Systems, methods, and devices for providing a joining technique for a metal part and a composite part. The joining technique in which either the metal or the composite part has at least one portion receive a laser etching treatment according at least in part to a laser configuration. Further, the joining technique in which the metal and composite parts are positioned to contact at least one etched surface. Even further, the joining technique in which a joining process is used to join the metal part and composite part to produce a unitary structure.
B32B 38/00 - Opérations auxiliaires liées aux procédés de stratification
B32B 37/06 - Procédés ou dispositifs pour la stratification, p. ex. par polymérisation ou par liaison à l'aide d'ultrasons caractérisés par le procédé de chauffage
F17C 1/00 - Récipients sous pression, p. ex. bouteilles de gaz, réservoirs de gaz, cartouches échangeables
2.
SYSTEMS AND METHODS FOR JOINING COMPOSITE STRUCTURES TO METAL STRUCTURES
Systems, methods, and devices for providing a joining technique for a metal part and a composite part. The joining technique in which either the metal or the composite part has at least one portion receive a laser etching treatment according at least in part to a laser configuration. Further, the joining technique in which the metal and composite parts are positioned to contact at least one etched surface. Even further, the joining technique in which a joining process is used to join the metal part and composite part to produce a unitary structure.
It is described a subsea electro-hydraulic actuator (100) for operating a biased fail-safe safety valve (500) in a subsea hydrocarbon production and/or processing system, the safety valve (500) being operable between an active position and a fail-safe position, the actuator (100) comprising: - a piston assembly (200) comprising a piston rod (210) configured to operate the safety valve (500); - a hydraulic reservoir (110); - a hydraulic pump (130) being hydraulically connected to the hydraulic reservoir (110); - a check valve (140) being hydraulically connected, at first port (141), to the hydraulic pump (130) and being hydraulically connected, at a second port (142), to the piston assembly (200); - dump valve (150) being operable between an open position and a closed position and hydraulically connected, at first port (153), to the piston assembly (200) and, at a second port (154), to the hydraulic reservoir (110), the dump valve (150) comprising a solenoid (151), the solenoid (151) being configured, when energised, to hold the dump valve (150) in the closed position, and, when deenergised, to allow the dump valve (150) to be brought to the open position to allow the safety valve (500) to be brought to the fail-safe position; wherein an accumulator (300) is hydraulically connected to the second port (142) of the check valve (140) and to the first port (153) of the dump valve (150). It is further described a subsea assembly comprising a biased fail-safe safety valve (500) and the subsea electro-hydraulic actuator (100).
F15B 1/02 - Installations ou systèmes comprenant des accumulateurs
F15B 20/00 - Dispositions propres à la sécurité pour systèmes de manœuvre utilisant les fluidesUtilisation des dispositifs de sécurité dans les systèmes de manœuvre utilisant des fluidesMesures d'urgence pour les systèmes de manœuvre utilisant des fluides
4.
METHODS OF PRODUCING A PRESSURE CONTAINING STRUCTURE FROM RECYCLED COMPOSITE PARTS AND PRESSURE CONTAINING PIPE
Systems, methods, and devices for providing a low permeability pressure containing structure from high performance recycled composite material, such as polymer carbon fiber composite. One or more recycled scrap composite parts are mechanically processed to form a plurality of fragments based on protected carbon fiber, which are then formed into the pressure containing structure. The distribution of the plurality of fragments and fibers included therein generate a tortuous effect that decreases the permeability of the pressure containing structure, such that the pressure containing structure is suitable for transporting and storing gases and other fluids that may corrode traditional steel pressure structures.
B29B 17/00 - Récupération de matières plastiques ou d'autres constituants des déchets contenant des matières plastiques
B29B 17/04 - Désintégration des matières plastiques
B29C 45/00 - Moulage par injection, c.-à-d. en forçant un volume déterminé de matière à mouler par une buse d'injection dans un moule ferméAppareils à cet effet
B29C 48/00 - Moulage par extrusion, c.-à-d. en exprimant la matière à mouler dans une matrice ou une filière qui lui donne la forme désiréeAppareils à cet effet
B29C 48/09 - Objets dont la section transversale comporte des cavités partiellement ou entièrement fermées, p. ex. tuyaux ou canaux
B29C 64/153 - Procédés de fabrication additive n’utilisant que des matériaux solides utilisant des couches de poudre avec jonction sélective, p. ex. par frittage ou fusion laser sélectif
F16L 9/12 - Tuyaux rigides en plastique avec ou sans armature
5.
SUBSEA ELECTRO-HYDRAULIC ACTUATOR WITH HYDRAULIC OPERATION OF DUMP VALVE FROM OPEN TO CLOSED POSITION, AND A DUMP VALVE SYSTEM WITH A SOLENOID
A subsea electro-hydraulic actuator (100) for operating a biased fail-safe safety valve (500) in a subsea hydrocarbon production and/or processing system, the safety valve (500) being operable between an active position and a fail-safe position, the actuator (100) comprising: - a piston assembly (200) comprising a piston rod (210) configured to operate the safety valve (500); - a hydraulic reservoir (110); - a hydraulic pump (130) being hydraulically connected to the hydraulic reservoir (110); - a check valve (140) being hydraulically connected, at a first port (141), to the hydraulic pump (130) and being hydraulically connected, at a second port (142), to the piston assembly (200); - a dump valve (150) being operable between an open position and a closed position and hydraulically connected, at first port (153), to the piston assembly (200) and, at a second port (154), to the hydraulic reservoir (110), the dump valve (150) comprising a solenoid (151), the solenoid (151) being configured, when energised, to hold the dump valve (150) in the closed position, and, when deenergised, to allow the dump valve (150) to be brought to the open position to allow the safety valve (500) to be brought to the fail-safe position; wherein the dump valve (150) being hydraulically connectable, at a pilot port (152), to the hydraulic pump (130) to allow hydraulic fluid from the hydraulic pump (130) to operate the dump valve (150) from the open position to the closed position. It is further described an associated subsea assembly as well as a dump valve system comprising: - a dump valve (150) being operable between an open position and a closed position, the dump valve (150) comprising a solenoid (151), the solenoid (151) being configured, when energised, to hold the dump valve (150) in the closed position, and, when deenergised, to allow the dump valve (150) to be brought to the open position; - activation means (130) for operating the dump valve (150) from the open position to the closed position.
F15B 1/02 - Installations ou systèmes comprenant des accumulateurs
F15B 20/00 - Dispositions propres à la sécurité pour systèmes de manœuvre utilisant les fluidesUtilisation des dispositifs de sécurité dans les systèmes de manœuvre utilisant des fluidesMesures d'urgence pour les systèmes de manœuvre utilisant des fluides
F15B 13/042 - Dispositifs de distribution ou d'alimentation du fluide caractérisés par leur adaptation à la commande de servomoteurs pour utilisation avec un servomoteur unique actionnés par la pression du fluide
F15B 13/044 - Dispositifs de distribution ou d'alimentation du fluide caractérisés par leur adaptation à la commande de servomoteurs pour utilisation avec un servomoteur unique actionnés par des moyens commandés électriquement, p. ex. des solénoïdes, des moteurs à couple
F15B 13/04 - Dispositifs de distribution ou d'alimentation du fluide caractérisés par leur adaptation à la commande de servomoteurs pour utilisation avec un servomoteur unique
6.
LOW PERMEATION STRUCTURES FROM RECYCLED COMPOSITE MATERIAL
Systems, methods, and devices for providing a low permeability pressure containing structure from high performance recycled composite material, such as polymer carbon fiber composite. One or more recycled scrap composite parts are mechanically processed to form a plurality of fragments based on protected carbon fiber, which are then formed into the pressure containing structure. The distribution of the plurality of fragments and fibers included therein generate a tortuous effect that decreases the permeability of the pressure containing structure, such that the pressure containing structure is suitable for transporting and storing gases and other fluids that may corrode traditional steel pressure structures.
B29C 48/00 - Moulage par extrusion, c.-à-d. en exprimant la matière à mouler dans une matrice ou une filière qui lui donne la forme désiréeAppareils à cet effet
B29B 17/04 - Désintégration des matières plastiques
B29C 48/09 - Objets dont la section transversale comporte des cavités partiellement ou entièrement fermées, p. ex. tuyaux ou canaux
B33Y 70/10 - Composites de différents types de matériaux, p. ex. mélanges de céramiques et de polymères ou mélanges de métaux et de biomatériaux
B33Y 80/00 - Produits obtenus par fabrication additive
F16L 9/12 - Tuyaux rigides en plastique avec ou sans armature
F16L 9/133 - Tuyaux rigides en plastique avec ou sans armature les parois étant constituées de deux couches
7.
Pump comprising a balance arrangement and a related method
A pump (110) is disclosed comprising: an inlet (114) being in fluid communication with an inlet cavity (115); an outlet (118) being in fluid communication with an outlet cavity (119); a motor (120) being arranged in a motor cavity (121); a pump axis (122) being rotatably drivable by the motor: impellers (124) being positioned between the inlet cavity and the outlet cavity and being actuatable by the pump axis to cause a differential pressure across the inlet cavity and the outlet cavity; and a balance arrangement (126) configured to at least partially offset an axial thrust affected upon the axis by the impellers when the pump is in operation, the balance arrangement comprising: a balance cavity (132); a balance drum (128) arranged between the outlet cavity and the balance cavity; and a balance line (134) extending between and fluidly connecting the balance cavity and the inlet cavity. The inlet is in fluid communication with the inlet cavity via the balance cavity and the balance line. A related method is also disclosed.
One illustrative production/annulus bore stab disclosed herein includes a one-piece body that comprises a first cylindrical outer surface and a second cylindrical outer surface and a plurality of individual fluid flow paths defined entirely within the one-piece body. In this illustrative example, each of the individual fluid flow paths is fluidly isolated from one another and each of the fluid flow paths comprise a first inlet/outlet at a first end of the fluid flow path that is positioned in the first cylindrical outer surface and a second inlet/outlet at a second end of the fluid flow path that is positioned in the second cylindrical outer surface.
A system may have a built hydraulic fracturing system with a plurality of devices connected together and in fluid communication with one or more wells. The system may also include at least one continuous pumping operations for one or more wells and a fracturing pumping plan provided on a software application. The fracturing plan may include instructions to perform at least one continuous pumping operations for the one or more wells. The instructions may include a sequence of valve operations to direct fluid flow through a selected path into the one or more wells.
A wellhead assembly (10) includes a casing head (16) configured to be mounted on a surface casing (12); a casing spool (18) mounted on the casing head and including a plurality of axially offset first through bores, each of which includes an annular first seat; a plurality of first casing hangers (36), each of which is supported on a corresponding first seat and configured to suspend a respective production casing through the surface casing; a tubing head (20) mounted on the casing spool and including a plurality of axially offset second through bores, each of which is aligned with a corresponding first through bore and each of which includes an annular second seat; and a plurality of tubing hangers, each of which includes an axial tubing hanger bore and each of which is supported on a corresponding second seat and is configured to suspend a respective production tubing through a corresponding production casing.
Systems, methods, and at least one seal pocket detection assembly configured to be placed within a pressure cavity of a well tubing system. The seal pocket detection assembly (214) includes a selectively removable insert body (302) supporting one or more seals (308) and one or more coils (304.306) that produce an electromagnetic field extending into the bore of tubing sections of the well tubing system. The seal pocket detection assembly is configured to detect a ferrous object (112) passing through the bore (206).
E21B 47/01 - Dispositifs pour supporter des instruments de mesure sur des trépans, des tubes, des tiges ou des câbles de forageProtection des instruments de mesure dans les trous de forage contre la chaleur, les chocs, la pression ou similaire
E21B 47/092 - Localisation ou détermination de la position d'objets dans les trous de forage ou dans les puitsIdentification des parties libres ou bloquées des tubes par détection d'anomalies magnétiques
A flexible pipe includes one or more outer layers, a primary liner disposed internal to the one or more outer layers, and a removable liner disposed internal to the primary liner. Additionally, a flexible piping system includes the flexible pipe with a first end and a second end. Further, an annulus is disposed between the primary liner and the removable liner. Furthermore, a pressure port is provided and extends from the annulus to an outer surface of the flexible piping system. An end fitting is disposed at the first end of the flexible pipe.
Systems, methods, and at least one seal pocket detection assembly configured to be placed within a pressure cavity of a well tubing system. The seal pocket detection assembly includes a selectively removable insert body supporting one or more seals and one or more coils that produce an electromagnetic field extending into the bore of tubing sections of the well tubing system. The seal pocket detection assembly is configured to detect a ferrous object passing through the bore.
G01V 3/10 - Prospection ou détection électrique ou magnétiqueMesure des caractéristiques du champ magnétique de la terre, p. ex. de la déclinaison ou de la déviation fonctionnant au moyen de champs magnétiques ou électriques produits ou modifiés par les objets ou les structures géologiques, ou par les dispositifs de détection en utilisant des cadres inducteurs
A torque limiter includes a housing; an input shaft which is rotatably supported in the housing; an output shaft which is rotatably supported in the housing coaxially with the input shaft; and a ball detent mechanism which is connected between adjacent ends of the input and output shafts. The ball detent mechanism includes a ball ring and has a plurality of ball members; a detent ring which is connected to the input shaft and has a plurality of detents which are configured to receive the ball members; and a biasing member which is positioned on a side of the ball ring opposite the detent ring. The biasing member is operatively engaged with the ball members so as to bias the ball members in a direction toward the detent ring and is designed to generate a force sufficient to maintain the ball members seated in the detents when a torque less than a predetermined torque is applied to the input shaft.
F16D 7/08 - Accouplements à glissement, p. ex. glissant en cas de surcharge, pour absorber les chocs du type à rochet avec billes ou rouleaux intermédiaires se déplaçant axialement entre l'engagement et le désengagement
F16D 43/206 - Embrayages automatiques à commande interne actionnés entièrement mécaniquement commandés par le couple, p. ex. embrayages à déclenchement en cas de surcharge, embrayages à glissement avec dispositifs par lesquels le couple fait varier la pression d'embrayage du type à rochet avec des billes ou des rouleaux intermédiaires se déplaçant axialement entre l'engagement et le désengagement
A system (1) for testing equipment for gas containment is disclosed and comprises a test specimen fixture (3) for coupling thereto a specimen to be tested for gas containment, a test gas source vessel (5), an accumulator (7) and a fluid communication line (9) between the test gas source vessel (5) and the accumulator (7). The accumulator (7) comprises a test gas chamber (11) for receiving and holding a pre-determined amount of test gas from the test gas source vessel (5) and a piston (15) movable within the test gas chamber (11) to compress or de-compress the test gas. The accumulator (7) is in fluid communication with the test specimen fixture (3). The piston (15) is actuatable so as to compress the pre-determined amount of test gas to a pre-determined pressure and provide the compressed test gas to the test specimen fixture (3). A first shut off valve (19) is provided in the fluid communication line (9) between the test gas source vessel (5) and the accumulator (7) for closing off the test gas source vessel (5) when performing testing.
G01M 3/22 - Examen de l'étanchéité des structures ou ouvrages vis-à-vis d'un fluide par utilisation d'un fluide ou en faisant le vide par détection de la présence du fluide à l'emplacement de la fuite en utilisant des révélateurs particuliers, p. ex. teinture, produits fluorescents, produits radioactifs pour tuyaux, câbles ou tubesExamen de l'étanchéité des structures ou ouvrages vis-à-vis d'un fluide par utilisation d'un fluide ou en faisant le vide par détection de la présence du fluide à l'emplacement de la fuite en utilisant des révélateurs particuliers, p. ex. teinture, produits fluorescents, produits radioactifs pour raccords ou étanchéité de tuyauxExamen de l'étanchéité des structures ou ouvrages vis-à-vis d'un fluide par utilisation d'un fluide ou en faisant le vide par détection de la présence du fluide à l'emplacement de la fuite en utilisant des révélateurs particuliers, p. ex. teinture, produits fluorescents, produits radioactifs pour soupapes
G01M 3/32 - Examen de l'étanchéité des structures ou ouvrages vis-à-vis d'un fluide par utilisation d'un fluide ou en faisant le vide par mesure du taux de perte ou de gain d'un fluide, p. ex. avec des dispositifs réagissant à la pression, avec des indicateurs de débit pour récipients, p. ex. radiateurs
16.
SINGLE RUN PRELOADED CASING HANGER AND ANNULUS SEAL ASSEMBLY AND METHODS OF USE THEREOF
A running tool (87) having an annulus seal assembly (86) and casing hanger (89) attached thereto may be sent into to the wellhead (1) to lock and preload the casing hanger (89) in a single trip. The running tool (87) may be rotated a first time to drop the annulus seal assembly on the casing hanger (89), a first pressure may be applied axially above the annulus seal assembly to set the annulus seal assembly, the running tool may be rotated a second time to close a gap between the annulus seal assembly and the wellhead, and a second pressure may be applied axially above the annulus seal assembly to preload the casing hanger.
A method for storing hydrogen in a plurality of subsea storages in a system. The system comprising an electrolyser source (100) for producing hydrogen at a source pressure; a downstream compressor (200) for compressing the hydrogen from the source pressure to a compressed higher pressure; and a plurality of storages (300) each for storing compressed hydrogen at the compressed higher pressure and each being subsea. The method comprising at least the steps of: producing hydrogen (1000) by the electrolyser source (100) at the source pressure; passing the hydrogen (2000) to the plurality of storages (300) through a bypass line (210) around the compressor (200); and storing the hydrogen (3000) in at least one of the plurality of storages (300) at a first pressure below the compressed higher pressure. A system for storing hydrogen in a plurality of subsea storages, the system comprising: an electrolyser source (100) for producing hydrogen at a source pressure; a downstream compressor (200) for compressing the hydrogen from the source pressure to a compressed higher pressure; a plurality of storages (300) each for storing compressed hydrogen at the compressed higher pressure and each being subsea; and a controller (400) for controlling the electrolyser source (100), the downstream compressor (200), and valves (310) to the plurality of storages (300). The controller (400) is configured for controlling the system in, at least, two alternative ways: A) passing the hydrogen, produced by the electrolyser source (100) at the source pressure, to the compressor (200), compressing the hydrogen by the compressor (200) to a compressed higher pressure, and passing the hydrogen, at the compressed higher pressure, from the compressor (200) to at least one of the plurality of subsea storages (300); and B) passing the hydrogen, produced by the electrolyser source (100) at the source pressure, to at least one of the plurality of storages (300), through a bypass line (210) around the compressor (200) at a first pressure below the compressed higher pressure.
A method of changing from a hydraulic operated X-mas tree to an electric operated X-mas tree. The X-mas tree comprising at least one hydraulic operated actuator (200) for a valve (110) in the X-mas tree, wherein a spring (210) in the hydraulic operated actuator (200) provides a fail-safe function for closing the valve (110). The X-mas tree further comprising a hydraulic control system (430) with a compensator (450). The method comprises adding (510) a linear electric operated actuator (300) to the hydraulic operated actuator (200) to actuate the valve (110); using (520) only the spring (210) of the hydraulic operated actuator (200) to provide the fail-safe function for closing the valve (110); adding (530) an electric control module (470) to the X-mas tree; and providing (540) means to interconnect all internal chambers (240) in the hydraulic operated actuator (200) to the compensator (450). A system for changing from a hydraulic operated X- mas tree to an electric operated X-mas tree, and vice versa, is also disclosed. The system comprises a X-mas tree (100) comprising at least one hydraulic operated actuator (200) for a valve (110) in the X-mas tree, wherein a spring (210) in the hydraulic operated actuator (200) provides a fail-safe function for closing the valve (110); a linear electric operated actuator (300) releasable coupled to the hydraulic operated actuator (200), the linear electric operated actuator (300) being configured for opening or closing the valve (110); and means to interconnect all internal chambers (240) in the hydraulic operated actuator (200) to a compensator (450), for hydraulics, of the X-mas tree (100).
E21B 41/04 - Manipulateurs pour opérations sous l'eau, p. ex. reliés temporairement aux têtes de puits
F15B 15/18 - Ensembles combinés comportant moteur et pompe
F16K 3/02 - Robinets-vannes ou tiroirs, c.-à-d. dispositifs obturateurs dont l'élément de fermeture glisse le long d'un siège pour l'ouverture ou la fermeture à faces d'obturation planesGarnitures d'étanchéité à cet effet
F15B 17/00 - Combinaisons de systèmes de télémoteurs et de servomoteurs
A retrievable umbilical termination module (UTM) is provided for a power distribution system. The UTM (30) includes a first wet-mate connector (32) directly connectable to a subsea transformer module (20), and a second connector (34) connectable to one or more offshore power generating apparatus (10). The first and second connectors (32,34) are electrically connected to one another. The UTM (30) further comprises an integrated switchgear (50) or disconnection switch that is adapted to selectively control the flow of power from the second connector (34) to the first connector (32). A subsea power system comprising the UTM, as well as methods for installing and retrieving the UTM, are also provided.
A pumpdown system for use in performing wireline operations on a well bore includes a wellhead assembly positioned at the top of the well bore, a pumpdown fluid source, a flowline having a first end connected to the pumpdown fluid source and an opposite second end, and a wireline pressure control string releasably connectable to the wellhead assembly. The wireline pressure control string includes a pumpdown sub having a body and a through bore which extends through the body, at least one pumpdown valve having an inlet connected to the second end of the flowline and an outlet in fluid communication with the through bore, and a connector positioned below the pumpdown assembly for releasably securing the wireline pressure control string to the wellhead assembly. In operation of the pumpdown system, the wireline pressure control string is connected to the wellhead assembly and fluid from the pumpdown fluid source is conveyed through the flowline, the pumpdown valve and the pumpdown sub into the well bore.
E21B 23/08 - Introduction ou circulation d'outils par pression de fluide, p. ex. systèmes d'outils mis en place par un courant de fluide
E21B 23/04 - Appareils pour déplacer, mettre en place, verrouiller, libérer ou retirer, les outils, les packers ou autres éléments dans les trous de forage mis en œuvre à l'aide de moyens fluides, p. ex. actionnés par explosion
E21B 33/072 - Têtes de puitsLeur mise en place comportant des dispositions pour introduire des objets dans les puits ou pour les en retirer, ou pour y introduire des fluides pour les outils manœuvrés par câbles
E21B 34/02 - Aménagements des vannes pour les trous de forage ou pour les puits dans les têtes de puits
21.
INTEGRATED CARBON SEQUESTRATION INJECTION CONTROL SYSTEM
Systems and methods for an integrated control system of a carbon sequestration injection system. The integrated control system receives information from fiber-optic sensing elements disposed within a sub-surface portion of the injection system such that operation of the surface injection equipment is automatically adjusted in real-time based on sub-surface parameters detected by the fiber-optic sensing elements.
E21B 41/00 - Matériel ou accessoires non couverts par les groupes
G01K 11/32 - Mesure de la température basée sur les variations physiques ou chimiques, n'entrant pas dans les groupes , , ou utilisant des changements dans la transmittance, la diffusion ou la luminescence dans les fibres optiques
G01L 11/02 - Mesure de la pression permanente, ou quasi permanente d'un fluide ou d'un matériau solide fluent par des moyens non prévus dans les groupes ou par des moyens optiques
22.
INTEGRATED CARBON SEQUESTRATION INJECTION CONTROL SYSTEM
Systems and methods for an integrated control system of a carbon sequestration injection system. The integrated control system receives information from fiber-optic sensing elements disposed within a sub-surface portion of the injection system such that operation of the surface injection equipment is automatically adjusted in real-time based on sub-surface parameters detected by the fiber-optic sensing elements.
E21B 43/16 - Procédés de récupération assistée pour l'extraction d'hydrocarbures
E21B 41/00 - Matériel ou accessoires non couverts par les groupes
E21B 47/06 - Mesure de la température ou de la pression
E21B 47/135 - Moyens pour la transmission de signaux de mesure ou signaux de commande du puits vers la surface, ou de la surface vers le puits, p. ex. pour la diagraphie pendant le forage par énergie électromagnétique, p. ex. gammes de fréquence radio utilisant des ondes lumineuses, p. ex. ondes infrarouges ou ultraviolettes
An annular seal element which includes a cylindrical seal body: first and second axially spaced sealing lips which are located on the seal body and are directed generally radially outwardly: first and second spaced-apart sealing flanges which extend radially outwardly from the seal body: and third and fourth sealing lips which are located on the first and second sealing flanges, respectively.
F16J 15/3232 - Joints d'étanchéité entre deux surfaces mobiles l'une par rapport à l'autre par joints élastiques, p. ex. joints toriques avec au moins une lèvre ayant plusieurs lèvres
One illustrative apparatus (1) disclosed herein includes a helix structure (20) that comprises at least at least one helical surface (15), a plurality of orientation slots (17) positioned around a perimeter of the helix structure, each of the orientation slots (17) being adapted to receive an orientation key (18), a component orientation slot (21) positioned adjacent a bottom end of the at least one helical surface (15) and a threaded bottom recess (43). The apparatus (1) also includes a threaded adjustable nut (30) that is adapted to be at least partially positioned in the bottom recess and threadingly coupled to the threaded bottom recess (43).
E21B 33/04 - Têtes de tubageSuspension des tubages ou des colonnes de production dans les têtes de puits
E21B 23/00 - Appareils pour déplacer, mettre en place, verrouiller, libérer ou retirer, les outils, les packers ou autres éléments dans les trous de forage
E21B 33/035 - Têtes de puitsLeur mise en place spécialement adaptées aux installations sous l'eau
A cap, for protecting a sealing surface area (12) of a riser unit (10). The cap comprises a body (200), a lock (300) and a fastener (400). The body (200) comprises a circumferential load shoulder (210) for an axial end of the riser unit (10), and a first area (220) with an inner profile. The lock (300) pivotally connected to the body (200), the lock (300) comprising a second area (320) with the inner profile. The fastener (400) for releasably fastening the lock (300) to the body (200) and thereby also, when in use, fastening the cap to the end of the riser unit (10). The cap comprises a first clearance (510) between the body (200) and the lock (300), the first clearance (510) extending in an axial direction of the body (200) and allowing thermal expansion of the body (200) and the lock (300).
A method involves obtaining current asset data for an asset, the current asset data including process data. The method further involves predicting, using a machine learning model, a methane emissions event associated with the asset, based on the current asset data, and reporting the predicted methane emissions event in a user visualization.
A system receives data from a submersible remote operated vehicle (ROV), the data being about the operation of an arm of the ROV. The system automatically controls, based on the data, movement of the arm in docking the arm to a tool holder. In certain instances, the system implements an image based control. In certain instances, the system implements a force accommodation control. In certain instances, the system implements both.
A method involves obtaining current asset data for an asset, the current asset data including process data. The method further involves predicting, using a machine learning model, a methane emissions event associated with the asset, based on the current asset data, and reporting the predicted methane emissions event in a user visualization.
A valve operating device (1) for operating a subsea valve (100), the valve operating device (1) comprises: —a housing (10); —thrust bearings (12) supported by the housing (10); —a chamber (20) within the housing (10), wherein the chamber (20) comprises a first part of a linear guide (21); —a rotational shaft (30) comprising a first end with an external interface (31) outside the chamber (20) and a second end inside the chamber (20), —a linear shaft (40) arranged within the chamber (20), the linear shaft (40) comprising a first portion (41) and a second portion (42), wherein the first portion (41) comprises threaded portion (43) connected to the threaded portion (34) of the rotational shaft (30) and wherein —the rotational shaft (30) comprises a pre-machined hole (36) extending over a part of an axial length of the rotational shaft (30).
A method includes providing a hydraulic connector having a hydraulic lock, wherein the hydraulic lock is operated using a hydraulic supply line and a hydraulic outlet line, and connecting the hydraulic connector to a component by activating the hydraulic lock. While the hydraulic lock is activated, a connection between the hydraulic connector and the component is pressure tested by directing a portion of the hydraulic fluid from the hydraulic supply line to a pressure testing system, using an intensifier in the pressure testing system to pressurize the portion of hydraulic fluid to a testing pressure, and directing the pressurized portion of hydraulic fluid to the connection to test a pressure rating of the connection.
G01M 3/28 - Examen de l'étanchéité des structures ou ouvrages vis-à-vis d'un fluide par utilisation d'un fluide ou en faisant le vide par mesure du taux de perte ou de gain d'un fluide, p. ex. avec des dispositifs réagissant à la pression, avec des indicateurs de débit pour tuyaux, câbles ou tubesExamen de l'étanchéité des structures ou ouvrages vis-à-vis d'un fluide par utilisation d'un fluide ou en faisant le vide par mesure du taux de perte ou de gain d'un fluide, p. ex. avec des dispositifs réagissant à la pression, avec des indicateurs de débit pour raccords ou joints d'étanchéité de tuyauxExamen de l'étanchéité des structures ou ouvrages vis-à-vis d'un fluide par utilisation d'un fluide ou en faisant le vide par mesure du taux de perte ou de gain d'un fluide, p. ex. avec des dispositifs réagissant à la pression, avec des indicateurs de débit pour soupapes
F16L 37/62 - Accouplements du type à action rapide actionnés pneumatiquement ou hydrauliquement
F16L 41/00 - Tuyaux de branchementRaccordements des tuyaux aux parois
A fluid storage system for an underwater environment, the system comprising an outer casing and a first bladder; wherein the outer casing comprises: an outer layer arranged to form a cavity; and an inner layer, located within the cavity formed by the outer layer, and defining an interior surface of-the outer casing; wherein the cavity comprises a first cavity and a second cavity; wherein the first cavity is formed between the outer layer and the inner layer; wherein the second cavity is defined by the interior surface of the outer casing: and wherein the outer casing is configured to receive and hold a first substance in the first cavity; and wherein the first bladder is suitable for storing the fluid to be stored; and wherein the first bladder is configured to receive and hold a second fluid, wherein the first bladder is located within the second cavity.
E04H 7/02 - Réservoirs pour fluides ou gazLeurs supports
E04B 1/16 - Structures formées à partir de matériaux en vrac, p. ex. de béton, coulés ou formés de façon analogue, sur place, avec ou sans emploi d'éléments additionnels, tels que coffrages permanents ou infrastructures à recouvrir du matériau porteur de la charge
E04H 15/20 - Tentes ou abris provisoires, en général gonflables, p. ex. dressés, renforcés ou supportés par un fluide sous pression
32.
SYSTEM AND METHOD FOR AN AUTOMATED AND INTELLIGENT FRAC PAD
A system may include a built hydraulic fracturing system with a plurality of devices connected together and a simulation of the built hydraulic fracturing system on a software application. Additionally, a fracturing plan may be provided on the software application to include pre-made instructions to perform multiple processes in a hydraulic fracturing operation such as a sequence of valve operations to direct fluid flow through a selected path. Further, the fracturing plan may be modified to create a customized fracturing plan including the pre-made instructions and at least one modified instruction. Furthermore, the customized fracturing plan may be executed to perform at least one of the processes in the built hydraulic fracturing system.
A control unit includes a hydraulic fluid system, a lubricant system, at least one sensor cable, an electronics module in communication with the at least one sensor cable, the hydraulic fluid system, and the lubricant system. A housing of the control unit contains the hydraulic fluid system, the lubricant system, the sensor cable(s), and the electronics module.
E21B 33/076 - Têtes de puitsLeur mise en place comportant des dispositions pour introduire des objets dans les puits ou pour les en retirer, ou pour y introduire des fluides spécialement adaptés aux installations sous l'eau
E21B 34/04 - Aménagements des vannes pour les trous de forage ou pour les puits dans les têtes de puits dans les têtes de puits situées sous l'eau
E21B 43/26 - Procédés pour activer la production par formation de crevasses ou de fractures
A tubing hanger assembly includes a tubing hanger body, a downward facing load shoulder which is axially displaceable relative to the body, and first and second inclined surfaces which are configured to engage each other. One of the first and second inclined surfaces has a fixed axial position relative to the body and the other of the first and second inclined surfaces has a fixed axial position relative to the load shoulder. The first and second inclined surfaces are configured such that rotation of one of the first and second inclined surfaces relative to the other of the first and second inclined surfaces results in axial displacement of the load shoulder relative to the body.
E21B 33/04 - Têtes de tubageSuspension des tubages ou des colonnes de production dans les têtes de puits
E21B 33/043 - Têtes de tubageSuspension des tubages ou des colonnes de production dans les têtes de puits spécialement adaptées aux têtes de puits sous l'eau
35.
IN-RISER TOOL OPERATION MONITORED AND VERIFIED THROUGH ROV
An in-riser communication system includes a riser extending from a surface facility to a subsea wellhead, a communication tool installed on a tool string, wherein the tool string is disposed in the riser, a repeater positioned on an exterior of the riser, a remote operated vehicle (ROV), and a computer system operatively connected to the ROV. When the communication tool and the repeater are positioned in proximity to one another, data is transferred from the communication tool, to the repeater, then to the ROV, and then to the computer system for processing.
E21B 17/01 - Colonnes montantes pour têtes de puits immergées
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
36.
IN-RISER TOOL OPERATION MONITORED AND VERIFIED THROUGH ROV
An in-riser communication system includes a riser extending from a surface facility to a subsea wellhead, a communication tool installed on a tool string, wherein the tool string is disposed in the riser, a repeater positioned on an exterior of the riser, a remote operated vehicle (ROV), and a computer system operatively connected to the ROV. When the communication tool and the repeater are positioned in proximity to one another, data is transferred from the communication tool, to the repeater, then to the ROV, and then to the computer system for processing.
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 17/01 - Colonnes montantes pour têtes de puits immergées
E21B 33/064 - Obturateurs anti-éruption spécialement adaptés aux têtes de puits sous l'eau
E21B 47/001 - Relevés dans les trous de forage ou dans les puits pour des installations sous-marines
E21B 47/26 - Stockage des données en fond de puits, p. ex. dans une mémoire ou sur un support d'enregistrement
A pipe assembly includes a flexible pipe segment and at least one end fitting. The at least one end fitting includes an end casing coupled to the flexible pipe segment and a seal housing removably coupled to the end casing. The end casing defines a seal housing-receiving bore extending longitudinally through the end casing, and the seal housing is positioned within the seal housing-receiving bore. The seal housing defines at least one seal bore extending from an axially distal surface of the seal housing, and one or more sealing elements are seated in a respective one of the at least one seal bore. The end casing is couplable to a counterpart fitting, and the seal housing and/or the one or more sealing elements are configured to define a sealing interface with the counterpart fitting.
F16L 33/18 - Dispositions d'assemblage des manches avec des organes rigidesRaccords rigides pour manches, p. ex. éléments unitaires s'engageant à la fois dans deux manches caractérisées par l'emploi de moyens d'étanchéité additionnels
F16L 33/28 - Dispositions d'assemblage des manches avec des organes rigidesRaccords rigides pour manches, p. ex. éléments unitaires s'engageant à la fois dans deux manches pour des manches ayant une extrémité en forme de collet ou de bride radiaux
A tubing head assembly for housing a tubing hanger in a well completion system is disclosed. The well completion system includes a wellhead positioned at the upper end of a well bore and a Christmas tree positioned above the wellhead. The tubing head system includes a tubing head connectable to the top of the wellhead and having an axially extending central bore, and a tubular adapter sleeve configured to be secured and sealed in the central bore and having an axially extending sleeve bore which is configured to receive the tubing hanger. In use of the tubing head assembly, the tubing hanger is positioned in the sleeve bore and the adapter sleeve is positioned in the central bore to thereby position the tubing hanger in the tubing head.
E21B 33/04 - Têtes de tubageSuspension des tubages ou des colonnes de production dans les têtes de puits
E21B 33/072 - Têtes de puitsLeur mise en place comportant des dispositions pour introduire des objets dans les puits ou pour les en retirer, ou pour y introduire des fluides pour les outils manœuvrés par câbles
A pipe assembly for flowing a fluid, the pipe assembly (100) comprising: a flexible pipe segment (102); and at least one end fitting (107), wherein a respective one of the at least one end fitting (107) comprises: an end casing (108) coupled to the flexible pipe segment, the end casing (108) defining a seal housing-receiving bore extending longitudinally through the end casing (108), a seal housing positioned within the seal housing-receiving bore and removably coupled to the end casing (108), wherein the seal housing defines at least one seal bore extending from an axially distal surface of the seal housing, and one or more sealing elements seated in a respective one of the at least one seal bore; wherein a respective one of the at least one end fitting (107) is couplable to a counterpart fitting (100, 110), wherein the seal housing and/or the one or more sealing elements are configured to define a sealing interface with the counterpart fitting (100, 110).
F16L 33/01 - Dispositions d'assemblage des manches avec des organes rigidesRaccords rigides pour manches, p. ex. éléments unitaires s'engageant à la fois dans deux manches spécialement adaptées pour des manches ayant une paroi à plusieurs couches
F16L 58/18 - Protection des tuyaux ou des accessoires pour tuyaux contre la corrosion ou l'entartrage spécialement conçue pour les raccords de tuyaux
F16L 23/028 - Raccords à brides les brides étant raccordées par des organes tendus axialement caractérisés par la façon dont les brides sont fixées ou forment une extension aux tuyaux les brides étant maintenues derrière un épaulement
A tubing head assembly for housing a tubing hanger in a well completion system is disclosed. The well completion system includes a wellhead positioned at the upper end of a well bore and a christmas tree positioned above the wellhead. The tubing head system includes a tubing head connectable to the top of the wellhead and having an axially extending central bore, and a tubular adapter sleeve configured to be secured and sealed in the central bore and having an axially extending sleeve bore which is configured to receive the tubing hanger. In use of the tubing head assembly, the tubing hanger is positioned in the sleeve bore and the adapter sleeve is positioned in the central bore to thereby position the tubing hanger in the tubing head.
A method includes choosing a well site for Carbon Capture and Sequestration, preparing the well site for Carbon Capture and Sequestration, and hydraulic fracturing a target area in a formation using fracturing fluid containing a reactant proppant to form fractures in the target formation and to trap the reactant proppant in the fractures. The target formation is in communication with a well in the well site. Such methods also include injecting a volume of carbon dioxide into the fractures in the target formation, chemically reacting the volume of carbon dioxide with the reactant proppant, converting the volume of carbon dioxide into a carbonate, and storing the carbonate in the fractures in the target formation.
A method includes choosing a well site for Carbon Capture and Sequestration, preparing the well site for Carbon Capture and Sequestration, and hydraulic fracturing a target area in a formation using fracturing fluid containing a reactant proppant to form fractures in the target formation and to trap the reactant proppant in the fractures. The target formation is in communication with a well in the well site. Such methods also include injecting a volume of carbon dioxide into the fractures in the target formation, chemically reacting the volume of carbon dioxide with the reactant proppant, converting the volume of carbon dioxide into a carbonate, and storing the carbonate in the fractures in the target formation.
This disclosure describes monitoring and operating subsea well systems, such as to perform operations in the construction and control of targets in a subsea environment. A submerisble ROV that performs operations in the construction and control of targets (e.g., well completion components) in a subsea environment, the ROV has one or more imaging devices that capture data that is processed to provide information that assists in the control and operations of the ROV and/or well completion system while the ROV is subsea.
A method for providing a subsea template system with a tail pipe, and a subsea template system are disclosed. The subsea template system comprising a structure (100), the structure (100) comprising a guide (110) with an opening (120) for a well, and the structure (100) comprising a plurality of supports (102) for engaging a sea bed; a tail pipe (200) being cylindrical and comprising a serrated end structure (210) at a first (lower) end (202) of the tail pipe (200), the tail pipe (200) being arranged in the opening (120), and the tail pipe (200) comprising an interface (400) for rotating and axially move the tail pipe (200) relative to the structure (100). The method comprising: placing the structure (100) and the tail pipe (200) on the sea bed; rotating and moving axially the tail pipe (200) relative to the guide (110) and into the sea bed to remain in the sea bed; drilling with the drill string (500) an opening (in the sea bed), inside the tail pipe (200), for an outer conductor casing (600); and installing the outer conductor casing (600) and applying cement between the outer conductor casing (600) and the tail pipe (200).
A pipe deployment system includes a vehicle, a deployment tool having a body with a spool engagement slot and a hydraulic motor mounted to the body, a spool having a pin extending along a rotational axis of the spool from an end of the spool, and an engagement spline rotationally engaging the hydraulic motor with the pin. The deployment tool is removably connected to the vehicle.
This disclosure describes monitoring and operating subsea well systems, such as to perform operations in the construction and control of targets in a subsea environment. A submerisble ROV that performs operations in the construction and control of targets (e.g., well completion components) in a subsea environment, the ROV has one or more imaging devices that capture data that is processed to provide information that assists in the control and operations of the ROV and/or well completion system while the ROV is subsea.
F03G 7/06 - Mécanismes produisant une puissance mécanique, non prévus ailleurs ou utilisant une source d'énergie non prévue ailleurs utilisant la dilatation ou la contraction des corps produites par le chauffage, le refroidissement, l'humidification, le séchage ou par des phénomènes similaires
48.
ROTATING INDEXING COUPLING (RIC) ASSEMBLY FOR INSTALLATION AND ORIENTATION OF A SUBSEA PRODUCTION TREE
One illustrative apparatus disclosed herein includes a stab body, a first and second inlet/outlet and a coupler body positioned around the stab body, wherein the coupler body is adapted to rotate relative to the stab body. Also included is a first and second hydraulic coupling element positioned on the coupler body and a first and second coiled tube positioned around the stab body, the first and second coiled tubes being in fluid communication with the first and second hydraulic coupling elements respectively and the first and second inlet/outlets respectively. Also included is a first and second orientation structure and a tubing hanger. The first and second orientation structures are adapted to engage each other and establish a desired relative orientation between the coupler body and the tubing hanger.
A tool interchange for a submersible remote operated vehicle (ROV) arm includes a first interchange body that affixes to an ROV arm. A second interchange body is carried by the first interchange body to rotate on a rotation axis. The second interchange body includes a tool mount actuable between gripping an ROV tool to the second interchange body and releasing the ROV tool from the second interchange body. An inductive power coupling part is provided in the tool mount. The inductive power coupling part is presented outwardly in the tool mount opposite the first interchange body, resides on the rotation axis and is fixed with respect to the first interchange body while the second interchange body rotates. The inductive power coupling part is adapted to inductively communicate power with a corresponding inductor power coupling part of the ROV tool when the ROV tool is docked in the tool mount.
A valve position sensing system includes a valve housing, a tail stock extending from the valve housing, an extendable valve stem extending axially through the tail stock, and a valve sensor housing assembly. The valve sensor housing assembly includes a housing body, having an interior cavity opening to a first and a second end, where the first end has a fixed connection portion integrally formed with the housing body and a movable connection portion that is movable relative to the fixed connection portion. The fixed and movable connection portions are fitted around the tail stock to secure the first end of the housing body to the tail stock. The valve sensor housing assembly further includes a closure mechanism disposed around the first end, a backplate covering the opening of the interior cavity at the second end, and a sensor provided in the interior cavity.
F16K 37/00 - Moyens particuliers portés par ou sur les soupapes ou autres dispositifs d'obturation pour repérer ou enregistrer leur fonctionnement ou pour permettre de donner l'alarme
51.
Pressure Compensator and Assembly Comprising a Subsea Installation and Such a Pressure Compensator
The invention proposes a double barrier pressure compensator for performing a pressure compensation between seawater surrounding a subsea installation and a medium filling a volume of the subsea installation. Said pressure compensator comprises: —a housing (20) having a first opening (202b) and a second opening (30); —a first bellows (4) and a second bellows (5) arranged one above the other within the housing (20) and each sealingly fixed to the housing (20) at their distal ends (43, 53); —a moving separation element (6) adapted to move inside the housing (20) and sealingly fixed to each of the proximal ends (44, 54) of the first and second bellows (4, 5) so as to separate a first compartment (21) from a second compartment (22) of the housing (20) sealed with respect to each other. Said pressure compensator (2) further comprising a third compartment (23) formed by a space between the housing (20) and the first and second bellows (4, 5), the first compartment (21) being arranged to be fluidly connected to the subsea installation (1) through the second opening (30), the second compartment (22) being arranged to be in communication with sea water through the first opening (202b), and said third compartment (23) being filled with a barrier medium.
F15B 3/00 - Amplificateurs ou convertisseurs de pression de fluide, p. ex. échangeurs de pressionTransmission de la pression d'un système à fluide à un autre, sans contact entre les fluides
A subsea valve actuation system (100, 200) is disclosed and comprises a contact portion (101, 201) for connecting an actuator to a receptacle (105, 205), a receptacle (105, 205) for connecting an actuator to a subsea valve. The receptacle (105, 205) comprises a receptacle housing (107, 207) having proximal (109, 209) and distal (111, 211) ends and an internal chamber (115, 215), wherein the proximal end (109, 209) is connectable to a body of the valve; and each of the contact portion (10, 201) and the receptacle (105, 205) having a longitudinal axis (L); the contact portion (101, 201) having a first axially facing mating end face (117, 217); and the receptacle housing (107, 207) having a second axially facing mating end face (119, 219). One of the first (117, 217) or second (119, 219) mating end faces has protrusions (121, 221); and the other of the first (117, 217) or second (119, 219) mating end faces defines corresponding recesses (123, 223) for receiving the protrusions (117, 217).
A subsea actuation sub-system comprising a position indicator (100) and a rotation-to-linear mechanism (200) is disclosed. The rotation-to-linear mechanism (200) being fixable to a subsea structure (10) comprising a valve (12) with a valve stem (14), and being connectable to the valve stem (14) of the valve (12) for moving the valve (12) between an open position and a closed position, the rotation-to-linear mechanism (200) comprising a shaft (210) with an end (212) for receiving rotational input from a separate retrievable motor actuator (300), the end (212) being positioned within a cylindrical bucket (220), the bucket (220) comprising a cylindrical opening (240) in an axial direction of the bucket (220) and a through opening (230), in a radial direction, in a side (222) of the bucket (220), the shaft (210) extending through a bottom of the bucket to the rotation-to- linear mechanism (200). The position indicator (100) indicating the position of the output movement of the rotation-to-linear mechanism (200) on the valve stem (14), the position indicator (100) being arranged to interact with the shaft (210) within the bucket (220). The position indicator (100) comprising a first gear (110) and a second gear (120), the two gears converting the rotation of the shaft (210) to a visual position indicator element (150) outside the bucket (220), the first gear (110) being arranged on the shaft (210), and the second gear (120) comprising an element (122); wherein the position of the linear movement of the rotation-to- linear mechanism (200) is indicated by the element (122).
E21B 41/00 - Matériel ou accessoires non couverts par les groupes
F16K 37/00 - Moyens particuliers portés par ou sur les soupapes ou autres dispositifs d'obturation pour repérer ou enregistrer leur fonctionnement ou pour permettre de donner l'alarme
54.
SUBSEA ACTUATION SYSTEM WITH RETRIEVABLE POSITION INDICATOR
A subsea actuation system with a, at least partly, retrievable position indicator (200) is disclosed. The subsea actuation system being connectable to a subsea structure (10) with a valve (12) with a rising valve stem (14), the rising valve stem (14) comprising a rotation-to-linear mechanism (100) for operating the valve (12), the subsea actuation system comprising an interface (110) for receiving rotational input from a separate retrievable actuator (300). The interface (110) comprises a cylindrical bucket (120) comprising an opening (130) in an axial direction of the cylindrical bucket (120), and a shaft (140) for receiving the rotational input from the retrievable actuator (300), the shaft (140) being connected to the rotation-to-linear mechanism (100). The position indicator (200)is configured for indicating amount of rotational movement of the shaft (140) and hence a position of the valve (12), and at least a part of the position indicator (200) is configured to be positionable at, and retrievable from, the interface (110). A first part (210) of the position indicator (200) is configured for being in an interior (124) of the cylindrical bucket (120), and a second part (220) of the position indicator (200) is configured for being positionable at, and retrievable from, an outer side (152) of the cylindrical bucket (120), the first part (210) being connected to the second part (220) through an opening (122) in the cylindrical bucket (120), the opening (122) being a through opening (122) in the radial direction.
A subsea control module (100, 200) for controlling one or more subsea devices (26, 46) is disclosed and comprises a housing (10) having top and bottom sides (12, 14). The housing (10) comprises: a first connection interface (16) with one or more connectors (18) for connection to one or more supply lines (20) outside the housing (10); a second connection interface (22) with one or more connectors (24) for connection to a respective subsea device (26, 46) outside the housing (10); at least one backup connector (28) in a third connection interface (17) for connection to a respective subsea device (26, 46) outside the housing (10); and one or more controllers (30, 32, 34) inside the housing (10) for controlling the respective subsea device (26, 46) outside the housing (10). The one or more controllers (30, 32, 34) are connectable to the respective subsea device (26, 46) via one or each of: the connectors (24) in the second connection interface (22); the backup connector (28) in the third connection interface (17).
A locking nut (400) for locking a subsea unit relative to a guide rod fixed to a subsea installation is described. The locking nut has a body (410) with a bore (412). The body (410) comprises first and second parts (413, 415) which are detachable from one another. An assembly (10) incorporating the locking nut (410) is also described.
A locking nut (200, 300) for locking a subsea unit relative to a guide rod fixed to a subsea installation is described. The nut (200, 300) comprises a body (210, 310) having a bore (212, 312); and a locking element (218, 318) with a threaded portion (220, 320). The body (210, 310) has first and second ends (214, 216, 314, 316). The body (210, 310) includes a tapered contact surface (222, 322) which tapers outwardly from the first end (214, 314) towards the second end (216, 316). An assembly incorporating the locking nut is also described.
An actuation assembly (10) for a subsea valve (41) is described. The actuation assembly (10) has an actuator (12) with a guide passage (37) and a receptacle (14) with a guide rod (38) which is removably secured within the guide passage (37) of the actuator (12).
E21B 34/02 - Aménagements des vannes pour les trous de forage ou pour les puits dans les têtes de puits
E21B 34/04 - Aménagements des vannes pour les trous de forage ou pour les puits dans les têtes de puits dans les têtes de puits situées sous l'eau
F16K 31/04 - Moyens de fonctionnementDispositifs de retour à la position de repos électriquesMoyens de fonctionnementDispositifs de retour à la position de repos magnétiques utilisant un moteur
E21B 33/038 - Connecteurs utilisés sur les têtes de puits, p. ex. pour relier l'obturateur anti-éruption et la colonne montante dans l'eau
E21B 41/04 - Manipulateurs pour opérations sous l'eau, p. ex. reliés temporairement aux têtes de puits
59.
Modular manifold system for continuous fluid pumping into a well
An illustrative modular manifold system includes, among other things, two or more modular pump manifolds, a low-pressure header, and a main high-pressure manifold. Modular pump manifolds may include a low-pressure manifold for supplying fracturing fluid or water to pumps, a high-pressure manifold for supplying fracturing fluid or water to one or more wells and a bleed-off/prime-up manifold. Each modular pump manifold of the modular manifold system is configured to be fluidly isolatable from the other modular pump manifolds. Each isolated modular pump manifold is configured to be flushed with water, bled off and primed up independently of the other modular pump manifolds. After the bleed off, maintenance procedures may be performed on pumps associated with the isolated modular pump manifold. The modular pump manifolds that are not isolated may continue in active fracing stage operations while a modular pump manifold is isolated.
A subsea hydrocarbon Christmas tree having a control and battery module (100) for controlling electrically actuated valves (200) is described. The control and battery module comprises a plurality of subsea electronics modules (110A, 110B) configured for receiving electric power provided from a top-side power supply (300) to operate the valves. The control and battery module also comprises a plurality of battery pack modules (120A, 120B, 120C). At least one of the plurality of battery pack modules (120B, 120C) is connectable to the subsea electronics modules to provide supplement electric power to the subsea electronics modules should electric power required for a desired valve operation exceed electric power provided to the subsea electronics modules from the top-side power supply. A related method is also described.
A subsea hydrocarbon Christmas tree (400) comprising a control and battery module (100) for controlling electrically actuated valves (200) is described. The control and battery module has first and second subsea electronics modules (110A, 110B) forming a redundant pair, wherein each subsea electronics module is configured for receiving electric power provided from a top-side power supply (300) to operate the valves (200), and a plurality of power back-up battery pack modules (120A, 120B, 120C). The power back-up battery pack modules comprises: a first battery pack module (120A) which is connectable to the first subsea electronics module to provide back-up electric power to the first subsea electronics module should power from the top-side power supply be interrupted; a second battery pack module (120B) which is connectable to the second subsea electronics module to provide back-up electric power to the second subsea electronics module should power from the top- side power supply be interrupted; and at least one additional battery pack module (120C) which is connectable to at least one of the first and the second subsea electronics modules (110A, 110B). A related method is also described (Fig. 2)
A guide rod, for guiding two subsea components together, the guide rod (10) being able to be both inserted and locked into a receptacle (20) on one (30) of the two subsea components. The guide rod comprises an element (100), the element (100) being substantially hollow and cylindrical, the element (100) comprising a first circumferential shoulder (110) towards a first end (102), a second circumferential shoulder (120) towards an opposite second end (104), and a plurality of openings (130), each opening (130) extending radially through the element (100) and extending axially along the element (100) opening up the element (100) from the first end (102) to the second circumferential shoulder (120), the plurality of openings (130) forming elongate flexible sections (140) of the element (100), and extending through the first circumferential shoulder (110); a wedge (200), the wedge (200) being inside the element (100) and substantially cylindrical and comprising a cone shaped section (210), the wedge (200) being restricted from rotating relative to the element (100) and comprising an end (202) being outside of the element (100); a cone (300), the cone (300) being connected to the end (202) of the wedge (200), and the cone (300) being cone shaped with a vertex (310) pointing away from the element (100); and a mechanism (400) for moving the wedge (200) axially relative to the element (100) in an insertion direction (50), and opposite the insertion direction (50), of the guide rod.
E21B 33/038 - Connecteurs utilisés sur les têtes de puits, p. ex. pour relier l'obturateur anti-éruption et la colonne montante dans l'eau
E21B 41/10 - Colonnes de guidage, p. ex. largablesLignes de guidage fixées à des bases de guidage sous l'eau
F16L 1/26 - Réparation ou assemblage des tuyaux sur ou sous l'eau
E21B 33/043 - Têtes de tubageSuspension des tubages ou des colonnes de production dans les têtes de puits spécialement adaptées aux têtes de puits sous l'eau
09 - Appareils et instruments scientifiques et électriques
Produits et services
Flow computers for managing and monitoring fluid measurement systems; metering control systems; computer controlled apparatus for measuring and monitoring fluid flow; flow meters.
64.
Wireline pressure control string with pumpdown assembly
A wireline pressure control string for use in performing wireline operations on a hydrocarbon well is disclosed. The wireline pressure control string includes a pumpdown assembly having a pumpdown sub and at least one pumpdown valve. The pumpdown sub includes a body and a through bore which extends axially through the body and is fluidly connectable to the well bore. The pumpdown valve includes an inlet which is fluidly connectable to a pumpdown fluid source and an outlet which is fluidly connected to the through bore. The wireline pressure control string may also include a connector positioned below the pumpdown assembly for releasably securing the wireline pressure control string to the wellhead assembly. In certain embodiments, the pumpdown valve may be connected to the pumpdown fluid source with a flexible flowline.
E21B 23/08 - Introduction ou circulation d'outils par pression de fluide, p. ex. systèmes d'outils mis en place par un courant de fluide
E21B 23/04 - Appareils pour déplacer, mettre en place, verrouiller, libérer ou retirer, les outils, les packers ou autres éléments dans les trous de forage mis en œuvre à l'aide de moyens fluides, p. ex. actionnés par explosion
E21B 33/072 - Têtes de puitsLeur mise en place comportant des dispositions pour introduire des objets dans les puits ou pour les en retirer, ou pour y introduire des fluides pour les outils manœuvrés par câbles
E21B 34/02 - Aménagements des vannes pour les trous de forage ou pour les puits dans les têtes de puits
65.
WIRELINE PRESSURE CONTROL STRING WITH PUMPDOWN ASSEMBLY
A wireline pressure control string for use in performing wireline operations on a hydrocarbon well is disclosed. The wireline pressure control string includes a pumpdown assembly having a pumpdown sub and at least one pumpdown valve. The pumpdown sub includes a body and a through bore which extends axially through the body and is fluidly connectable to the well bore. The pumpdown valve includes an inlet which is fluidly connectable to a pumpdown fluid source and an outlet which is fluidly connected to the through bore. The wireline pressure control string may also include a connector positioned below the pumpdown assembly for releasably securing the wireline pressure control string to the wellhead assembly. In certain embodiments, the pumpdown valve may be connected to the pumpdown fluid source with a flexible flowline.
E21B 23/04 - Appareils pour déplacer, mettre en place, verrouiller, libérer ou retirer, les outils, les packers ou autres éléments dans les trous de forage mis en œuvre à l'aide de moyens fluides, p. ex. actionnés par explosion
A flow control module includes an inlet hub, a flow meter, a choke, and an outlet hub. The inlet hub is coupled to a first flow passage having a first flow bore. The flow meter is associated with the first flow bore and positioned for top-down fluid flow. The choke is disposed in a second flow passage having a second flow bore. The second flow passage is coupled to a distal end of the first flow passage. The outlet hub is coupled to a distal end of the second flow passage and faces in a different direction from the inlet hub.
E21B 33/035 - Têtes de puitsLeur mise en place spécialement adaptées aux installations sous l'eau
E21B 33/043 - Têtes de tubageSuspension des tubages ou des colonnes de production dans les têtes de puits spécialement adaptées aux têtes de puits sous l'eau
E21B 33/064 - Obturateurs anti-éruption spécialement adaptés aux têtes de puits sous l'eau
E21B 33/076 - Têtes de puitsLeur mise en place comportant des dispositions pour introduire des objets dans les puits ou pour les en retirer, ou pour y introduire des fluides spécialement adaptés aux installations sous l'eau
E21B 34/02 - Aménagements des vannes pour les trous de forage ou pour les puits dans les têtes de puits
E21B 34/04 - Aménagements des vannes pour les trous de forage ou pour les puits dans les têtes de puits dans les têtes de puits situées sous l'eau
E21B 43/013 - Raccordement d'une colonne de production à une tête de puits sous l'eau
67.
METHOD AND SYSTEMS FOR REAL-TIME MEASUREMENT OF REID VAPOR PRESSURE IN FLUIDS
A vapor pressure monitoring system may include a plurality of sensors disposed on equipment at a processing facility during one or more stages of refining and/or processing fluids. The plurality of sensors may be configured to monitor one or more properties of the fluid. In addition, one or more transmitters may be configured to transmit the one or more properties from the plurality of sensors to a computer system. The computer system may be configured to determine vapor pressure of the fluids based on the one or more fluid properties.
A modular pump skid includes a base, a prime mover mounted on the base, and one or more hydraulic pump circuits removably mounted on the base and operationally coupled to the prime mover, wherein each hydraulic pump circuit has a hydraulic pump operationally coupled to the prime mover and a hydraulically driven pump fluidly coupled to the hydraulic pump. Each hydraulic pump circuit is in a closed loop independent of other hydraulic pump circuits.
F04B 23/06 - Combinaisons de plusieurs pompes les pompes étant toutes du type à déplacement positif alternatif
E21B 43/26 - Procédés pour activer la production par formation de crevasses ou de fractures
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
It is described cylindrical subsea vessel (1) for separation of a flow, the vessel (1) comprising first and second longitudinal ends (T,1″), wherein the subsea vessel (1) comprises: —a liner (2); —at least one fluid inlet (3) and one fluid outlet (4, 5) into and out of an inner volume (7) of the vessel (1); —at least one flange (8) connected in one of the longitudinal ends (1′, 1″), wherein the at least one flange (8) and the liner (2) form the inner volume of the subsea vessel (1), and wherein the at least one flange (8) comprises at least one through-going opening (4,5,6) forming the at least one fluid inlet (3,4) and/or fluid outlet (5); —a load bearing structure (9) arranged outside the liner (2) and the at least one flange (8), wherein the load bearing structure (9) is of a composite material. It is further described a method of manufacturing the subsea vessel.
An illustrative modular manifold disclosed herein includes, among other things, a low-pressure manifold comprising a frac fluid outlet valve, wherein a fracturing fluid is adapted to be supplied from the low-pressure manifold via the frac fluid outlet valve to a suction side of a frac pump, and a high-pressure manifold comprising at least one frac fluid inlet valve, wherein the high-pressure manifold is adapted to receive, via the frac fluid inlet valve, a fracturing fluid discharged from the frac pump. In this example, the modular manifold also includes a support structure for mechanically supporting the low- and high-pressure manifolds and a plurality of height-adjustable support legs operatively coupled to the support structure.
E21B 43/26 - Procédés pour activer la production par formation de crevasses ou de fractures
E21B 33/068 - Têtes de puitsLeur mise en place comportant des dispositions pour introduire des objets dans les puits ou pour les en retirer, ou pour y introduire des fluides
F16L 3/00 - Supports pour tuyaux, pour câbles ou pour conduits de protection, p. ex. potences, pattes de fixation, attaches, brides, colliers
F16L 41/03 - Ensembles de branchements, p. ex. d'une seule pièce, soudés à l'autogène, rivetés comportant des pièces d'assemblage pour quatre tuyaux ou plus
71.
Submersible remote operated vehicle vision assistance and control
This disclosure describes monitoring and operating subsea well systems, such as to perform operations in the construction and control of targets in a subsea environment. A submersible ROV that performs operations in the construction and control of targets (e.g., well completion components) in a subsea environment, the ROV has one or more imaging devices that capture data that is processed to provide information that assists in the control and operations of the ROV and/or well completion system while the ROV is subsea.
A system and methods for barrier testing of a X-mas tree production system (300) are disclosed. The X-mas tree is subsea and comprises a fluid line (330) between a set of two barrier valves (310,320), one of the barrier valves of the set of two barrier valves being an upstream barrier valve (320) closer to a reservoir (400) and the other barrier valve being a downstream barrier valve (310) closer to an environment, and pressure monitoring devices (180, 380) in the fluid line (330) and downstream of the downstream barrier valve (310). The system provides fluid at different test pressures to the fluid line (330) between the downstream barrier valve (310) and the upstream barrier valve (320). The system comprises a first fluid connection line (101) from a fluid source (200) to a pressure increasing unit (160), with a first valve (110) positioned in the first fluid connection line (101); a second fluid connection line (102) from the pressure increasing unit (160) to a first connection point (332) on the fluid line (330) between the downstream barrier valve (310) and the upstream barrier valve (320), with a second valve (120) positioned in the second fluid connection line (102); and a third fluid connection line (103) from a fluid receiving unit (170) to a second connection point (122) on the second fluid connection line (102), the second connection point (122) being between the second valve (120) and the first connection point (332), with a third valve (130) positioned in the third fluid connection line (103), such that fluid at the different test pressures may be provided to the fluid line (330) between the barrier valves (310, 320) for testing of the barrier valves (310, 320).
E21B 33/035 - Têtes de puitsLeur mise en place spécialement adaptées aux installations sous l'eau
E21B 47/117 - Détection de fuites, p. ex. du tubage, par test de pression
73.
A Method of Laying a Pipeline on a Seafloor, Monitoring Surrounding Zones of the Installed Pipeline for Approaching Vessels and Warning Vessels Considered to be Able to Cause Harm to the Pipeline
It is described a method of laying a pipeline (1) on a seafloor (2), wherein the method comprises the steps of: —bringing the pipeline to an offshore location using a vessel, —laying the pipeline on the seafloor using the vessel, —defining a first zone (10) surrounding at least a first part length (1′) of the pipeline when laid subsea, wherein the first part length is uncovered, —defining a second zone (20) extending from the first zone, —monitoring the second zone for vessels approaching the first zone, —analysing vessels detected during said monitoring of the second zone, for the purpose of determining whether the vessels can cause harm to the first part length of the pipeline, —for each vessel monitored in the second zone and considered to be able to cause harm to the first part length of the pipeline, informing the vessel about the first zone and/or requesting the vessel not to enter into the first zone.
One illustrative production/annulus bore stab disclosed herein includes a one-piece body that comprises a first cylindrical outer surface and a second cylindrical outer surface and a plurality of individual fluid flow paths defined entirely within the one-piece body. In this illustrative example, each of the individual fluid flow paths is fluidly isolated from one another and each of the fluid flow paths comprise a first inlet/outlet at a first end of the fluid flow path that is positioned in the first cylindrical outer surface and a second inlet/outlet at a second end of the fluid flow path that is positioned in the second cylindrical outer surface.
A method for performing simultaneous operations at a wellsite comprising two or more adjacent wellheads, each respectively connected to a well, may include the following steps: providing a fluid supply via upstream equipment to an intermediate supply point; fluidly connecting the intermediate supply point to a single wellhead, the fluidly connecting comprising connecting a first end of a flexible pipe to the intermediate supply point and a second end of the flexible pipe to a first wellhead; performing a wellbore operation on a first well using the fluid supply from the upstream equipment supplied to the first wellhead; disconnecting the second end of the flexible pipe from the first wellhead; and connecting the second end of the flexible pipe to a second wellhead.
A method for performing simultaneous operations at a wellsite comprising two or more adjacent wellheads, each respectively connected to a well, may include the following steps: providing a fluid supply via upstream equipment to an intermediate supply point; fluidly connecting the intermediate supply point to a single wellhead, the fluidly connecting comprising connecting a first end of a flexible pipe to the intermediate supply point and a second end of the flexible pipe to a first wellhead; performing a wellbore operation on a first well using the fluid supply from the upstream equipment supplied to the first wellhead; disconnecting the second end of the flexible pipe from the first wellhead; and connecting the second end of the flexible pipe to a second wellhead.
A subsea system (1) connected to a subsea well (4) for boosting a process fluid flowing out of the well, comprising: —a preconditioning arrangement (2) connectable to a process fluid line from a well, wherein the preconditioning arrangement comprises at least one sensor for measuring temperature and one sensor for measuring pressure of the process fluid—means for estimating density of the process fluid based on measured temperature and pressure, —a cooler system (20, 21) comprising at least a first cooler for cooling the process fluid wherein the subsea system further comprises: —a pressure boosting device (3) arranged downstream of the preconditioning arrangement (2), the pressure boosting device having an operational window dictating operational parameter in terms of maximum and minimum allowable density of the process fluid entering the pressure boosting device (3).
E21B 36/00 - Aménagements pour le chauffage, le refroidissement ou l'isolation dans les trous de forage ou dans les puits, p. ex. pour être utilisés dans les zones de permagel
E21B 43/01 - Procédés ou dispositifs pour l'extraction de pétrole, de gaz, d'eau ou de matériaux solubles ou fusibles ou d'une suspension de matières minérales à partir de puits spécialement adaptés à l'extraction à partir d'installations sous l'eau
E21B 43/12 - Procédés ou appareils pour commander l'écoulement du fluide extrait vers ou dans les puits
E21B 41/00 - Matériel ou accessoires non couverts par les groupes
Poppet coupling comprising a male member (100) comprising a cylindrical body part (130) comprising a first outer diameter (132), and a cylindrical nose part (140) having a second outer diameter (142), at an end (102) which is to be inserted into a female member (200) first; and the female member (200) comprising an end opening (250) for receiving the male member first, a primary seal (300) for engaging the cylindrical body part (130), a cone shaped opening (240), and a cylindrical opening (230), the cylindrical opening (230) having a first inner diameter (232) for receiving the cylindrical nose part (140). The primary seal (300) is a metal seal; the second outer diameter (142) and the first inner diameter (232) are complementary to allow the cylindrical nose part (140) to be slidable inserted into the cylindrical opening (230) guiding and aligning the male member (100) and the female member (200).
F16L 29/04 - Raccords comportant des moyens pour couper le courant de fluide comportant un obturateur dans chacune des deux extrémités de tuyau, les obturateurs s'ouvrant automatiquement lors de l'accouplement
F16L 37/35 - Accouplements du type à action rapide avec moyens pour couper l'écoulement du fluide avec un obturateur dans chaque extrémité de tuyau avec deux clapets dont l'un au moins est ouvert automatiquement au moment de l'accouplement au moins un des clapets possédant un canal axial communiquant avec des ouvertures latérales
79.
Subsea Induction Heating System and Related Method
Abstract: A subsea induction heating system (10) comprising a subsea inline heater module (14) configured for heating a subsea hydrocarbon production or processing component (7) is described. The subsea inline heater module has an induction coil (6) configured for generating a variable magnetic field in the component. The system has a subsea variable frequency drive (4) configured for energizing the induction coil to achieve a desired temperature in the component. A corresponding method is also disclosed.
E21B 36/00 - Aménagements pour le chauffage, le refroidissement ou l'isolation dans les trous de forage ou dans les puits, p. ex. pour être utilisés dans les zones de permagel
E21B 41/00 - Matériel ou accessoires non couverts par les groupes
E21B 36/04 - Aménagements pour le chauffage, le refroidissement ou l'isolation dans les trous de forage ou dans les puits, p. ex. pour être utilisés dans les zones de permagel utilisant des réchauffeurs électriques
A high-pressure unit (HPU) skid includes one or more hydraulic pumps, a grease pump, a hydraulic reservoir, and two or more accumulators all mounted on a portable frame. The HPU skid also includes fluidic connections to connect one or more valves to an output of the grease pump and fluidic connections to connect one or more valves to an output of at least one of the two or more accumulators. The accumulators are configured to close at least one of the one or more valves using a charged pressure. The HPU skid further includes fluidic connections to connect one or more valves to at least one of the one or more hydraulic pumps. The hydraulic pumps are configured to withdraw hydraulic fluid from the hydraulic reservoir for charging the accumulators, operating the grease pump, charging the accumulators and operating the grease pump at a same time, or operating one or more valves.
A monitoring system for reciprocating pump having a plunger connected to a crankshaft by a crosshead and connecting rod assembly. The monitoring system includes a plurality of wireless temperature sensors which each have a temperature probe connected to a sensor head, a plurality of antennas which each have an antenna head configured to communicate wirelessly with a corresponding one of the sensor heads, and a signal processing unit connected to the plurality of antennas. Each temperature probe is positioned in contact with a corresponding crank pin bearing, wrist pin bearing or crosshead bearing. Each sensor head is mounted to the crosshead, and each antenna head is mounted to the pump at a location in which communication is enabled between the antenna head and its corresponding sensor head when the crosshead reaches a first position during each reciprocation of the crosshead. In operation, each antenna head transmits a radar pulse which is reflected by its corresponding sensor head, the reflected pulse is received by the antenna head and communicated to the signal processing unit, and the signal processing unit determines the temperature of the sensor head from the reflected pulse, which temperature is indicative of the temperature of its corresponding monitored bearing.
F04B 9/02 - "Machines" ou pompes à piston caractérisées par les moyens entraînants ou entraînés liés à leurs organes de travail les moyens étant mécaniques
F04B 53/14 - Pistons, tiges de piston ou liaisons piston-tige
82.
Submersible remote operated vehicle tool change control
A system receives data from a submersible remote operated vehicle (ROV), the data being about the operation of an arm of the ROV. The system automatically controls, based on the data, movement of the arm in docking the arm to a tool holder. In certain instances, the system implements an image based control. In certain instances, the system implements a force accommodation control. In certain instances, the system implements both.
A system includes a foundation with a post mounted on the foundation top surface and a pipe module configured to couple to the foundation. The pipe module has a yoke to cooperate with the post to engage the pipe module with the foundation. The pipe module is connected to the end of a pipeline and is configured to slide along the foundation responsive to longitudinal and angular movements of the end of the pipeline. A method includes deploying a foundation subsea and securing the foundation to a seafloor. The foundation has a post. The method includes deploying the pipe module via the pipeline suspended by a pipe module installation machine. The pipe module has a yoke. The method includes engaging the yoke with the post, paying out the pipeline to lower the yoke, and lowering and engaging the pipe module with the foundation.
A system for transferring fluid from a pump to a manifold, the manifold having a plurality of fluid inlets. A first pump truck includes a first pump having a first fluid outlet. A first flexible pipe couples the first fluid outlet to a first fluid inlet. The first flexible pipe is self-supporting and forms an arch extending over the first pump truck. The first pump truck may include a second pump having a second fluid outlet and a second flexible pipe may couple the second fluid outlet to a second fluid inlet. A second pump truck may include third and fourth pumps having third and fourth fluid outlets, respectively, that may be coupled to third and fourth fluid inlets by third and fourth self-supporting flexible pipes.
One method disclosed herein of processing a process fluid that comprises dissolved gas includes performing a degassing process on the process fluid by heating the process fluid via heat transfer with a heat transfer fluid, wherein at least some amount of the heat transfer fluid condenses in the first heat transfer process and latent heat of the heat transfer fluid as it condenses is used to increase the temperature of the process fluid. Thereafter, the heat transfer fluid is passed through an expansion device so as to produce a post-expansion heat transfer fluid. The temperature of the heated process fluid is decreased by performing a second heat transfer process between the post-expansion heat transfer fluid and the heated process fluid, wherein the temperature of the post-expansion heat transfer fluid is increased and the latent heat that was supplied to the process fluid in the first heat transfer process is removed.
A system may include a connector coupled to a wellhead assembly. The system may also include a hydraulic power unit coupled to the connector and a valve of the wellhead assembly. The system may further include a controller in communication with the connector and the hydraulic power unit. The controller may be operable to receive one or more conditions associated with the connector and a valve of the wellhead assembly. The controller may also be operable to operate at least one of the connector and the valve through the hydraulic power unit based on the one or more condition.
Storage tank comprising—an outer container (2) having a first closable opening (23), and—an inner bladder container (3) disposed within said outer container (2) and having a second closable opening (30), said outer container (2) and inner container (3) being sealed with respect to each other, said inner container (3) being adapted to be filled and or emptied with a liquid through said second closable opening (30), a space (8) between the outer container (2) and the inner container (3) being adapted to be filled with liquid through the first closable opening (23). The outer container (2) is rigid with at least one flexible portion incorporated in the rigid outer container and configured to flex so as to expand and contract to compensate volume variations caused by pressure and or temperature variations to which the storage tank (1) is subjected.
A tubing hanger assembly includes a tubing hanger body, a downward facing load shoulder axially displaceable relative to the body, an annular load member rotatably supported on the body, and a torque member operatively engaged between the load member. The load shoulder and load member are arranged such that rotation of the load member relative to the body results in axial displacement of the load shoulder relative to the body. In use, the torque member rotates the load member to thereby displace the load shoulder axially relative to the body.
E21B 33/04 - Têtes de tubageSuspension des tubages ou des colonnes de production dans les têtes de puits
E21B 33/043 - Têtes de tubageSuspension des tubages ou des colonnes de production dans les têtes de puits spécialement adaptées aux têtes de puits sous l'eau
90.
Method for evacuating hydrocarbon from a subsea process module
Method for evacuating hydrocarbon from a subsea process module (210), the subsea process module having an upper fluid connection point (222) and a lower fluid connection point (232), the method comprising: connecting (110) a receiving container line (220) to the upper fluid connection point (222) of the subsea process module (210); connecting (120) a liquid adding line (230) to the lower fluid connection point (232) of the subsea process module (210); displacing (130) hydrocarbon by a liquid displacement medium added through the liquid adding line (230); removing (140) the liquid adding line from the lower fluid connection point (232); connecting (150) a gas adding line (260) to either the upper fluid connection point (222) or a lower fluid connection point (232); connecting (160) a receiving container line (220) to the lower fluid connection point (232) and or another lower fluid connection point; diluting (170) the remaining hydrocarbon by a gas medium added through the gas adding line (260).
E21B 43/01 - Procédés ou dispositifs pour l'extraction de pétrole, de gaz, d'eau ou de matériaux solubles ou fusibles ou d'une suspension de matières minérales à partir de puits spécialement adaptés à l'extraction à partir d'installations sous l'eau
91.
Yoke over pipeline end termination assembly and method of use
A system includes a foundation with a post mounted on the foundation top surface and a pipe module configured to couple to the foundation. The pipe module has a yoke to cooperate with the post to engage the pipe module with the foundation. The pipe module is connected to the end of a pipeline and is configured to slide along the foundation responsive to longitudinal and angular movements of the end of the pipeline.
A method includes deploying a foundation subsea and securing the foundation to a seafloor. The foundation has a post. The method includes deploying the pipe module via the pipeline suspended by a pipe module installation machine. The pipe module has a yoke. The method includes engaging the yoke with the post, paying out the pipeline to lower the yoke, and lowering and engaging the pipe module with the foundation.
F16L 1/235 - Appareils pour le contrôle des tuyaux pendant la pose
F16L 1/12 - Pose ou récupération des tuyaux sur ou sous l'eau
F16L 1/26 - Réparation ou assemblage des tuyaux sur ou sous l'eau
F16L 1/20 - Accessoires à cet effet, p. ex. flotteurs ou poids de lestage
F16L 1/18 - Pose ou récupération des tuyaux sur ou sous l'eau sur le fond les tuyaux ayant la forme d'un S ou d'un J et étant sous tension pendant la pose
92.
PUMP COMPRISING A BALANCE ARRANGEMENT AND A RELATED METHOD
A pump (110) is disclosed comprising: an inlet (114) being in fluid communication with an inlet cavity (115); an outlet (118) being in fluid communication with an outlet cavity (119); a motor (120) being arranged in a motor cavity (121); a pump axis (122) being rotatably drivable by the motor; impellers (124) being positioned between the inlet cavity and the outlet cavity and being actuatable by the pump axis to cause a differential pressure across the inlet cavity and the outlet cavity; and a balance arrangement (126) configured to at least partially offset an axial thrust affected upon the axis by the impellers when the pump is in operation, the balance arrangement comprising: a balance cavity (132); a balance drum (128) arranged between the outlet cavity and the balance cavity; and a balance line (134) extending between and fluidly connecting the balance cavity and the inlet cavity. The inlet is in fluid communication with the inlet cavity via the balance cavity and the balance line. A related method is also disclosed.
09 - Appareils et instruments scientifiques et électriques
12 - Véhicules; appareils de locomotion par terre, par air ou par eau; parties de véhicules
Produits et services
Tools and tool holders for manipulator arms. Sensors and control systems for manipulator arms;
manipulator arm systems for submersible vehicles, namely,
remotely controlled manipulator arms and parts and
sub-assemblies thereof. Wrist tool interfaces for manipulator arms.
94.
SYSTEM AND METHOD FOR REMOTE OPERATION OF WELL EQUIPMENT
A system and a method for remote operation of a well equipment through a marine riser (50) is disclosed. The system is for remote operation of a well equipment through a marine riser (50), the marine riser (50) extending between a blowout preventer, BOP, (20) attached to a well head (60) and a vessel or a rig (10) at the surface. An umbilical comprising three lines, an electric power line, a hydraulic power line, and a communication line, being excluded from the system for the remote operation of the well equipment. The system comprising a first module (100) and a second module (200) connectable to a landing string (40) in the marine riser (50); wherein the first module (100) comprises a communication module (110), batteries (120), and a control module (130); and wherein the second module (200) comprises a plurality of reservoirs (210) for fluid, one or more pumps (290), a plurality of motors (240), a plurality of valves (250), and a control unit (260). The control module (130) controls the one or more pumps (290), and the control unit (260) controls the plurality of motors (240), and the plurality of valves (250). Each valve (250) being configured for controlling one or more tools of the well equipment. The first module (100) is a separate module from the second module (200) along the landing string (40), the second module (200) being configured to be closer to the well head (60) than the first module (100) along the landing string (40). The communication module (110) of the first module (100) is configured to receive communication data for controlling the one or more tools of the well equipment, the communication data being received from the vessel or the rig (10) at the surface. The first module (100) and the second module (200) are configured to have an electric cable (300) between them, the first module (100) supplying via the electric cable (300) electric power from the batteries (120), in the first module (100), to the one or more pumps (290) and the plurality of motors (240), in the second module (200), and the first module (100) supplying via the electric cable (300) communication data from the control module (130), in the first module (100), to the control unit (260), in the second module (200).
E21B 33/035 - Têtes de puitsLeur mise en place spécialement adaptées aux installations sous l'eau
E21B 41/00 - Matériel ou accessoires non couverts par les groupes
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
95.
Single Line Quick Connector (SQC), a System Comprising the Single Line Quick Connector and Method of Operating
It is described a single line quick connector (10), a system comprising the connector (10) and associated method, for connecting a hydraulic, chemical or water fluid line (20) to a fluid connection interface (2) on a component (1), wherein the connector (10) comprises: an outer housing (11) comprising a tool (12) in one axial end thereof for operation by a tool (3), a flow bore (14) for fluid connection with the fluid connection interface (2) on the component (1), a screw element (13) which is rotationally movable and axially fixed relative the outer housing (11), wherein the screw element (13) extends in a longitudinal direction of the connector (10) and comprises external threads (15) along a part of its axial length and further comprises a termination (16) which is operable by the tool (3), a collet sleeve (17) which is rotationally fixed and axially movable relative the outer housing (11), wherein the collet sleeve (17) further comprises internal threads (18) for cooperation with the external threads (15) on the screw element (13), and wherein the collet sleeve (17) comprises a plurality of collet fingers (19) in an axial end thereof for connection to the fluid connection interface (2) on the component (1), and, a fluid line insert (23) comprising a groove (24) for a coupler (25), wherein the outer housing (11), the screw element (13) and the collet sleeve (17) are arranged such that: a rotation of the screw element (13) in a first direction results in an axial movement of the outer housing (11) relative the collet sleeve (17), and thus the collet fingers (19), in a first axial direction, and a rotation of the screw element (13) in a second direction, opposite of the first rotational direction, results in an axial movement of the outer housing (11) relative the collet sleeve (17), and thus the collet fingers (19), in a second direction, which is opposite to the first axial direction, wherein the outer housing (11) comprises a through-going opening (21) ( ) and the collet sleeve (17) comprises at least one recess (22) between neighboring collet fingers (19), wherein the through-going opening (21) and the at least one recess (22), when connected, are configured to accommodate the fluid line insert (23), and wherein the fluid line insert (23) is connectable to the fluid line (20). The is further described a method of overriding a malfunctioning single line quick connector which is in an engaged position locked to the connection interface on the component in order to release the connector from the engaged relationship with the component.
E21B 33/035 - Têtes de puitsLeur mise en place spécialement adaptées aux installations sous l'eau
F16L 37/091 - Accouplements du type à action rapide dans lesquels l'assemblage entre les extrémités s'aboutant ou se chevauchant est maintenu par des organes de blocage combinés à un verrouillage automatique au moyen d'une bague pourvue de dents ou de doigts
37 - Services de construction; extraction minière; installation et réparation
42 - Services scientifiques, technologiques et industriels, recherche et conception
Produits et services
construction, installation, maintenance and repair of energy generation and storage systems and ancillary structures and equipment; construction project management services in the field of energy generation and storage systems; construction, installation, maintenance and repair of fixed and floating platforms for energy generation and storage apparatus technical consulting services in the field of technology used for energy generation and energy storage; research, development, design and engineering of energy generation and storage systems and ancillary structures and equipment
A method of retrofitting an existing separator pressure vessel (100) with a solids removal system (118) includes installing a support structure (122) in the separator pressure vessel (100), adjusting a size of the support structure (122) within the separator pressure vessel to frictionally engage contact surfaces of the support structure with an inner surface of the separator pressure vessel or a surface of a component installed in the separator pressure vessel, installing a supply header (124) and a suction header (126) on the support structure in the separator pressure vessel, coupling a jetting nozzle (128) or a cyclonic device to the supply header, coupling the supply header to an inlet nozzle (160a) extending from an interior of the separator pressure vessel to an exterior of the separator pressure vessel; and coupling the return header to an outlet nozzle (160b) from an interior of the separator pressure vessel to an exterior of the separator pressure vessel.
A subsea system includes a first foundation structure supporting a first compressor train and having a connection interface for connecting to a second foundation structure supporting an additional compressor train. The first compressor train includes a first compressor having an inlet connectable via a fluid line to a well flow line. A compressed fluid line having a flow regulation device is connected to an outlet of the first compressor and to a common outlet for compressed fluid. A first connection line is connected to the compressed fluid line at a position upstream of the flow regulation device, and a third connection line is connected to the fluid line at a position upstream of the first compressor. Each of the first and third connection lines includes a flow regulating device and is configured to connect to the additional compressor train. A second connection line is connected to the compressed fluid line at a position downstream of the flow regulation device and is configured to connect to the additional compressor train to thereby connect the additional compressor train to the common outlet.
E21B 43/01 - Procédés ou dispositifs pour l'extraction de pétrole, de gaz, d'eau ou de matériaux solubles ou fusibles ou d'une suspension de matières minérales à partir de puits spécialement adaptés à l'extraction à partir d'installations sous l'eau
F04D 17/14 - Pompes multiétagées avec moyens de changer le trajet du flux à travers les étages, p. ex. par des transformations série-parallèle
F04D 25/06 - Ensembles comprenant des pompes et leurs moyens d'entraînement la pompe étant entraînée par l'électricité
N″). Further, the flowline system has a power output connector (Pout) for providing electrical power to a subsea hydrocarbon production system; a first electrical conduit (306′) extending between the neutral connection point of the cable termination of the first trace heating cable and the power output connector; and a second electrical conduit (306″) extending between the neutral connection point of the cable termination of the second trace heating cable and the power output connector, wherein the first and the second electrical conduits are electrically accessible at the power output connector for powering the subsea hydrocarbon production system.
E21B 36/04 - Aménagements pour le chauffage, le refroidissement ou l'isolation dans les trous de forage ou dans les puits, p. ex. pour être utilisés dans les zones de permagel utilisant des réchauffeurs électriques
F16L 53/38 - Chauffage par résistance ohmique en utilisant des éléments de chauffage électrique allongés, p. ex. des fils ou des rubans
E21B 47/001 - Relevés dans les trous de forage ou dans les puits pour des installations sous-marines
E21B 17/00 - Tiges ou tubes de forageTrains de tiges souplesTiges d'entraînementMasses-tigesTiges de pompageTubagesColonnes de production
E21B 43/01 - Procédés ou dispositifs pour l'extraction de pétrole, de gaz, d'eau ou de matériaux solubles ou fusibles ou d'une suspension de matières minérales à partir de puits spécialement adaptés à l'extraction à partir d'installations sous l'eau
A filtration apparatus includes a tubular casing having a longitudinal axis and first and second casing ends, a plurality of partition plates positioned in the casing and sealed thereto to thereby define a plurality of axially successive chambers within the casing, including an intake collection chamber between a first of the partition plates and the first casing end, a discharge collection chamber between a second of the partition plates and the second casing end, and a reject collection chamber opposite the second partition plate from the second casing end. A plurality of elongated filtration membrane stacks are positioned side-by-side in the casing generally parallel to the longitudinal axis. Each filtration membrane stack includes an intake end which is fluidly connected to the intake collection chamber, a discharge end which is fluidly connected to the reject collection chamber, and a permeate channel which extends between the intake and discharge ends and is fluidly connected to the discharge collection chamber, an end of the permeate channel located adjacent the intake end being sealed from the intake collection chamber. The filtration apparatus also includes an intake pipe having a first end fluidly connected to the intake collection chamber and a second end fluidly connected to a first connector located proximate the second casing end; a discharge pipe having a first end fluidly connected to the discharge collection chamber and a second end fluidly connected to a second connector located proximate the first connector; and a reject pipe having a first end fluidly connected to the reject collection chamber and a second end fluidly connected to a third connector located proximate the first and second connectors. Each filtration membrane stack includes a plurality of filtration membranes, and the plurality of filtration membrane stacks together define a plurality of axially successive sets of radially adjacent filtration membranes. Also, each filtration membrane of each of the sets of filtration membranes is sealed to a corresponding hole in a respective one of the partition plates.
