELS TO SUPPORT DECISION MAKING FOR HYDROCARBON OPERATIONS
A method and system are described for hydrocarbon exploration, development and production. The method relates to performing regression and/or classification in subsurface models to support decision making for hydrocarbon operations. The evaluation may then be used in performing hydrocarbon operations, such as hydrocarbon exploration, hydrocarbon development and/or hydrocarbon production.
A method and system are described to form a subsurface model for use in hydrocarbon operations. The method and system utilize stability proxies with the subsurface models, such as simulation models, and to manage the reservoir simulation.
A method and system for manufacturing and using a self-supporting structure in processing unit for adsorption or catalytic processes. The self-supporting structure has greater than 50% by weight of the active material in the self-supporting structure to provide a foam- geometry structure providing access to the active material. The self-supporting structures, which may be disposed in a processing unit, may be used in swing adsorption processes and other processes to enhance the recovery of hydrocarbons.
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
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
B01J 20/28 - Compositions absorbantes ou adsorbantes solides ou compositions facilitant la filtration; Absorbants ou adsorbants pour la chromatographie; Procédés pour leur préparation, régénération ou réactivation caractérisées par leur forme ou leurs propriétés physiques
64.
SELF-SUPPORTING STRUCTURES HAVING ACTIVE MATERIALS
A method and system for manufacturing and using a self-supporting structure in processing unit for adsorption or catalytic processes. The self-supporting structure has greater than 50% by weight of the active material in the self-supporting structure to provide an open-celled structure providing access to the active material. The self-supporting structures, which may be disposed in a processing unit, may be used in swing adsorption processes and other processes to enhance the recovery of hydrocarbons.
B01J 20/28 - Compositions absorbantes ou adsorbantes solides ou compositions facilitant la filtration; Absorbants ou adsorbants pour la chromatographie; Procédés pour leur préparation, régénération ou réactivation caractérisées par leur forme ou leurs propriétés physiques
B33Y 80/00 - Produits obtenus par fabrication additive
B29C 64/00 - Fabrication additive, c. à d. fabrication d’objets en trois dimensions [3D] par dépôt additif, agglomération additive ou stratification additive, p.ex. par impression en 3D, stéréolithographie ou frittage laser sélectif
B01D 46/24 - Séparateurs de particules utilisant des corps filtrants creux et rigides, p.ex. appareils de précipitation de poussières
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
Methods of determining a spatial distribution of an injected tracer material (60) within a subterranean formation (40) are disclosed, including flowing the tracer material, which includes a tracer electrical capacitance that differs from a formation electrical capacitance of a region of the subterranean formation, into the region of the subterranean formation via a wellbore (50). Subsequent to the flowing, the methods also include providing an input electromagnetic signal (92) to the region of the subterranean formation. Responsive to the providing, the methods further include receiving an output electromagnetic signal (97) from the subterranean formation. The methods further include determining the spatial distribution of the tracer material (60) within the subterranean formation (40) based, at least in part, on the output electromagnetic signal (97).
E21B 47/10 - Localisation des fuites, intrusions ou mouvements du fluide
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
66.
METHOD FOR ESTIMATING PETROPHYSICAL PROPERTIES FOR SINGLE OR MULTIPLE SCENARIOS FROM SEVERAL SPECTRALLY VARIABLE SEISMIC AND FULL WAVEFIELD INVERSION PRODUCTS
A computer-implemented method for determining rock and fluid parameters of a subsurface region from measured seismic reflection data, said method including: generating, with a computer, a geophysical data volume by combining a plurality of angle stacks obtained from the measured seismic reflection data and geophysical property data obtained from a full wavefield inversion of the measured seismic reflection data; for each point of the geophysical data volume, determining, with a computer, a petrophysical model that is a probability of a rock state based on initial values of the rock and fluid parameters and the geophysical data volume; iteratively determining, using a computer, updated values for the rock and fluid parameters, wherein the iteratively determining includes determining a petrophysical parameter estimate for the rock and fluid parameters from the petrophysical model as constrained by the geophysical data volume and the initial values of the rock and fluid parameters, minimizing a misfit between the geophysical data volume and synthetic data generated from a forward modeling of the initial values of the rock and fluid parameters using a cost function that includes the petrophysical parameter estimate of the rock and fluid parameters, and repeating the iteratively determining until a predetermined stopping criteria is satisfied and final values for the rock and fluid parameters are generated, and each subsequent iteration of the iteratively determining replaces the initial values for the rock and fluid parameters with the updated values for the rock and fluid parameters from a previous iteration; determining, with a computer, uncertainty in the final values for the rock and fluid parameters; and exploring for or producing hydrocarbons using the final values for the rock and fluid parameters and there uncertainty.
Methods of acoustically communicating and wells that utilize the methods are disclosed herein. The methods generally utilize an acoustic wireless network including a plurality of nodes spaced-apart along a length of a tone transmission medium and include determining a major frequency of a received acoustic tone transmitted via the tone transmission medium.
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 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
H04B 11/00 - Systèmes de transmission utilisant des ondes ultrasonores, sonores ou infrasonores
68.
SWING ADSORPTION PROCESSES FOR REMOVING WATER USING 3A ZEOLITE STRUCTURES
The present disclosure describes the use of a specific adsorbent material in a rapid cycle swing adsorption to perform dehydration of a gaseous feed stream. The adsorbent material includes a zeolite 3A that is utilized in the dehydration process to enhance recovery of hydrocarbons.
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
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
An electro-acoustic communications node system and method for downhole wireless telemetry, the system including a housing (386) for mounting to or with a tubular body (310); a receiver transducer (388) positioned within the housing, the receiver transducer structured and arranged to receive acoustic waves that propagate through the tubular member; a transmitter transducer (336) and a processor, positioned within the housing and arranged to retransmit the acoustic waves to another acoustic receiver in a different housing, using the tubular member for the acoustic telemetry. In some embodiments, the transducers may be piezoelectric transducers and/or magnetostrictive transducers. Included in the housing is also a power source (390) comprising one or more batteries. A downhole wireless telemetry system and a method of monitoring a hydrocarbon well are also provided.
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
70.
PROCESS TO DECOUPLE REGENERATION GAS COMPRESSOR FROM REGENERATION GAS TREATING
A method for continuously treating a regeneration gas stream used to regenerate a molecular sieve adsorption vessel is disclosed. The regeneration gas stream is cooled in a cooler to a temperature suitable to condense liquids therein. A separator removes liquids condensed in the regeneration gas stream. The regeneration gas stream is compressed in a compressor. The regeneration gas stream is flowed through the cooler, the separator, and the compressor when the compressor is operational. The regeneration gas stream is flowed through the second cooler and the second separator but not the compressor when the compressor is not operational, thereby enabling continuous treatment of the regeneration 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
Methods of acoustically communicating acoustically within a wellbore (30) and wells that utilize the methods are disclosed herein. The methods generally utilize an acoustic wireless network (50) including a plurality of nodes (60) spaced-apart along a length of a tone transmission medium (100).The disclosure includes a method of conserving power in the acoustic wireless network (50).
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
The communication networks include an elongate tubular body (30) and a wireless data transmission network (50) including a plurality of relay nodes (100). The relay nodes include an electro-acoustic transmitter array (112, 122, 132) and an electro-acoustic receiver (114, 124, 134). The methods include inducing a first non-dispersive guided acoustic wave within the elongate tubular body with a first relay node (110), conveying said first non-dispersive guided acoustic wave along the elongate tubular body to a second relay node (120), and receiving said first non-dispersive guided acoustic wave with the second relay node (120), further inducing a second non-dispersive guided acoustic wave within the elongate tubular body with the second relay node (120), conveying the second acoustic wave along the elongate tubular body to a third relay node (130), and receiving the second acoustic wave with the third relay node (130).
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
73.
RESERVOIR FORMATION CHARACTERIZATION USING A DOWNHOLE WIRELESS NETWORK
A system for reservoir formation characterization with a downhole wireless telemetry system, including at least one sensor (178) disposed along a tubular body (110); at least one sensor communications node (184) placed along the tubular body and affixed to a wall of the tubular body, the sensor communications node being in communication with the at least one sensor and configured to receive signals therefrom; a topside communications node (182) placed proximate a surface; a plurality of intermediate communications nodes (180) spaced along the tubular body and configured to transmit signals received from the at least one sensor communications node to the topside communications node in substantially a node-to-node arrangement; a receiver (190) at the surface configured to receive signals from the topside communications node; and a topside data acquisition system structured to communicate with the topside communications node. A method for reservoir formation characterization is also provided.
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 47/12 - 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
74.
METHODS OF ACOUSTICALLY COMMUNICATING AND WELLS THAT UTILIZE THE METHODS
The methods utilize an acoustic wireless network including a plurality of nodes spaced-apart along a length of a tone transmission medium, the methods include encoding an encoded character with an encoding node. The encoding includes selecting a first frequency based upon a first predetermined lookup table and the encoded character, and transmitting a first transmitted acoustic tone at the first frequency. The encoding further includes selecting a second frequency based upon a second lookup table and the encoded character, and transmitting a second transmitted acoustic tone at the second frequency.These methods also include decoding a decoded character with a decoding node. The decoding includes receiving the first and second acoustic tone, calculating first and second frequency distributions for the respective tones, and determining a first and second decoded character distribution for the decoded character and identifying the decoded character based upon the first and second decoded character distributions.
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 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
H04B 11/00 - Systèmes de transmission utilisant des ondes ultrasonores, sonores ou infrasonores
75.
SYSTEM AND METHOD FOR LIQUEFYING NATURAL GAS WITH TURBINE INLET COOLING
A system and method for processing natural gas to produce liquefied natural gas is disclosed. The natural gas is cooled in one or more heat exchangers using a first refrigerant from a first refrigerant circuit in which the first refrigerant is compressed in a first compressor driven by a first gas turbine having a first inlet air stream. The natural gas is liquefied using a second refrigerant, the second refrigerant being compressed in a second compressor driven by a second gas turbine having a second inlet air stream. At least one of the inlet air streams is chilled from about the respective dry bulb temperature to a temperature below the respective wet bulb temperature. Water contained in at least one of the chilled first and second air streams is condensed and separated therefrom. At least a portion of the first refrigerant is condensed or sub-cooled using the separated water.
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
76.
SYSTEMS AND METHODS FOR DYNAMIC LIQUID LEVEL MONITORING AND CONTROL
Methods and systems for determining a liquid level above a horizontal segment of a wellbore in a formation are disclosed. Local temperatures and pressures are determined for each of a plurality of zones along the wellbore segment. For each zone, a local inflow rate is determined for fluids entering the wellbore from the formation. Based on the local inflow rate, local temperature, and local pressure, a local reservoir pressure is determined, and a local liquid level is determined based on the local reservoir pressure and a pressure associated with an injector wellbore positioned above the horizontal segment.
Thermal recovery methods for recovering viscous hydrocarbons from a subterranean formation. The thermal recovery methods include performing a plurality of injection cycles. Each injection cycle in the plurality of injection cycles includes injecting a heated solvent vapor stream into a heated chamber that extends within the subterranean formation and fluidly contacting the viscous hydrocarbons with the heated solvent vapor stream to generate mobilized viscous hydrocarbons. Each injection cycle also includes injecting a steam stream into the heated chamber. The thermal recovery methods further include producing a chamber liquid and/or mobilized viscous hydrocarbons from the subterranean formation.
E21B 43/241 - Procédés de récupération assistée pour l'extraction d'hydrocarbures utilisant la chaleur, p.ex. injection de vapeur combinés avec une exploitation au moyen de solvants de matières minérales autres que des hydrocarbures, p.ex. pyrolyse de schistes bitumineux au moyen de solvants
E21B 43/24 - Procédés de récupération assistée pour l'extraction d'hydrocarbures utilisant la chaleur, p.ex. injection de vapeur
78.
SELF-SOURCED RESERVOIR FLUID FOR ENHANCED OIL RECOVERY
Disclosed techniques include a method of obtaining an enhanced oil recovery fluid from a hydrocarbon reservoir, comprising producing a hydrocarbon stream (102) from the hydrocarbon reservoir (104), separating an associated gas stream (118) from the hydrocarbon stream (102), and condensing at least a portion of the associated gas stream (118) to obtain an enriched hydrocarbon fluid (124) suitable for injecting into a liquid layer (108) of the hydrocarbon reservoir (104) to enhance recovery of hydrocarbons from the hydrocarbon reservoir.
A method including providing an oil sand tailings stream and introducing a polysaccharide into the oil sand tailings stream to assist fines capture in a resultant treated oil sand tailings stream.
C10G 1/04 - Production de mélanges liquides d'hydrocarbures à partir de schiste bitumineux, de sable pétrolifère ou de matières carbonées solides non fusibles ou similaires, p.ex. bois, charbon par extraction
B03B 9/02 - Disposition générale d'un atelier de séparation, p.ex. schéma opératoire spécialement adapté aux séparations pétrole/sable, pétrole/craie, pétrole/schistes, ozokérite, bitume ou similaires
80.
APPARATUS AND SYSTEM FOR SWING ADSORPTION PROCESSES RELATED THERETO
Provided are apparatus and systems for performing a swing adsorption process. This swing adsorption process may involve passing streams through adsorbent bed units to remove contaminants, such as water, from the stream. As part of the process, the adsorbent bed unit may provide access to the adsorbent material within the adsorbent bed unit without having to remove one or more of valves, conduits and manifolds.
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
Methods to optimize solvent use in solvent-dominated processes for recovery of hydrocarbons are disclosed herein. In some embodiments, disclosed methods include injecting a solvent composition into a reservoir at a pressure above a liquid/vapor phase change of the solvent composition; injecting a chaser into the reservoir at a pressure above the liquid/vapor phase change of the solvent composition; allowing the solvent composition to mix with hydrocarbons in the reservoir and at least partially dissolve into the hydrocarbons to produce a solvent/hydrocarbon mixture; reducing the pressure in the reservoir below the liquid/vapor phase change pressure of the solvent composition thereby flowing at least a fraction of the solvent/hydrocarbon mixture from the reservoir; and repeating these steps as required.
A method comprising: a) providing an oil sand slurry stream; b) adding a process aid to the oil sand slurry stream; c) processing the oil sand slurry stream into bitumen froth, fine tailings (FT), and coarse sand tailings (CST), including using a primary separation cell (PSC); d) measuring a water chemistry parameter of at least one of the oil sand slurry stream, the FT, the CST, the bitumen froth, middlings from the PSC, and a middling layer inside the PSC; and e) based on the measured water chemistry parameter, adjusting at least one of a dosage of the process aid added to the oil sand slurry stream, process temperature, mixing conditions, oil sand slurry stream composition, and water addition to the PSC.
The apparatus and systems are for removing contaminants from an exhaust stream. The process may involve passing at least a portion of an exhaust stream through a cooling component, which draws a cooling stream into the cooling component. The cooling stream interacts with the at least a portion of the exhaust stream to form a mixed stream. The resulting mixed stream is a lower temperature than the at least portion of the exhaust stream.
Disclosed is a water-based oil sand extraction method including introducing a feed stream comprising bitumen, solids, and water into an extraction vessel; and introducing a froth overwash into the extraction vessel above a froth layer in the extraction vessel for facilitating solids removal from the froth layer.
A method to drill a borehole or wellbore through an earthen formation using a drill bit on a drillstring, comprising the steps of: selecting a frequency-domain dynamic model of a drilling assembly that describes the dynamic response of the drilling assembly to excitation at an excitation frequency for operating at a set of selected drilling parameters that include at least rotary speed and weight on bit; calculating a composite vibration index by combining calculated vibration indices for each excitation frequency with the spectral weighting factors for each of the drilling parameter partitions; displaying said composite vibration index for each of the drilling parameter partitions; selecting preferred drilling parameters based on the displayed results, and using the preferred drilling parameters to drill a borehole with the modeled drilling assembly.
E21B 44/00 - Systèmes de commande automatique spécialement adaptés aux opérations de forage, c. à d. systèmes à fonctionnement autonome ayant pour rôle d'exécuter ou de modifier une opération de forage sans l'intervention d'un opérateur humain, p.ex. systèmes de ; Systèmes spécialement adaptés à la surveillance de plusieurs variables ou conditions de forage
E21B 47/007 - Mesure des contraintes dans le cuvelage ou la tige de forage
E21B 45/00 - Mesure du temps de forage ou de la vitesse de pénétration
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
86.
PRE-COOLING OF NATURAL GAS BY HIGH PRESSURE COMPRESSION AND EXPANSION
A method of producing liquefied natural gas (LNG) is disclosed. A natural gas stream is provided from a supply of natural gas. The natural gas stream is compressed in at least two serially arranged compressors (102,112) to a pressure of at least 138 bara (2,000 psia) to form a compressed natural gas stream (114). The compressed natural gas stream is cooled (116) to form a cooled compressed natural gas stream (118). The cooled compressed natural gas stream is expanded in at least one work producing natural gas expander (120) to a pressure that is less than 207 bara (3,000 psia) and no greater than the pressure to which the at least two serially arranged compressors compress the natural gas stream, to thereby form a chilled natural gas stream (122). The chilled natural gas stream is 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
87.
EXPANDER-BASED LNG PRODUCTION PROCESSES ENHANCED WITH LIQUID NITROGEN
A method for producing liquefied natural gas (LNG). A natural gas stream is directed to a mechanical refrigeration unit to liquefy the natural gas stream and form a pressurized liquefied natural gas (LNG) stream with a pressure greater than 50 psia (345 kPa) and less than 500 psia (3445 kPa). A liquid refrigerant subcooling unit is provided at a first location. Liquid refrigerant is produced at a second location that is geographically separate from the first location. The produced liquid refrigerant is transported to the first location. The pressurized LNG stream is subcooled in the liquid refrigerant subcooling unit by exchanging heat between the pressurized LNG stream and at least one stream of the liquid refrigerant to thereby produce an LNG stream.
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 1/00 - Procédés ou appareils de liquéfaction ou de solidification des gaz ou des mélanges gazeux
88.
METHOD OF NATURAL GAS LIQUEFACTION ON LNG CARRIERS STORING LIQUID NITROGEN
A method for producing liquefied natural gas (LNG). A natural gas stream is transported to a liquefaction vessel. The natural gas stream is liquefied on the liquefaction vessel using at least one heat exchanger that exchanges heat between the natural gas stream and a liquid nitrogen stream to at least partially vaporize the liquefied nitrogen stream, thereby forming a warmed nitrogen gas stream and an at least partially condensed natural gas stream comprising LNG. The liquefaction vessel includes at least one tank that only stores liquid nitrogen and at least one tank that only stores LNG.
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 1/00 - Procédés ou appareils de liquéfaction ou de solidification des gaz ou des mélanges gazeux
89.
METHOD AND SYSTEM FOR SEPARATING NITROGEN FROM LIQUEFIED NATURAL GAS USING LIQUEFIED NITROGEN
A method for separating nitrogen from an LNG stream with a nitrogen concentration of greater than 1 mo1%. A pressurized LNG stream is produced at a liquefaction facility by liquefying natural gas, where the pressurized LNG stream has a nitrogen concentration of greater than 1 mo1%. At least one liquid nitrogen (LIN) stream is received from storage tanks, the at least one LIN stream being produced at a different geographic location from the LNG facility. The pressurized LNG stream is separated in a separation vessel into a vapor stream and a liquid stream. The vapor stream has a nitrogen concentration greater than the nitrogen concentration of the pressurized LNG stream. The liquid stream has a nitrogen concentration less than the nitrogen concentration of the pressurized LNG stream. At least one of the one or more LIN streams is directed to the separation vessel.
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 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
Provided are methods of estimating a volume of a biogenic gas for an area of interest. The method includes predicting a methanogenesis rate for one or more of the periods of time for the area of interest based on energy available for microbial activity and calculating the volume of the biogenic gas based on the predicted methanogenesis rate for the one or more of the periods of time for the area of interest.
An oil-in-water monitoring (OIWM) system (200) for monitoring an oil-in-water concentration of treated water in a subsea processing system. The system includes a first OIWM portion (220) including a separation component (222) configured to separate the treated water stream (218) into a separated oil portion (232) and a separated water portion (238) which has a plenum (228) including the separated oil portion and the separated water portion. A separation component instrument (230) is operatively coupled to the plenum. The system also includes at least two of: an oil line instrument (234) operatively coupled to an oil line, a water line instrument (240) operatively coupled to a water line, and an inlet line instrument (225) operatively coupled to the inlet line. A computational device (223) is configured to output an oil-in-water concentration of the inlet treated water stream using the parameters measured by the separation component instrument and at least two of the other instruments. Methods using such systems are also disclosed.
Select-fire, downhole shockwave generation devices (190), hydrocarbon wells that include the shockwave generation devices, and methods of utilizing the same are disclosed herein. The shockwave generation devices (190) are configured to generate a shockwave (194) within a wellbore fluid that extends within a tubular conduit (40) of a wellbore tubular. The shockwave generation devices include a core, a plurality of explosive charges arranged on an external surface of the core, and a plurality of triggering devices. Each of the plurality of triggering devices is associated with a selected one of the plurality of explosive charges and is configured to selectively initiate explosion of the selected one of the plurality of explosive charges. The methods include methods of generating a shockwave utilizing the downhole shockwave generation devices.
Wellbore tubulars including a plurality of selective stimulation ports and methods of utilizing the same are disclosed herein. The wellbore tubulars include a tubular body (40) including an external surface and an internal surface that defines a tubular conduit. The wellbore tubulars also include a plurality of selective stimulation ports (100), and each selective stimulation port includes an SSP conduit and an isolation device that is configured to selectively transition from a closed state to an open state responsive to a shockwave having greater than a threshold shockwave intensity. The methods include methods of stimulating a subterranean formation utilizing the wellbore tubulars. The methods also include methods of re-stimulating the subterranean formation utilizing the wellbore tubulars.
Selective stimulation ports including sealing device retainers and methods of utilizing the same are disclosed herein. The selective stimulation ports (SSPs) are configured to be operatively attached to a wellbore tubular that defines a tubular conduit. The SSPs include an SSP conduit, which extends at least substantially perpendicular to a wall of the wellbore tubular, and a sealing device receptacle, which defines at least a portion of the SSP conduit and is sized to receive a sealing device. The SSPs also include a sealing device seat, which is shaped to form a fluid seal with the sealing device. The SSPs further include a sealing device retainer, which is configured to retain the sealing device within the sealing device receptacle. The methods include methods of stimulating the hydrocarbon well utilizing the SSPs and/or methods of conveying a downhole tool within the hydrocarbon well utilizing the SSPs.
A pump system for submersing into a slurry, the pump system including a pump body having an inlet for receiving the slurry; and a plate for mitigating coning, the plate being disposed adjacent the inlet and extending outwardly from the pump body. A method including submersing the pump system into a slurry; and pumping the slurry through the pump system. An apparatus for mitigating coning around a submersible pump, the submersible pump comprising a pump body having an inlet, the apparatus including a plate for mitigating coning around the submersible pump in use, the plate being for disposing adjacent the inlet and extending outwardly from the pump body; and a plate positioning structure for holding the plate in position.
F04D 7/04 - Pompes adaptées à la manipulation de liquides particuliers, p.ex. par choix de matériaux spéciaux pour les pompes ou pièces de pompe du type centrifuge les fluides étant visqueux ou non homogènes
F04D 13/08 - Ensembles comprenant les pompes et leurs moyens d'entraînement la pompe étant entraînée par l'électricité pour utilisation en position immergée
F04D 29/66 - Lutte contre la cavitation, les tourbillons, le bruit, les vibrations ou phénomènes analogues; Equilibrage
96.
DOWNHOLE GAS SEPARATORS AND METHODS OF SEPARATING A GAS FROM A LIQUID WITHIN A HYDROCARBON WELL
Downhole gas separators, artificial lift systems including the downhole gas separators, hydrocarbon wells including the artificial lift systems, and methods of separating a gas from a liquid hydrocarbon within a hydrocarbon well. The downhole gas separators include an elongate outer housing that defines an enclosed volume, a fluid inlet port, and a gas outlet port. The downhole gas separators further include an elongate dip tube that extends within the enclosed volume, and the gas outlet port is configured to selectively provide fluid communication between the enclosed volume and an external region.
A method for evaluating annulus-tubing communication points in a production well having an annulus between a production string and a surrounding string(s) of casing. Determining a composition of production fluids produced from the well, and injecting one or more tracer materials into the annulus of the well under pressure as part of a lift gas. Each of the one or more tracer materials defines a material that is not native to the production fluids, and each has a different rate of diffusivity in the lift gas. The tracer materials are detected upon being produced at the surface. A mass spectrometer or other analyzer capable of detecting tracer materials at concentrations of less than 1,000 ppm is used. Determining injection points of the one or more tracer materials, and determining whether each of the injection points represents a gas lift valve along the production tubing.
A method of designing, constructing, and operating a hydrocarbon gas treatment plant is disclosed. A target hydrocarbon production range for a hydrocarbon gas meeting a required product specification is established. A cryogenic distillation column is designed and constructed with a vapor capacity to meet the target hydrocarbon production range. A variable feed refrigeration system is incorporated to cool an inlet feed of the hydrocarbon gas. The variable feed refrigeration system is designed to handle the target hydrocarbon production range and a wide range of contaminant concentrations in the inlet feed. A variable bottoms heating system is incorporated to handle heating duties associated with the wide range of contaminant concentrations in the inlet feed. A variable bottoms pumping system is incorporated to handle liquid flows associated with the wide range of contaminant concentrations in the inlet feed.
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
99.
APPARATUS AND SYSTEM FOR SWING ADSORPTION PROCESSES RELATED THERETO
Provided are apparatus and systems for performing a swing adsorption process. This swing adsorption process may involve passing streams through adsorbent bed units to remove contaminants, such as water, from the stream. As part of the process, the adsorbent bed unit is purged with a purge stream that is provided from the overhead of the demethanizer. The configuration integrates a PPSA dehydration system with a cryogenic recovery system.
B01D 53/04 - SÉPARATION Épuration chimique ou biologique des gaz résiduaires, p.ex. gaz d'échappement des moteurs à combustion, fumées, vapeurs, gaz de combustion ou aérosols par adsorption, p.ex. chromatographie préparatoire en phase gazeuse avec adsorbants fixes
B01D 53/28 - Emploi de substances spécifiées comme agents desséchants
C10L 3/10 - Post-traitement de gaz naturel ou de gaz naturel de synthèse
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
100.
EXPLORATION METHOD AND SYSTEM FOR DETECTION OF HYDROCARBONS FROM THE WATER COLUMN
A method for detecting hydrocarbons is described. The method includes obtaining seismic data associated with a body of water in a survey region, filtering the seismic data to enhance diffraction anomaly signals (1103) with respect to horizontal or nearly horizontal signals associated with the water column, analyzing the seismic data to identify at least one noise indicator (1106, 1107, 1108, 1109, 1111) to produce a noise indicator image; and determining seepage locations (1103) by comparing the at least one noise indicator image to the filtered seismic data.
brevets
