A packer assembly includes a packer mandrel and a packing element disposed about the packer mandrel. An upper recovery sleeve is disposed about the packer mandrel and extending between the packer mandrel and an upper end of the packing element, and a lower recovery sleeve is disposed about the packer mandrel and extending between the packer mandrel and a lower end of the packing element. An upper backup assembly is movably disposed about the upper recovery sleeve and adjacent to the upper end of the packing element. A lower backup assembly is movably disposed about the lower recovery sleeve. The lower backup assembly has a lower backup ring assembly configured to enclose an outer surface of the lower end of the packing element. A retrieval sleeve is selectively movable relative to the lower backup ring assembly and configured to at least partially retract the lower backup ring assembly.
Fail-safe methods for deactivating the pulsed neutron generator (PNG) of a logging tool are described herein, as are logging tools configured to execute the fail-safe methods. The fail- safe methods deactivate the PNG if the logging tool is disposed in air outside of a borehole. Measurements taken using one or more gamma ray detectors of the logging tool are used to calculate a value for a parameter that is indicative of the tool being disposed in an air environment. Examples of such parameters include ratios of capture gamma rays and burst gamma rays. The disclosed methods operate without reference to sensors and/or control from outside the tool. The methods do not inadvertently deactivate the tool when it encounters an air-filled borehole.
G01V 5/10 - Prospection ou détection au moyen de radiations nucléaires, p.ex. de la radioactivité naturelle ou provoquée spécialement adaptée au carottage en utilisant des sources de radiation nucléaire primaire ou des rayons X en utilisant des sources de neutrons
Methods, tools, and systems for determining the lithium concentration of a formation traversed by a wellbore using pulsed neutron logging are described. Since determining lithium directly using pulsed neutron logging is problematic, this disclosure provides ways of determining lithium concentration indirectly using models that relate lithium concentration with concentrations of other elements that are predicted to be associated with lithium.
G01V 5/10 - Prospection ou détection au moyen de radiations nucléaires, p.ex. de la radioactivité naturelle ou provoquée spécialement adaptée au carottage en utilisant des sources de radiation nucléaire primaire ou des rayons X en utilisant des sources de neutrons
A flow measurement apparatus can include a main flow passage, a bypass flow passage having an inlet and an outlet connected with the main flow passage, a mass flowmeter connected in the bypass flow passage between the inlet and the outlet, and a flow restrictor connected in the bypass flow passage between the inlet and the outlet. A method can include connecting the flow measurement apparatus, so that a fluid flow in the well also flows through the flow measurement apparatus, and determining at least one rheological parameter of a non-Newtonian fluid, based on an output of the flow measurement apparatus.
E21B 21/08 - Commande ou surveillance de la pression ou de l'écoulement du fluide de forage, p.ex. remplissage automatique des trous de forage, commande automatique de la pression au fond
G01F 15/02 - Compensation ou correction des variations de pression, de poids spécifique ou de température
G01F 1/84 - Débitmètres massiques du type Coriolis ou gyroscopique
5.
DEBRIS EXCLUSIVE-PRESSURE INTENSIFIED-PRESSURE BALANCED SETTING TOOL FOR LINER HANGER
A system and method set a liner hanger in a borehole by actuating a hydraulic setting mechanism on the hanger to engage slips in the borehole. A setting tool runs the hanger into position. A reserve volume of the tool holds a clean fluid separate from the borehole. A piston of the tool has a tool volume for the fluid. During run in, pressure in the tool volume is balanced to hydrostatic pressure by drawing actuation fluid from the reserve volume to the tool volume through a check valve. To set the hanger, a plug is engaged on a seat in the tool, tubing pressure is applied behind the engaged plug, and the seat is unlocked. With more applied pressure, the piston moves, reduces the tool volume, and intensifies pressure of the clean fluid communicated to the hanger's setting mechanism. Over-pressure can be handled by a venting valve.
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 33/04 - Têtes de tubage; Suspension des tubages ou des colonnes de production dans les têtes de puits
E21B 43/10 - Mise en place de tubages, filtres ou crépines dans les puits
A stage tool used in a wellbore has two sub-housings that couple together. A first sleeve is movably disposed in the tool and is held closed with a temporary connection relative to a side port. The first sleeve has a first seat of millable material. A second sleeve is also movably disposed in the tool and is held open with a temporary connection relative to the side port. The second sleeve has a second seat of millable material. An opening plug lands on the first seat so pressure can break the connection and shift the first sleeve open relative to the side port. After pumping cement out of the tool, a closing plug pumped to the second seat allows pressure to break the connection and shift the second sleeve closed. The first sleeve includes a bypass that allows for fluid to pass beyond the seated plug.
E21B 33/14 - Procédés ou dispositifs de cimentation, de bouchage des trous, des fissures ou analogues pour la cimentation des tubes dans les trous de forage ou de sondage
E21B 34/14 - Aménagements des vannes pour les trous de forage ou pour les puits dans les puits actionnés par le mouvement des outils, p.ex. obturateurs à manchons actionnés par des pistons ou par des outils à câble
7.
REAL TIME DETECTION AND REACTION TO ANOMALIES IN THREADED CONNECTION MAKE-UP
A method (80) of making-up a threaded connection can include rotating a tubular (12), measuring torque (44) applied to the tubular during the rotating, thereby generating data (82) including measured torque values, detecting (84) an anomalous occurrence (70) in the data during the rotating, and ceasing (88) application of the torque to the tubular in response to detection of the anomalous occurrence. A threaded connection make-up system (10) can include a rotary clamp (24) to apply torque to a tubular, a torque sensor (44) to produce measurements of the applied torque, and a control system (52) including a neural network, an artificial intelligence device, machine learning and/or genetic algorithms trained to detect an anomalous occurrence in data input to the control system. The data may include the applied torque and turns of the tubular as measured by a turn sensor.
A downhole tool for use in a wellbore includes a cone, a cone adapter at least partially disposed in the cone, a shoe member, and a slip assembly disposed between the cone and the shoe member. A mandrel extends through the cone adapter and attached to the shoe member. The cone adapter is retrievable with the mandrel.
A bottom hole assembly for use in a subterranean well can include a whipstock, a mill releasably secured to the whipstock, an antenna, and a release mechanism configured to release the mill from the whipstock in response to a predetermined radio frequency signal received by the antenna. A method can include positioning a bottom hole assembly in a well, the bottom hole assembly including a mill and a whipstock releasably secured to the mill, and then releasing the mill from the whipstock by displacing a radio frequency identification tag into the bottom hole assembly. A well system can include a bottom hole assembly comprising an anchor, a whipstock and a mill, and a radio frequency identification tag displaceable with fluid flow into the bottom hole assembly.
E21B 7/06 - Modification de la direction du trou de forage
E21B 47/13 - Moyens pour la transmission de signaux de mesure ou signaux de commande du puits vers la surface, ou de la surface vers le puits, p.ex. pour la diagraphie pendant le forage par énergie électromagnétique, p.ex. gammes de fréquence radio
E21B 47/26 - Stockage des données en fond de puits, p.ex. dans une mémoire ou sur un support d'enregistrement
E21B 23/02 - Appareils pour déplacer, mettre en place, verrouiller, libérer ou retirer, les outils, les packers ou autres éléments dans les trous de forage pour verrouiller les outils ou autres éléments sur des supports ou dans des retraits entre sections adjacentes du tubage
E21B 47/12 - Moyens pour la transmission de signaux de mesure ou signaux de commande du puits vers la surface, ou de la surface vers le puits, p.ex. pour la diagraphie pendant le forage
A catcher for use in a wellbore includes a housing and an insert disposed within the housing. A method of using the catcher includes disintegrating at least a portion of the insert while the insert is held rotationally stationary with respect to the housing by a taper connection between the insert and the housing.
E21B 23/06 - Appareils pour déplacer, mettre en place, verrouiller, libérer ou retirer, les outils, les packers ou autres éléments dans les trous de forage pour le montage des packers
E21B 33/14 - Procédés ou dispositifs de cimentation, de bouchage des trous, des fissures ou analogues pour la cimentation des tubes dans les trous de forage ou de sondage
An operating tool (50) for an artificial lift system (20) includes a housing (52) having a key slot (60). The operating tool further includes at least one biasing member (56) disposed in the housing. The operating tool further includes a key (70) including a key head having a key profile, wherein the key head (72) is remove from the slot when aligned with the key slot. The operating tool further includes a cam including a cam profile, wherein the cam is disposed in the housing and biased toward the slot by the at least one biasing member, wherein the cam profile is configured to engage the key profile to align the key head with the key slot.
E21B 17/046 - Accouplements; Joints entre tige et trépan, ou entre tiges avec nervures, goupilles ou mâchoires et rainures complémentaires ou similaires, p.ex. accrochage à baïonnette
E21B 17/10 - Protecteurs contre l'usure; Dispositifs de centrage
A well tool assembly (12) can include a well barrier (22) and a detachable sub (24) connected to the well barrier. The detachable sub can include a sensor data receiver (28). A method of retrieving sensor data can include positioning a sensor (18) on one side of a well barrier (22), connecting a detachable sub (24) on an opposite side of the well barrier, the detachable sub including a sensor data receiver (28) configured to receive sensor data from the sensor, and conveying the well barrier, the sensor and the detachable sub together into a well. A system can include a sensor (18), a detachable sub (24), and a well barrier (22) positioned between the sensor and the detachable sub, the detachable sub including a sensor data receiver, a passage (32) extending longitudinally through the detachable sub, and a closure (30) that selectively opens and blocks the passage.
E21B 47/26 - Stockage des données en fond de puits, p.ex. dans une mémoire ou sur un support d'enregistrement
E21B 47/06 - Mesure de la température ou de la pression
E21B 47/12 - Moyens pour la transmission de signaux de mesure ou signaux de commande du puits vers la surface, ou de la surface vers le puits, p.ex. pour la diagraphie pendant le forage
A bottom hole assembly can include a mill and a whipstock having an upper end and an opening. A retractable pin extends from the mill into the opening. A section of the whipstock is separable from the whipstock in response to a force applied to the mill. The section is positioned between the opening and the upper end. A method can include positioning a bottom hole assembly in a well, the bottom hole assembly including a whipstock releasably secured to a mill, and then releasing the mill from the whipstock by separating a section of the whipstock from a remainder of the whipstock. Another method can include conveying a bottom hole assembly into a well, setting an anchor, then applying pressure to a hydraulic release mechanism, and then applying a force to the mill, thereby separating a section of the whipstock from a remainder of the whipstock.
A float valve is used in a tubular having a through-bore for flow. The tubular can be a casing joint, a casing pup joint, a housing or a shell of a float collar/shoe, or other tubular element. A sleeve of drillable material is expanded inside the tubular. Sealing and/or anchor elements on the exterior of the sleeve can engage inside the tubular. Caps composed of drillable material are disposed on ends of the sleeve and have passages connected to ends of a flow tube. The flow tube is also composed of drillable material and has a bore therethrough for flow. A valve composed of drillable material is disposed in the passage of one of the caps and is configured to control the flow in the tubing through the flow tube.
A float tool is used for controlling flow in tubing. The float tool comprises a housing, at least one valve, and at least one inset. The housing is configured to install on the tubing and has a longitudinal bore therethrough. The at least one valve is disposed in the longitudinal bore. The at least one valve is configured to allow the flow in a downbore direction through the longitudinal bore and is configured to prevent flow in a upbore direction through the longitudinal bore. The at least one inset is disposed in the longitudinal bore and is disposed downbore of the at least one valve. The at least one inset defines an orifice therethrough. The orifice has one or more vanes angled relative to the longitudinal bore. The one or more vanes are configured to produce turbulence in the flow in the downbore direction through the longitudinal bore.
E21B 33/16 - Procédés ou dispositifs de cimentation, de bouchage des trous, des fissures ou analogues pour la cimentation des tubes dans les trous de forage ou de sondage utilisant des bouchons pour isoler la charge de ciment; Bouchons à cet effet
E21B 34/10 - Aménagements des vannes pour les trous de forage ou pour les puits dans les puits actionnés par un fluide de commande provenant de l'extérieur du trou de forage
16.
CONTROLLED DEFORMATION AND SHAPE RECOVERY OF PACKING ELEMENTS
A packer assembly includes a mandrel and a packing element disposed about the mandrel. Upper and lower recovery sleeves are disposed about the mandrel and extend between the mandrel and respective upper and lower ends of the packing element. The upper and lower recovery sleeves each have a recovery profile embedded within the packing element. Upper and lower backup assemblies are movably disposed about the respective upper and lower recovery sleeves, adjacent to the respective upper and lower ends of the packing element. The packer assembly includes at least one release mechanism. When setting the packer assembly in a bore, the packing element is axially compressed between the upper and lower backup assemblies to contact the bore wall, and the upper and lower backup assemblies splay outwards. Upon release, the packing element and backup assemblies retract, thereby facilitating retrieval of the packer assembly from the bore.
A slip assembly includes a first support cone configured to move a first extension ramp between retracted and extended positions. The first extension ramp is biased towards the retracted position by a first biasing member. The slip assembly further includes a second support cone configured to move a second extension ramp between retracted and extended positions. The second extension ramp is biased towards the retracted position by a second biasing member. The slip assembly further includes a slip member disposed between the first extension ramp and the second extension ramp. The slip member is configured to slide between retracted and extended positions along an outer surface of the first extension ramp and along an outer surface of the second extension ramp. A shank of the slip member is held in a cage by a retainer that moves radially when the slip member moves between the retracted and extended positions.
E21B 23/06 - Appareils pour déplacer, mettre en place, verrouiller, libérer ou retirer, les outils, les packers ou autres éléments dans les trous de forage pour le montage des packers
E21B 23/01 - Appareils pour déplacer, mettre en place, verrouiller, libérer ou retirer, les outils, les packers ou autres éléments dans les trous de forage pour ancrer les outils ou similaires
E21B 23/04 - 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 33/128 - Packers; Bouchons avec un organe dilaté radialement par pression axiale
E21B 33/129 - Packers; Bouchons à patins mécaniques pour accrochage dans le tubage
18.
FLUID SAMPLER TOOL AND ASSOCIATED SYSTEM AND METHOD
A method including deploying into a well a fluid sampler tool (12) including a fluid sampler (28), a sampler valve (36, 38), a controller (40) and a sensor (42, 44), and the controller operating the sampler valve in response to a sensed well parameter being within a predetermined well parameter range. A fluid sampler tool (12) including a fluid sampler (28), a sampler valve (36, 38), a controller (40) and a carrier (32) configured to connect the fluid sampler tool in a tubular string (14), the controller being enclosed within a chamber (56) that is externally accessible on the carrier.
A system used downhole in tubing is operable with pressure communicated via at least one control line. The system includes a tool and a stinger. The tool disposed with the tubing has a tool bore for passage of tubing flow. The tool has an operator movable between operable states, and the operator has a tool key disposed in the bore. The stinger removably disposed in the tubing is configured to insert into the tool bore. The stinger has an actuator in communication with the at least one control line. Actuated by the control line, a stinger key disposed on the stinger is movable with the actuator between positions. In this way, the stinger key is configured to engage the tool key and is configured to move the tool's operator at least from the one state to another.
E21B 23/02 - Appareils pour déplacer, mettre en place, verrouiller, libérer ou retirer, les outils, les packers ou autres éléments dans les trous de forage pour verrouiller les outils ou autres éléments sur des supports ou dans des retraits entre sections adjacentes du tubage
E21B 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 34/10 - Aménagements des vannes pour les trous de forage ou pour les puits dans les puits actionnés par un fluide de commande provenant de l'extérieur du trou de forage
E21B 34/14 - Aménagements des vannes pour les trous de forage ou pour les puits dans les puits actionnés par le mouvement des outils, p.ex. obturateurs à manchons actionnés par des pistons ou par des outils à câble
E21B 34/16 - Moyens de commande situés à l'extérieur du trou de forage
20.
BEAM PUMPING UNIT INSPECTION SENSOR ASSEMBLY, SYSTEM AND METHOD
A sensor assembly can include a gyroscope, an accelerometer, and a housing assembly containing the gyroscope and the accelerometer. An axis of the gyroscope can be collinear with an axis of the accelerometer. A method of inspecting a well pumping unit can include attaching a sensor assembly to the pumping unit, recording acceleration versus time data, and in response to an amplitude of the acceleration versus time data exceeding a predetermined threshold, transforming the data to acceleration versus frequency data. A method of balancing a well pumping unit can include comparing peaks of acceleration versus rotational orientation data to peaks of acceleration due to circular motion, and adjusting a position of a counterweight, thereby reducing a difference between the peaks of acceleration due to circular motion and the peaks of the acceleration versus rotational orientation data for subsequent operation of the pumping unit.
A piston initiator is used on an assembly having a milling tool (60) and a whipstock (70) for creating a sidetrack in a wellbore. A piston (120) disposed in an uphole position in a bore (112) of the milling tool seals the bore from communicating with a side port (118). A line (155) from the port can communicate pressure to components on the whipstock for initiating their activation. The piston is movable from the uphole position, but is held by a releasable connection (141) configured to release the piston in response to a predetermined force from fluid flow in a downhole direction against an exposed surface area of the piston. An uphole shoulder (114) in the milling tool prevents movement of the piston in an uphole direction in response to reverse fluid flow through the milling tool.
E21B 7/06 - Modification de la direction du trou de forage
E21B 34/10 - Aménagements des vannes pour les trous de forage ou pour les puits dans les puits actionnés par un fluide de commande provenant de l'extérieur du trou de forage
22.
SIDETRACK ASSEMBLY WITH REPLACEMENT MILL HEAD FOR OPEN HOLE WHIPSTOCK
A sidetrack assembly for forming a lateral wellbore includes a cutting device having a body having a passage, and a mill head configured to connect to the body so that an interior of the mill head and the body form a pressure chamber in fluid communication with the outlet passage. The mill head includes a first port in fluid communication with the pressure chamber, a second port in fluid communication with the pressure chamber, and a blade arranged on a face of the mill head. A whipstock connected to the cutting device includes a tubing having a first end removably inserted in the first port and the passage and a second end connectable to a downhole tool, an inclined surface for guiding the mill at a non-zero angle relative to a central axis of an existing wellbore, and an attachment section removably connecting the cutting device and the whipstock.
The present disclosure generally relates to a flapper valve including a pressure relief assembly. The pressure relief assembly is operable to activate when a pressure differential across the flapper approaches or exceeds a design pressure of the flapper.
E21B 34/08 - Aménagements des vannes pour les trous de forage ou pour les puits dans les puits sensibles à l'écoulement ou à la pression du fluide obtenu
A method of making-up tubular string components can include inputting to an image processor image data output from at least one camera (28), the image processor in response detecting positions of a tubular (14) and a mark (30) on another tubular (20), threading the tubulars with each other while inputting position data from the image processor to a controller, and the controller terminating the threading in response to the position of the mark relative to the position of the first tubular being within a predetermined range. Another method of making-up tubular string components can include, in response to inputting image data to an image processor, the image processor detecting longitudinal positions of two tubulars, threading the tubulars with each other, and a controller terminating the threading in response to the longitudinal position of one tubular relative to the longitudinal position of the other tubular being within a predetermined range.
A method of making-up or breaking-out tubular string components can include threading tubulars with each other while a camera obtains images of the tubulars, outputting image data from the camera to an image processor that detects optical flow vector fields from the image data, the optical flow vector fields representing displacements of the respective tubulars during the threading, and controlling the threading in response to a difference between the displacements. Another method can include positioning a camera so that the camera simultaneously observes at least two tubulars, threading the tubulars with each other, outputting image data from the camera to an image processor, the image processor detecting optical flow vector fields from the image data, the optical flow vector fields representing displacements of the respective tubulars during the threading, and controlling the threading in response to the image processor detecting the optical flow vector fields.
A gravel pack assembly for a borehole has first and second joints and a foil. The basepipes of the joints connect end-to-end, and both of the basepipes having filters for filtering fluid passage from a borehole into bores of the basepipes. Transport tubes are disposed along the first and second joint, and a jumper tube expands across the connected ends of the basepipes and connects the transport tubes together. The foil encloses an area across the connected ends. The foil has an external surface defining an annulus thereabout with the borehole. The foil has end rings abutting the filters of the joints. At least a section of the foil leaks fluid from the borehole to the area enclosed by the foil, and at least a filter portion of the assembly filters the leaked fluid from the area to at least one of the first and second bores.
A load cell for use with a tong assembly includes a body; a chamber formed in the body; and a strain gauge disposed in the chamber. The load cell also includes a first eye for pivotal coupling to the tong assembly, and a second eye for pivotal coupling to the tong assembly. An optional biasing member is disposed around the second eye for biasing the body relative to the tong assembly.
A liner string (10) for a wellbore includes a liner hanger assembly LHA (30) and a liner hanger deployment assembly LHDA (20) releasably attached to the LHA (30). The LHDA (20) includes a central bore (21) and a running tool (400) moveable from a locked position to an unlocked position, the running tool including a flow path in communication with the central bore (21). The liner string further includes a chamber (900) disposed between the LHDA and LHA, wherein the chamber is in selective fluid communication with the flow path. Wherein, when the flow path is closed, the chamber (900) is isolated from the central bore, and when the flow path is open, the flow path provides fluid communication between central bore and chamber (900).
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 33/04 - Têtes de tubage; Suspension des tubages ou des colonnes de production dans les têtes de puits
E21B 34/10 - Aménagements des vannes pour les trous de forage ou pour les puits dans les puits actionnés par un fluide de commande provenant de l'extérieur du trou de forage
A method and apparatus for operating a debris collection tool (500). The tool includes a cover assembly (100) having a plurality of covers (120) spaced from one another along the length of the assembly creating a gap between adjacent covers. A carrier (300) disposed within the cover assembly is axial movable relative thereto and has a plurality of magnet groups (310) spaced from one another along its length. In an unactuated position of the tool (500), each of the plurality of magnet groups (310) is under one of the plurality of covers and in an actuated position, each of the plurality of magnets (310) is in a gap between covers.
Aspects of the present disclosure relate to a multiple range load cell capable of automatically switching measuring range and method for operating the multiple range load cell.
E21B 19/00 - Manipulation de tiges, tubages, tubes ou autre objets analogues à l'extérieur du trou de forage, p.ex. dans la tour de forage; Appareils pour faire avancer les tiges ou les câbles
E21B 47/00 - Relevés dans les trous de forage ou dans les puits
G01D 3/024 - Dispositions pour la mesure prévues pour les objets particuliers indiqués dans les sous-groupes du présent groupe avec dispositions pour changer ou corriger la fonction de transfert pour changer la plage de fonctionnement; Dispositions pour remplacer un organe sensible par un autre
A tong for handling a tubular includes a jaw carrier having an active jaw movable from a retracted position to an extended position relative to the jaw carrier; a cam body disposed about the jaw carrier and rotatable relative to the cam body; and a brake assembly including an first brake member for engaging an upper surface coupled to the jaw carrier.
ABSTRACT A system and method controls a plurality of artificial lift units at a plurality of wellsites. Processing equipment installs at a plurality of the wellsites. Operating parameters of each of the artificial lift units are obtained with sensing equipment at the wellsites and are communicated in real-time from the wellsites to the installed processing equipment at the plurality of the wellsites. A modelling function of the processing equipment analyzes a trend of the operating parameters of the artificial lift units, and automated machine learning of the processing equipment predicts a condition of at least one of the artificial lift units based on the analyzed trend. The processing equipment determines at least one automated control for the determined condition of the at least one artificial lift unit and counters the determined condition by implementing the at least one automated control at the at least one artificial lift unit. CA 3060937 2019-11-06
E21B 43/12 - Procédés ou appareils pour commander l'écoulement du fluide extrait vers ou dans les puits
E21B 47/12 - Moyens pour la transmission de signaux de mesure ou signaux de commande du puits vers la surface, ou de la surface vers le puits, p.ex. pour la diagraphie pendant le forage
A liner string includes a liner hanger assembly and a liner hanger deployment assembly. The liner hanger assembly includes a liner hanger. The liner hanger includes a plurality of slips and a liner hanger actuation assembly configured to set the plurality of slips. The liner hanger deployment assembly is disposed within the liner hanger assembly. The liner hanger deployment assembly includes a setting tool configured to selectively allow fluid communication between a central bore of the setting tool and the liner hanger actuation assembly.
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 23/06 - Appareils pour déplacer, mettre en place, verrouiller, libérer ou retirer, les outils, les packers ou autres éléments dans les trous de forage pour le montage des packers
E21B 33/04 - Têtes de tubage; Suspension des tubages ou des colonnes de production dans les têtes de puits
E21B 34/06 - Aménagements des vannes pour les trous de forage ou pour les puits dans les puits
E21B 34/10 - Aménagements des vannes pour les trous de forage ou pour les puits dans les puits actionnés par un fluide de commande provenant de l'extérieur du trou de forage
E21B 34/14 - Aménagements des vannes pour les trous de forage ou pour les puits dans les puits actionnés par le mouvement des outils, p.ex. obturateurs à manchons actionnés par des pistons ou par des outils à câble
A power tong including a rotary gripping apparatus having a rotary base having a first jaw and at least one rotary arm movable relative to the rotary base between an open position and a closed position, the at least one rotary arm having a second jaw. A gap is present between the rotary base and the at least one rotary arm for receiving the tubular when the at least one rotary arm is in the open position. The gap is closed when the at least one rotary arm is in the closed position.
Near- Infra red (NIR) filter photometry is used to calculate component concentrations in multiphase flows. The disclosed methodology adapts the Beer-Lambert law for nonhomogeneous immiscible mixtures (such as oil and water) by modeling the fluid layer as a nonhomogeneous distribution of its components and deriving a mathematical relationship between measured absorbances, component path lengths, and non-homogeneity factors. The methodology is integrated into a multi-channel filter photometer to measure phase concentrations in oil-and-gas pipelines.
G01N 21/359 - Couleur; Propriétés spectrales, c. à d. comparaison de l'effet du matériau sur la lumière pour plusieurs longueurs d'ondes ou plusieurs bandes de longueurs d'ondes différentes en recherchant l'effet relatif du matériau pour les longueurs d'ondes caractéristiques d'éléments ou de molécules spécifiques, p.ex. spectrométrie d'absorption atomique en utilisant la lumière infrarouge en utilisant la lumière de l'infrarouge proche
G01N 21/31 - Couleur; Propriétés spectrales, c. à d. comparaison de l'effet du matériau sur la lumière pour plusieurs longueurs d'ondes ou plusieurs bandes de longueurs d'ondes différentes en recherchant l'effet relatif du matériau pour les longueurs d'ondes caractéristiques d'éléments ou de molécules spécifiques, p.ex. spectrométrie d'absorption atomique
G01N 21/85 - Analyse des fluides ou solides granulés en mouvement
A system and method are used in drilling a borehole in a formation. A trip to move a drillstring in the borehole is identified, where the trip is expected to produce a piston effect that changes a downhole pressure of the fluid in the borehole. A peak speed to move the drillstring in the borehole is calculated for the trip, and adjustments to a surface backpressure of the drilling system is calculated for the trip at the calculated peak speed to keep the downhole pressure within a tolerance of the formation. The drillstring is moved in the trip according to the calculated peak speed, and the downhole pressure change produced by the piston effect is counteracted by automatically adjusting the surface backpressure according to the calculated adjustments.
E21B 21/08 - Commande ou surveillance de la pression ou de l'écoulement du fluide de forage, p.ex. remplissage automatique des trous de forage, commande automatique de la pression au fond
E21B 44/00 - Systèmes de commande automatique spécialement adaptés aux opérations de forage, c. à d. systèmes à fonctionnement autonome ayant pour rôle d'exécuter ou de modifier une opération de forage sans l'intervention d'un opérateur humain, p.ex. systèmes de ; Systèmes spécialement adaptés à la surveillance de plusieurs variables ou conditions de forage
E21B 45/00 - Mesure du temps de forage ou de la vitesse de pénétration
E21B 47/06 - Mesure de la température ou de la pression
An apparatus and method are disclosed for wet shoe applications in cementing tubing in a wellbore. A wet shoe tool has a seat and an insert in a flow bore of the tool. A first wiper plug is deployed down the tubing at least behind the cement and seats on the insert, which can then be moved in the flow bore to a bypass position allowing for fluid flow through the tool to produce a wet shoe track. A second plug is deployed down the tubing behind the second plug and seats on the seat in the flow bore of the tool. The seated second plug isolates applied pressure from passing downhole end of the tool so the integrity of the tubing can be tested. The second plug is self-removable (e.g., dissolvable) in the tool to reestablish fluid communication through the flow bore of the tool.
E21B 33/16 - Procédés ou dispositifs de cimentation, de bouchage des trous, des fissures ou analogues pour la cimentation des tubes dans les trous de forage ou de sondage utilisant des bouchons pour isoler la charge de ciment; Bouchons à cet effet
E21B 33/14 - Procédés ou dispositifs de cimentation, de bouchage des trous, des fissures ou analogues pour la cimentation des tubes dans les trous de forage ou de sondage
A wet mate connection can include two connector assemblies, each connector assembly including at least one connector and a protective barrier displaceable between closed and open positions, and one connector assembly including an engagement device that displaces the protective barrier of the other connector assembly from the closed position to the open position in response to engagement between the connector assemblies. A method of making a connection between lines in a well can include installing a connector assembly, then installing another connector assembly, each connector assembly including a connector and an alignment profile, then axially compressing the connector assemblies, thereby opening protective barriers for the respective connectors, operatively connecting the connectors, and engaging the alignment profiles, thereby maintaining rotational alignment of the connectors. A system for use with a well can include a wet mate optical connection made between packers of the respective connector assemblies.
A method of manufacturing a centralizer having a plurality of blades is provided, and includes cutting the plurality of blades from a metal sheet. The method further includes hardening the plurality of blades using a heat treatment process, and welding the plurality of blades to a tubular body. The blades may be welded to the tubular body using a plurality of weld seams.
A well barrier can include an inner mandrel, a flow passage, and a releasably secured plug. The plug blocks fluid flow through the flow passage, and includes a shoulder that prevents the plug from displacing completely through the inner mandrel. A method of treating a subterranean well can include treating a deeper zone, setting a well barrier in the well between the deeper zone and a shallower zone, then treating the shallower zone, and then applying a pressure differential from the deeper to the shallower zone, thereby displacing a plug out of the well barrier. A well treatment system can include a well barrier with a plug releasably secured to an inner mandrel. The plug is released by application of a pressure differential in a longitudinal direction, and fluid communication is unblocked by application of a pressure differential in an opposite longitudinal direction.
ABSTRACT A well barrier can include an inner mandrel, a flow passage, and a releasably secured plug. The plug blocks fluid flow through the flow passage, and includes a shoulder that prevents the plug from displacing completely through the inner mandrel. A method of treating a subterranean well can include treating a deeper zone, setting a well barrier in the well between the deeper zone and a shallower zone, then treating the shallower zone, and then applying a pressure differential from the deeper to the shallower zone, thereby displacing a plug out of the well barrier. A well treatment system can include a well barrier with a plug releasably secured to an inner mandrel. The plug is released by application of a pressure differential in a longitudinal direction, and fluid communication is unblocked by application of a pressure differential in an opposite longitudinal direction. Date Regue/Date Received 2022-11-16
Methods and tools for determining one or more parameters of an earth formation using time-of-flight (TOF) measurements of fast neutrons through the formation are disclosed. The disclosed tools feature a neutron source capable of emitting a population of fast neutrons having a distribution of neutron energies and one or more neutron detectors. The TOF of the fast neutrons travelling from the neutron source to the detector(s) and traversing a portion of the formation is measured and binned as a function of TOF (which is a function of neutron energy). By determining which neutron energies are attenuated by the intervening formation, the composition of the intervening formation is determined.
G01V 5/10 - Prospection ou détection au moyen de radiations nucléaires, p.ex. de la radioactivité naturelle ou provoquée spécialement adaptée au carottage en utilisant des sources de radiation nucléaire primaire ou des rayons X en utilisant des sources de neutrons
G01T 3/06 - Mesure de flux de neutrons avec des détecteurs à scintillation
43.
METHOD AND SYSTEM FOR BOOSTING SEALING ELEMENTS OF DOWNHOLE BARRIERS
A downhole barrier can include a housing disposed between a slip and a seal element, a mandrel extending through the housing and the seal element, and a piston fixed to the mandrel and separating two chambers in the housing. One chamber is positioned between the slip and the other chamber, and is in communication with a passage in the mandrel. The other chamber is in communication with an exterior of the barrier. A system can include a downhole barrier set in a wellbore. The barrier can include a housing disposed between a slip and a seal element, a mandrel, and a piston fixed to the mandrel, the piston separating two chambers in the housing. An outer area of the mandrel in one chamber is equal to twice a difference between an inner area of the housing and an outer area of the mandrel in the other chamber.
For a wellbore drilled in low or subnormal pressure reservoirs, a static loss rate of drilling fluid is monitored within a limit of a drilling rate. Reaching the limit, the annulus is closed off to returns, or the annulus remains open to atmosphere at surface. Operations may not be able to keep the annulus filled with a mud cap so pressurized mud cap drilling cannot be sustained. Instead, an initial fluid level of the mud cap is defined in the annulus. Drilling with the mud cap then involves: pumping a sacrificial fluid through the drillstring without returns to surface, and monitoring the initial fluid level in the annulus to detect a change. Monitoring uses downhole instrumentation to measure pressure, temperature, and gas level of the mud cap. In response to the change, the drilling can be further controlled, including stopping the drilling, turning off pumps, and possibly bullheading the well.
E21B 21/08 - Commande ou surveillance de la pression ou de l'écoulement du fluide de forage, p.ex. remplissage automatique des trous de forage, commande automatique de la pression au fond
45.
DRILLING SYSTEM AND METHOD USING CALIBRATED PRESSURE LOSSES
Control of a drilling system drilling a wellbore is improved using a hydraulic model corrected for pressure losses. A surface backpressure of the outlet and a standpipe pressure of the inlet are measured with sensors in the system. An estimate of the standpipe pressure is calculated based integrating from the measured surface backpressure back to the inlet in the hydraulics model. The pressure loss increment in the hydraulics model is calculated based on a difference between the measured and estimated standpipe pressures. Meanwhile, a parameter in the drilling system is monitored during drilling so the parameter can be adjusted at least partially based on the hydraulics model corrected for the pressure loss.
E21B 21/08 - Commande ou surveillance de la pression ou de l'écoulement du fluide de forage, p.ex. remplissage automatique des trous de forage, commande automatique de la pression au fond
E21B 44/00 - Systèmes de commande automatique spécialement adaptés aux opérations de forage, c. à d. systèmes à fonctionnement autonome ayant pour rôle d'exécuter ou de modifier une opération de forage sans l'intervention d'un opérateur humain, p.ex. systèmes de ; Systèmes spécialement adaptés à la surveillance de plusieurs variables ou conditions de forage
46.
CALIPER-BEHIND-CASING FROM PULSED NEUTRON APPARATUS
A caliper-behind casing apparatus and method determines a location and size of a washout (i.e., a void) behind casing in a borehole for a salt cavern used for storing hydrocarbons. The cavern and tubing in the casing are filled with brine. Gaseous nitrogen is used to fill an annulus between the tubing and the casing above and below a casing shoe to obtain image responses from operating a pulsed neutron logging tool in the tubing along the borehole. Analysis of burst ratios of near and far detectors on the pulsed neutron logging tool from these passes is used to detect and estimate a void or washout in the formation behind the casing.
A gas migration prevention module can include a housing, control line connections configured to connect the housing between control line sections, spaced apart pistons sealingly received in the housing, and a fluid volume defined between the pistons. A control line system can include an upper control line section, a lower control line section in fluid communication with a downhole tool, and a gas migration prevention module connected between the upper and lower control line sections, the lower control line section providing fluid communication between the gas migration prevention module and the downhole tool, and the gas migration prevention module comprising spaced apart pistons and a fluid volume defined between the pistons, the fluid volume being in fluid communication with an exterior of the gas migration prevention module.
E21B 34/08 - Aménagements des vannes pour les trous de forage ou pour les puits dans les puits sensibles à l'écoulement ou à la pression du fluide obtenu
E21B 43/12 - Procédés ou appareils pour commander l'écoulement du fluide extrait vers ou dans les puits
A valve assembly (50) can include a flow passage (38) extending between an uphole end (54) and a downhole end (56) of the valve assembly, a flapper (62) that pivots between an open position and a closed position, and a pump (82) operable to pivot the flapper, the pump being positioned between the flapper and the downhole end. A method of testing a completion tubing string (22) can include increasing pressure in the completion tubing string while a closure member (62) of a valve assembly is in a closed position, thereby testing a pressure integrity of the completion tubing string on an uphole side of the closure member, and transmitting a pressure signal via a flow passage to a pressure sensor (90) of the valve assembly, thereby causing the closure member to displace to an open position, the pressure sensor being connected to an electronic circuit (86) positioned on a downhole side of the closure member.
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 47/117 - Détection de fuites, p.ex. du tubage, par test de pression
E21B 47/12 - Moyens pour la transmission de signaux de mesure ou signaux de commande du puits vers la surface, ou de la surface vers le puits, p.ex. pour la diagraphie pendant le forage
A liner assembly is used for a polished rod of a reciprocating pump movable through a stuffing box. A liner sleeve positions on the polished rod and has an external thread on its distal ends. Roots of the external thread increase in depth along the length toward the distal end. A nut positions on the polished rod and has internal thread configured to thread to the liner sleeve's external thread. A head positions on the polished rod. The head is configured to engage the polished (e.g., with clamping or fastening), and the head is configured to affix to the nut (e.g., with thread or with flanges and fasteners). A gasket positions on the polished rod between the nut and the head. The gasket is held between a nose of the nut and a smooth bore relief of the head or is held between reliefs on the nut and head.
E21B 33/04 - Têtes de tubage; Suspension des tubages ou des colonnes de production dans les têtes de puits
F04B 47/02 - Pompes ou installations de pompage spécialement adaptées pour élever un fluide à partir d'une grande profondeur, p.ex. pompes de puits les mécanismes d'entraînement étant placés au niveau du sol
F16J 15/06 - Joints d'étanchéité entre surfaces immobiles entre elles avec garniture solide comprimée entre les surfaces à joindre
Embodiments of the present disclosure relate to apparatus and methods for locating a tubular joint using two dimensional images. A tubular feature may be located by capturing a first two dimensional image of a tubular, capturing a second two dimensional image of the tubular including a reference, identifying a tubular joint or stick-up of the tubular from the first or second two dimensional image, and determining a vertical position of the tubular joint or stick-up of the tubular using the reference.
A riser extending from a floating rig has a riser manifold. A rig manifold can be manipulated by an arm to couple in an automated manner to the riser manifold when running the riser from the rig. The riser and rig manifolds have mechanical connectors that mechanically connect them. Additionally, the manifolds have flow couplings mating together for conducting flow in at least one flow connection, and the manifolds control couplings mating together for conducting control in at least one flow connection. At least one of the manifolds has at least one valve controllable with the at least one control connection and configured to control fluid communication for the at least one flow connection between at least one rig flow line and an internal passage of the riser.
E21B 17/046 - Accouplements; Joints entre tige et trépan, ou entre tiges avec nervures, goupilles ou mâchoires et rainures complémentaires ou similaires, p.ex. accrochage à baïonnette
E21B 19/00 - Manipulation de tiges, tubages, tubes ou autre objets analogues à l'extérieur du trou de forage, p.ex. dans la tour de forage; Appareils pour faire avancer les tiges ou les câbles
E21B 21/08 - Commande ou surveillance de la pression ou de l'écoulement du fluide de forage, p.ex. remplissage automatique des trous de forage, commande automatique de la pression au fond
52.
SELF-ALIGNING, MULTI-STAB CONNECTIONS FOR MANAGED PRESSURE DRILLING BETWEEN RIG AND RISER COMPONENTS
A riser (20) extending from a floating rig (12) includes one or more flow control devices (30, 32, 34) having at least one flow connection (90a) and having at least one control connection (90b). A riser manifold (100a) is disposed on the riser above the one or more flow control devices and has a first mechanical connector (106), a first flow coupling, and a first control coupling. A rig manifold (150a, b) can be manipulated by an arm to couple in an automated manner to the riser manifold (100a, b) when running the riser from the rig. The rig manifold (150a, b) has a second mechanical connector (156) that mechanically connects to the first mechanical connector of the riser manifold. Additionally, the rig manifold has a second flow coupling mating with the first flow coupling of the riser manifold for conducting flow, and has a second control coupling mating with the first control coupling of the riser manifold for conducting control.
E21B 17/046 - Accouplements; Joints entre tige et trépan, ou entre tiges avec nervures, goupilles ou mâchoires et rainures complémentaires ou similaires, p.ex. accrochage à baïonnette
E21B 19/00 - Manipulation de tiges, tubages, tubes ou autre objets analogues à l'extérieur du trou de forage, p.ex. dans la tour de forage; Appareils pour faire avancer les tiges ou les câbles
E21B 21/08 - Commande ou surveillance de la pression ou de l'écoulement du fluide de forage, p.ex. remplissage automatique des trous de forage, commande automatique de la pression au fond
A sucker rod can include a base metal, a corrosion resistant layer on the base metal, and an abrasion resistant layer external to the corrosion resistant layer, the abrasion resistant layer comprising a phenolic material. Another sucker rod can include a base metal, a corrosion resistant layer on the base metal, and an abrasion resistant layer external to the corrosion resistant layer, the abrasion resistant layer comprising an abrasion resistant particulate material and a matrix material. A method of producing a continuous sucker rod can include displacing the continuous sucker rod through a surface treatment system, applying a corrosion resistant layer on a base metal of the continuous sucker rod, then applying an abrasion resistant layer external to the corrosion resistant layer.
A tong for use at a wellbore includes a tong body; at least one door pivotally coupled to the tong body and movable between an open position and a closed position; a carrier ring rotatable relative to the tong body; and a brake plate coupled to the carrier ring. The tong also includes a brake band configured to move with the at least one door between the open and closed positions, and a braking member for moving the brake band into contact with the brake plate to stop rotation of the carrier ring.
Embodiments of the present disclosure relate to apparatus and methods for making up and evaluating tubular threaded connections. A tong assembly may be used for making up threaded connections. A threaded connection may be made up automatically by controlling the rotation speed of the tong assembly according to measurements of torque, turns, and/or time. After a threaded connection is made up, measurements of time, torque, and/or turns may be corrected based on operating parameters. The corrected measurements may be evaluated for indications of failure, such as discontinuity, torque spikes, and torque drops. The threaded connection is then accepted or rejected based on the evaluation.
A bottom hole assembly (BHA), comprising a whipstock including a latch release mechanism; a milling tool including a plurality of blades and a lock mechanism; and a collar coupled to a first end of the whipstock. The collar and the first end of the whipstock define an opening. A portion of the milling tool is disposed in the opening and the blades of the milling tool abut the collar. The milling tool is releasably coupled to the whipstock by the interaction of the latch release mechanism and the lock mechanism.
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 7/06 - Modification de la direction du trou de forage
E21B 7/08 - Dispositifs particuliers pour modifier la direction du forage, p.ex. trépans particuliers, joints articulés, sifflets-déviateurs
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
Methods and apparatus for releasing a downhole tool of a BHA from a whipstock in a wellbore include a latch release mechanism disposed on a whipstock. The latch release mechanism has a latch actuator and a latch member. The latch actuator has a switch and an actuator piston disposed in housing having an inlet. The inlet is in fluid communication with the actuator piston. The switch has first, intermediate, and second configurations. Fluid communication between the inlet and the actuator piston is blocked when the switch is in the first and intermediate configurations, and the fluid communication is unblocked when the switch is in the second configuration. The actuator piston is coupled to the latch member and configured to move the latch member out of engagement with a lock mechanism of the downhole tool in response to fluid communication from the inlet when the switch is in the second configuration.
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 7/06 - Modification de la direction du trou de forage
E21B 7/08 - Dispositifs particuliers pour modifier la direction du forage, p.ex. trépans particuliers, joints articulés, sifflets-déviateurs
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
An assembly for use downhole. The assembly comprises an actuator and a switch assembly. The switch assembly has a housing having an inlet in selective fluid communication with the actuator; and a switch having a first configuration, an intermediate configuration, and a second configuration. The switch is a piston assembly with a piston having a first piston head and a second piston head. The first piston head has a greater piston surface area than a piston surface area of the second piston head. The switch blocks the fluid communication between the inlet and the actuator when in the first configuration and the intermediate configuration. The switch allows the fluid communication between the inlet and the actuator when in the second configuration.
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 7/06 - Modification de la direction du trou de forage
Methods and apparatus for releasing a downhole tool of a BHA from a whipstock in a wellbore include a latch release mechanism disposed on a whipstock. The latch release mechanism has a latch actuator and a latch member. The latch actuator has a switch and an actuator piston disposed in housing having an inlet. The inlet is in fluid communication with the actuator piston. The switch has first, intermediate, and second configurations. Fluid communication between the inlet and the actuator piston is blocked when the switch is in the first and intermediate configurations, and the fluid communication is unblocked when the switch is in the second configuration. The actuator piston is coupled to the latch member and configured to move the latch member out of engagement with a lock mechanism of the downhole tool in response to fluid communication from the inlet when the switch is in the second configuration.
A float shoe for a downhole tubular or casing includes a housing, a nose, a support, and a valve. The housing is attached to the casing, and the nose having a shell of a millable material (e.g., composite, aluminum, etc.) extends from the housing. A support of cement, fills an internal cavity of the nose's shell and support a valve in the housing. The shell for the nose defines a flow passage communicating with the valve and can have a conical or eccentric shape to facilitate passage of the float shoe in a borehole during run-in. The shell for the nose can also have a port or jet that communicate the flow passage out the side of the nose.
E21B 33/14 - Procédés ou dispositifs de cimentation, de bouchage des trous, des fissures ou analogues pour la cimentation des tubes dans les trous de forage ou de sondage
A tubular handling assembly includes a mandrel; a plurality of gripping elements for gripping a tubular, the plurality of gripping elements coupled to and rotatable with the mandrel; one or more accumulators; a first actuator configured to supply fluid to the one or more accumulators; and a second actuator configured to receive fluid from at least one of the one or more accumulators and to actuate the plurality of gripping elements.
A bottom hole assembly for use in a wellbore includes a whipstock; a downhole tool coupled to the whipstock; and a cleaning tool coupled to the downhole tool for cleaning a portion of a wall of the wellbore, wherein the downhole tool is configured to engage the cleaned portion of the wall. In one example, the cleaning tool includes a body and a plurality of cleaning elements for cleaning the portion of the wall.
The present disclosure generally relates to a tong assembly having position sensors for controlling door opening and closing sequence. The tong assembly includes a back section, an outer door section movably coupled to the back section, a first actuator configured to move the outer door section between an open position and a closed position, an inner door section movably coupled to the back section, a second actuator configured to move the inner door section between an open position and a closed position, a first sensor positioned to measure a position of the outer door section; and a second sensor positioned to measure a position of the inner door section.
A sucker rod assembly for use downhole includes sucker rods and couplings. The sucker rods having pin connections with a pin face and a threaded pin. The coupling make up adjoining rods using box connections each having a box face and internal thread. Dry film lubrication is applied only to the internal thread of the couplings and excluded from the box face of the box connections. During make up, the dry film lubrication can help prevent seizing and/or galling of the threads for the connection between the coupling and the rods. The box connection is circumferentially displaced relative to the pin connection to place a preload on the pin, and the box face has a friction abutment with the pin face.
A method for connecting a tong cassette and a positioning device includes moving a positioning arm of the positioning device toward a predetermined position on the rig; identifying a position of the tong cassette relative to the positioning arm; and connecting the positioning arm to the tong cassette. A system includes a tong cassette; and a positioning device having a first sensor configured to measure a distance between the tong cassette and the positioning device; and a second sensor configured to measure a stick-up height of a tubular string.
A downhole apparatus for use in a tubular (10) includes a mandrel (30), a slip (120), a wedge (150), a cone (110), and seal elements (140, 160). The mandrel, which can be permanent or temporary, has an end shoulder (35). The slip (120) is disposed on the mandrel (30) adjacent the first end shoulder (35), and the wedge (150) is disposed on the mandrel between the (110) cone and the slip (120). The cone (110) is movable relative to the end shoulder (35) to engage the slip (120) toward the tubular. The seal elements (140, 160) are disposed on the wedge (150) and slip (120) and fit between each other. The fit seal elements seal against the tubular (10) and seas off fluid communication in the annular space between the plug and the tubular (10).
E21B 23/01 - Appareils pour déplacer, mettre en place, verrouiller, libérer ou retirer, les outils, les packers ou autres éléments dans les trous de forage pour ancrer les outils ou similaires
E21B 33/129 - Packers; Bouchons à patins mécaniques pour accrochage dans le tubage
E21B 34/06 - Aménagements des vannes pour les trous de forage ou pour les puits dans les puits
E21B 34/14 - Aménagements des vannes pour les trous de forage ou pour les puits dans les puits actionnés par le mouvement des outils, p.ex. obturateurs à manchons actionnés par des pistons ou par des outils à câble
67.
APPARATUS AND METHOD FOR FORMING A LATERAL WELLBORE
An assembly for forming a lateral wellbore includes a mill having a bore and a plurality of blades; a whipstock having an inclined surface for guiding movement of the mill, the mill releasably connected to the whipstock; and a tubing disposed in the bore of the mill and the whipstock. In one example, at least one of the plurality of blades is disposed in a slot formed in the whipstock.
For gas lift, gas lift valves install on a completion in a wellbore. The gas lift valve has a pressure-sensitive valve (140,150) and a check valve (160) configured to control communication in the valve. A piston (210) is held closed with a first connection (230) relative to the valve's outlet exposed to tubing pressure, while the check valve is held open in the valve with a second connection (240). Pressure testing can be performed on the integrity of the tubing and casing by increasing the tubing and annulus pressures while the piston stays closed. The gas lift valve is then actuated for operation by increasing the tubing or annulus pressure beyond a predetermined limit of the first connection to release the piston to move open relative to the outlet. The movement of the piston (210) releases the hold of the second connection (240) on the check valve so the check valve can function normally as a one-way valve.
E21B 43/12 - Procédés ou appareils pour commander l'écoulement du fluide extrait vers ou dans les puits
E21B 34/10 - Aménagements des vannes pour les trous de forage ou pour les puits dans les puits actionnés par un fluide de commande provenant de l'extérieur du trou de forage
E21B 34/14 - Aménagements des vannes pour les trous de forage ou pour les puits dans les puits actionnés par le mouvement des outils, p.ex. obturateurs à manchons actionnés par des pistons ou par des outils à câble
69.
CABLE TO REDUCE OPTICAL FIBER MOVEMENT AND METHODS TO FABRICATE
Certain aspects of the present disclosure provide techniques for making armored cables. An example method for making an armored cable includes forming a strip stock into an armor tubing; welding a seam of the armor tubing in a welding zone; inserting at least one of a first optical fiber or a first wire into a first end of a first guide tube, wherein: the first guide tube extends through the welding zone; the first guide tube protects the at least one of the first optical fiber or the first wire during the welding of the seam; and the first guide tube is not part of the armored cable after the making of the armored cable; and supporting the first guide tube within the armor tubing by a plurality of support legs such that the first guide tube does not contact the armor tubing.
A tong includes a gear ring powered by a motor assembly, the gear ring having a plurality of ramps formed on an inner surface thereof and a brake plate rotationally independent of the gear ring, the brake plate having a gripping assembly for interacting with the ramps to grip a tubular. Also included is a brake assembly for preventing rotation of the brake plate, the brake assembly including an adjustable brake band for applying friction to the brake plate and at least one brake pad made of braking material disposed on an outer surface thereof in the area of contact with the brake band for reducing friction between the brake plate and the brake band. In one embodiment, the braking material is bronze.
E21B 19/16 - Branchement ou débranchement des accouplements de tubes ou de joints
E21B 19/06 - Elévateurs, c. à d. dispositifs agrippant tiges ou tubes
E21B 19/08 - Appareils pour faire avancer les tiges ou les câbles; Appareils pour augmenter ou diminuer la pression sur l'outil de forage; Appareils pour compenser le poids des tiges
71.
STREAMLINED VALVE ASSEMBLY FOR DOWNHOLE PUMP OR RECIPROCATING PUMP SYSTEM
A downhole pump used for a reciprocating pump system includes a barrel coupling to a tubing string and having a standing valve and includes a plunger coupling to a rod string and having a traveling valve. One or both of the valves can include an assembly comprising a housing, an insert, a ball, and a seat. The insert allowing for flow therethrough defines a ball stop at one end has a ball passage at the other end. The insert positions in flow passage of the housing, and one of the ends engages a shoulder in the passage. The insert includes sidewalls and a conical body to reduce turbulence, flow velocity, gas breakout, ball chatter, and the like.
F04B 47/02 - Pompes ou installations de pompage spécialement adaptées pour élever un fluide à partir d'une grande profondeur, p.ex. pompes de puits les mécanismes d'entraînement étant placés au niveau du sol
F04B 47/12 - Pompes ou installations de pompage spécialement adaptées pour élever un fluide à partir d'une grande profondeur, p.ex. pompes de puits élevant le fluide à pomper jusqu'à la surface au moyen d'un piston libre
F16K 1/12 - Soupapes ou clapets, c. à d. dispositifs obturateurs dont l'élément de fermeture possède au moins une composante du mouvement d'ouverture ou de fermeture perpendiculaire à la surface d'obturation à corps de soupape profilé autour duquel le fluide s'écoule quand la soupape est ouverte
F16K 15/04 - Soupapes, clapets ou valves de retenue à corps de soupapes rigides guidés en forme de sphère
A downhole pump is used for a reciprocating pump system having a rod string disposed in a tubing string. A barrel of the pump is disposed, and a plunger of the pump coupled to the rod string is movably disposed in the barrel. The plunger has an external surface disposed at an annular gap relative to the barrel's internal surface. The external surface has circumferential grooves defined thereabout that hold wipers. An inner ring of the wipers composed of a swellable material is engaged in the one or more circumferential grooves, while an outer ring composed of a second material is disposed about the inner ring. The swellable material of the inner ring energizes the outer ring in slideable engagement with the internal surface of the barrel.
F04B 47/02 - Pompes ou installations de pompage spécialement adaptées pour élever un fluide à partir d'une grande profondeur, p.ex. pompes de puits les mécanismes d'entraînement étant placés au niveau du sol
F04B 53/02 - Garnissage de l'espace libre entre des cylindres et des pistons
73.
DETERMINATION OF ELEMENTAL CONCENTRATIONS FROM THE CAPTURE AND INELASTIC ENERGY SPECTRA
Methods and systems for determining the elemental composition of formation rock are disclosed. The systems include a pulsed-neutron geochemical logging tool that is conveyed in a borehole traversing the formation. The pulsed-neutron geochemical logging tool can collect inelastic and capture neutron spectra. The inelastic and capture spectra are processed to provide the elemental composition of formation rock after removing contributions due to elements in the borehole and in the pores of the formation.
G01V 5/10 - Prospection ou détection au moyen de radiations nucléaires, p.ex. de la radioactivité naturelle ou provoquée spécialement adaptée au carottage en utilisant des sources de radiation nucléaire primaire ou des rayons X en utilisant des sources de neutrons
A sealing device includes a tubular body having a bore; a collet seat having a plurality of collets; a frangible sealing element disposed in the collet seat and blocking fluid communication through the bore; and a releasable sleeve releasably attached to the tubular body and retaining the collet seat against the tubular body. In one embodiment, the plurality of the collets includes threads mated with threads on the tubular body. In another embodiment, the plurality of the collets is attached to the sleeve.
A downhole pump used for a reciprocating pump system includes a barrel coupling to a tubing string and having a standing valve and includes a plunger coupling to a rod string and having a traveling valve. One or both of the valves can include an assembly comprising a housing, an insert, a ball, and a seat. The insert allowing for flow therethrough defines a ball stop at one end has a ball passage at the other end. The insert positions in flow passage of the housing, and one of the ends engages a shoulder in the passage. The insert is secured in the flow passage with metallic material metallurgically affixed between at least a portion of the insert and the flow passage. For example, brazing material can be brazed at the end of the insert to metallurgically affix the insert in the passage. The ball is positioned in the insert, and the seat is positioned adjacent an end of the insert. The assembly is then incorporated into components of the pump.
E21B 34/06 - Aménagements des vannes pour les trous de forage ou pour les puits dans les puits
F04B 47/02 - Pompes ou installations de pompage spécialement adaptées pour élever un fluide à partir d'une grande profondeur, p.ex. pompes de puits les mécanismes d'entraînement étant placés au niveau du sol
A method of balancing a beam pumping unit can include securing counterweights to crank arms, thereby counterbalancing a torque applied at a crankshaft at a maximum torque factor position due to a polished rod load and any structural unbalance. A well system can include a beam pumping unit including a gear reducer having a crankshaft, crank arms connected to the crankshaft, a beam connected at one end to the crank arm and at an opposite end to a rod string polished rod, and counterweights secured to the crank arms, and in which a torque applied at the crankshaft at a maximum torque factor position due to weights of the crank arms, the counterweights and wrist pins equals a torque applied at the crankshaft at the maximum torque factor position due to a load applied to the beam via the polished rod and any structural unbalance.
F04B 47/02 - Pompes ou installations de pompage spécialement adaptées pour élever un fluide à partir d'une grande profondeur, p.ex. pompes de puits les mécanismes d'entraînement étant placés au niveau du sol
A surface unit reciprocates a rod string for a downhole pump in a slanted well. The unit has a beam with a bend and pivots at a pivot between the bend and the horsehead of the beam. A post of the unit supports the pivot and is oriented to support the beam's load along the post and reduce bending stress. A crank arm is rotated by a prime mover about a crank point and translates pitman arms to oscillate the beam on the pivot, which reciprocates the rod string at surface along the slanted axis. The unit can be set at various offset distances relative to the intersection of the well so the unit can be used at various inclinations of slanted axis. The horsehead defines a segment with a face to accommodate at least 70% engagement or greater with the rod load for both largest and smallest inclinations.
F04B 47/02 - Pompes ou installations de pompage spécialement adaptées pour élever un fluide à partir d'une grande profondeur, p.ex. pompes de puits les mécanismes d'entraînement étant placés au niveau du sol
A whipstock assembly includes an inner body having a bore and an inclined surface at an upper portion; and an outer body disposed around the inner body and releasably attached to the inner body, the outer body having an inclined surface and an upper portion closed to fluid communication.
A jarring device includes a housing, a mandrel received within the housing, and a pressure chamber defined between the housing and the mandrel and filled with a hydraulic fluid. A hydraulic lock piston is arranged about the mandrel and radially interposes the housing and the mandrel. The hydraulic lock piston includes a pressure piston having a first end exposed to the pressure chamber, a second end, and first and second fluid flowpaths defined in the pressure piston and extending axially between the first and second ends. When the mandrel moves in a first direction relative to the housing, the hydraulic fluid is metered through the first fluid flowpath and the second fluid flowpath is occluded. When the mandrel moves in a second direction relative to the housing and opposite the first direction, the hydraulic fluid is metered through the second fluid flowpath and the first fluid flowpath is occluded.
E21B 31/113 - Repêchage ou dégagement d'objets dans les trous de forage ou dans les puits en utilisant des moyens de percussion pour dégager les parties coincées, p.ex. des coulisses de battage fonctionnant hydrauliquement
A method and apparatus for removal of tools, tubulars, casing, or other components that become stuck in a well. An anchor includes a mandrel, a carrier disposed on the mandrel and movable relative to the mandrel between an extended position and a retracted position, and an insert configured to engage an internal surface of a tubular, the insert movably disposed in the carrier as the carrier moves between the extended position and the retracted position. A method for anchoring a tool in a wellbore includes deploying the tool into the wellbore through a tubular to a first position, the tool comprising an anchor having a carrier and an insert disposed in the carrier, extending the carrier towards the tubular, and moving the insert relative to the carrier while engaging the inserts with the tubular, thereby anchoring the tool in the wellbore.
E21B 23/01 - Appareils pour déplacer, mettre en place, verrouiller, libérer ou retirer, les outils, les packers ou autres éléments dans les trous de forage pour ancrer les outils ou similaires
E21B 31/20 - Outils de préhension, p.ex. pinces ou grappins saisissant intérieurement, p.ex. harpons
Methods and apparatus for tubular stabbing guides are presented. One example tubular stabbing guide includes a frame, a clamping assembly mounted to the frame, the clamping assembly including a plurality of guide members configured to receive a tubular and movable between an open position and a closed position, and a support plate configured to support a weight of the tubular, the support plate movable between an extended position and a retracted position.
To perform an aligned operation downhole, a tubular disposed downhole has an internal bore with a first inner circumference and has a target at a first radial orientation. A locator profile is defined about the internal bore at a first location, and an internal nipple is defined about the internal bore at a second location. The internal nipple has a second inner circumference less than the first of the internal bore. An orientation slot is defined longitudinally across the internal nipple and is disposed at a second radial orientation configured relative to the first radial orientation of the target. A tool is deployable into the internal bore. The tool has a locator to engage in the locator profile and has an orientation key to engage in the slot and align an operational component for the aligned operation with the target.
E21B 23/02 - Appareils pour déplacer, mettre en place, verrouiller, libérer ou retirer, les outils, les packers ou autres éléments dans les trous de forage pour verrouiller les outils ou autres éléments sur des supports ou dans des retraits entre sections adjacentes du tubage
83.
FIBER OPTIC CABLE FOR INHIBITING BREACHING FLUID FLOW
Fiber optic cables suitable for use in downhole applications, with one or more features for inhibiting flow of any fluid breaching an armor layer of the optical cable are provided. By preventing, or at least impeding, fluid flow along the cable length, any breaching fluid may be confined to a small region of the cable, which may significantly reduce the deleterious effects (e.g., hydrogen darkening) of an armor layer breach. One example optical cable (300) generally includes one or more optical fibers (308), an inner tube (302) surrounding the one or more optical fibers (308), an outer tube (304) surrounding the inner tube (302), and one or more polymer sealing features (310) disposed in an annulus between the outer tube (304) and the inner tube (302) and bonded to at least one of the inner tube (302) or the outer tube (304) to prevent fluid flow in the annulus along at least a portion of a length of the optical cable (300).
G02B 6/44 - Structures mécaniques pour assurer la résistance à la traction et la protection externe des fibres, p.ex. câbles de transmission optique
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
A packer (100) for sealing in a tubular includes a mandrel (110) on which a packing element (150) is disposed between booster pistons (170). Each piston defines a sealed chamber (175) with housed areas of the mandrel. A setting force compresses packing element (150) between the booster pistons (170), which shear free. Ratchet mechanisms (200) including ratchet sleeves (210) and body lock rings (220) disposed between the pistons (170) and the housed areas initially allow the pistons to move in a direction away from the packing element (150), which expands the respective sealed chamber. Thereafter, in response to a pressure differential across the respective sealed chamber (175), the ratchet mechanisms (200) each permit urging of the respective piston (170) toward the packing element (150) while preventing retraction of respective piston (70) in the opposite direction.
A coupling mechanism for coupling a first downhole tool to a second downhole tool includes a first portion, a second portion, and a locking device for locking the first portion to the second portion. The first portion includes a frame; a plug body movable relative to the frame; a guiding element coupled to the plug body; at least one of a hydraulic plug and an electric plug; and an actuator for moving the plug body relative to the frame. The second portion includes a receptacle body; a guide receptacle for receiving the guiding element; a respective receptacle for receiving at least one of the hydraulic plug; and the electric plug.
A well plug for use in a subterranean well can include a generally tubular mandrel, a seal element positioned on the mandrel, and a setting rod releasably secured relative to the mandrel by an annular shaped shear ring or a bonded sleeve. The setting rod is releasable for longitudinal displacement relative to the mandrel in response to a predetermined shear force applied to the shear ring or bonded sleeve. A method of setting a well plug in a subterranean well can include displacing a generally tubular mandrel with a setting rod relative to an outer housing of the well plug, outwardly extending a seal element of the well plug in response to the displacing, and shearing a releasable attachment securing the setting rod relative to the mandrel, the releasable attachment comprising an annular shaped shear ring, or a bond between a sleeve and a surface.
An inflatable packer assembly can include an inflatable seal element having an internal inflation chamber, a flow passage extending longitudinally through the inflatable packer assembly, a flow restrictor between sections of the flow passage, and a flow controller that selectively permits and prevents fluid communication between the inflation chamber and each of the flow passage sections. The flow controller changes from a deflate configuration to an inflate configuration in response to an increase in flow rate through the flow passage. A method can include connecting an inflatable packer assembly in a tubular string, so that a longitudinal flow passage of the tubular string extends through the inflatable packer assembly, and a flow restrictor restricts flow between sections of the flow passage, and inflating an inflatable seal element of the inflatable packer assembly while fluid flows between the flow passage sections via the flow restrictor.
A flow control apparatus includes a housing having a bore extending and a port formed through a wall of the housing; a port sleeve disposed in the housing and having a port in communication with the port of the housing; a first sleeve releasably attached to the housing, wherein the first sleeve is movable from a first position preventing axial movement of the port sleeve relative to the housing to a second position allowing axial movement of the port sleeve relative to the housing; and a second sleeve releasably attached to the port sleeve, wherein the second sleeve is movable from a first position blocking fluid communication through the port of housing and the port of the port sleeve to a second position allowing fluid communication through the ports.
E21B 34/14 - Aménagements des vannes pour les trous de forage ou pour les puits dans les puits actionnés par le mouvement des outils, p.ex. obturateurs à manchons actionnés par des pistons ou par des outils à câble
E21B 33/13 - Procédés ou dispositifs de cimentation, de bouchage des trous, des fissures ou analogues
E21B 34/10 - Aménagements des vannes pour les trous de forage ou pour les puits dans les puits actionnés par un fluide de commande provenant de l'extérieur du trou de forage
89.
EROSION RESISTANT SHUNT TUBE ASSEMBLY FOR WELLSCREEN
A wellscreen has a gravel pack assembly installed that can communicate slurry from a transport tube to a pack tube. A bypass has erosion resistant surfaces exposed to flow of the conveyed slurry and diverts portion of the conveyed slurry from the fluid bore of the transport tube to a tube opening, from which the pack tube extends. The bypass can be incorporated into the top ring for supporting the filter on the basepipes. A sheath of erosion resistance can be formed on or installed in a channel of the end ring to be covered by a cover.
A tubular handling apparatus includes a power tong; a backup tong; and a load transfer assembly connected between the power tong and the backup tong. The load transfer assembly includes a first link having a first load cell positioned to measure a first force exerted on the first link; and a second link having a second load cell positioned to measure a second force exerted on the second link. The tubular handling apparatus may also include a tong control assembly configured to select the first load cell for use in a tubular makeup operation and to select the second load cell for use in a tubular breakout operation.
G01L 5/00 - Appareils ou procédés pour la mesure des forces, du travail, de la puissance mécanique ou du couple, spécialement adaptés à des fins spécifiques
91.
LOAD BALANCED POWER SECTION OF PROGRESSING CAVITY DEVICE
A progressing cavity device operates as a motor to impart torque to a bit. A stator of the device defines an internal profile having uphole stages with a first dimension being less than a second dimension of downhole stage. A rotor has an external profile with a constant outer dimension along its length. Disposed in the stator, the rotor defines cavities with the stator and is rotatable with pumped fluid progressing in the cavities from the uphole to downhole to transfer torque to the drive toward the downhole end. Although the rotor is subjected at the downhole end to a reactive torque from the bit, the interference fit of the rotor's constant dimension with the stator's downhole stages is less than with the uphole stages, which can mitigate issues with heat buildup in the downhole stages. The device can also operates as a progressing cavity pump.
F04C 2/107 - Machines ou pompes à piston rotatif du type à engrènement extérieur, c. à d. avec un engagement des organes coopérants semblable à celui d'engrenages dentés du type à axe interne, l'organe externe ayant plus de dents ou de parties équivalentes de prise, p.ex. de rouleaux, que l'organe interne avec des dents hélicoïdales
E21B 4/02 - Moyens d'entraînement de type rotatif par fluide
F01C 1/107 - "Machines" ou machines motrices à piston rotatif d'un type à engrènement extérieur, c. à d. avec engrènement des organes coopérants semblable à celui d'engrenages dentés d'un type à axe interne dans lequel l'organe externe a plus de dents ou de parties équivalentes de prise, p.ex. de galets, que l'organe interne avec dents hélicoïdales
F04C 15/00 - "MACHINES" À LIQUIDES À DÉPLACEMENT POSITIF, À PISTON ROTATIF OU OSCILLANT; POMPES À DÉPLACEMENT POSITIF, À PISTON ROTATIF OU OSCILLANT - Parties constitutives, détails ou accessoires des "machines", des pompes ou installations de pompage non couverts par les groupes
92.
CHEMICAL INJECTION VALVE ENHANCED SEALING CAPABILITY
A chemical injection valve can include a valve stem reciprocably disposed relative to a primary seal, and a variable flow restrictor upstream of the primary seal relative to a direction of flow through the chemical injection valve. The variable flow restrictor restricts the flow when the valve stem is disengaged from the primary seal. A chemical injection system can include a chemical treatment pumped through a chemical injection valve and into an interior of a tubular string in a well, the chemical injection valve including a valve stem, a primary seal sealingly engaged with the valve stem in a closed position and disengaged from the valve stem in an open position, and a flow restrictor that restricts the flow of the chemical treatment downstream from the primary seal in the open position.
E21B 34/06 - Aménagements des vannes pour les trous de forage ou pour les puits dans les puits
E21B 34/10 - Aménagements des vannes pour les trous de forage ou pour les puits dans les puits actionnés par un fluide de commande provenant de l'extérieur du trou de forage
E21B 37/06 - Procédés ou appareils pour nettoyer les trous de forage ou les puits utilisant des moyens chimiques pour empêcher ou limiter le dépôt de paraffine ou de substances analogues
Methods and systems for controlling a set of tools for hydrocarbon recovery are presented. One example system generally includes a remote controller (206), a first tool (202a), and a first control device (204) mounted on the first tool. The remote controller is communicatively coupled to the first control device. The first control device is generally configured to receive a command to operate the first tool from the remote controller. Based on the command, the first control device generates one or more instructions executable by the first control device. The first control device executes the one or more instructions to operate the first tool.
E21B 44/00 - Systèmes de commande automatique spécialement adaptés aux opérations de forage, c. à d. systèmes à fonctionnement autonome ayant pour rôle d'exécuter ou de modifier une opération de forage sans l'intervention d'un opérateur humain, p.ex. systèmes de ; Systèmes spécialement adaptés à la surveillance de plusieurs variables ou conditions de forage
E21B 19/00 - Manipulation de tiges, tubages, tubes ou autre objets analogues à l'extérieur du trou de forage, p.ex. dans la tour de forage; Appareils pour faire avancer les tiges ou les câbles
E21B 19/16 - Branchement ou débranchement des accouplements de tubes ou de joints
A rotary steerable tool used for directional drilling include a housing, at least one external director, and at least one valve. The external director is hydraulically movable to an extended condition relative to the housing, and the valve selectively directs pressurized fluid from a first side of the valve to the external director on the valve's second side. A first seal of the valve is selectively orientable about an axis and has an inlet, which communicates with the pressurized fluid from the first side. A second seal of the valve disposed adjacent the first seal has an outlet, which communicates the pressurized fluid to the second side at least when aligned with the inlet. A bearing assembly of the valve is disposed at the axis between the seals and has male and female bearing surfaces, which are angled off the axis and are mated with one another.
An apparatus disposed on a drillstring for deviating a borehole advanced by a drill bit includes a housing, a director, and an actuator. The housing on the drillstring transfers rotation to the drill bit. The housing has a bore communicating fluid to the drill bit. The director is disposed on the housing to rotate therewith. The director includes a piston movable in a chamber, a pad pivotable about a pivot point between extended and retracted conditions relative to the housing, and a linkage arm pivotably connected between the piston and the pad. The actuator in fluid communication with the bore is operable at least between a first condition directing communicated fluid from the bore or other source to the chamber of the director and a second condition at least permitting the director to retract toward the retracted condition.
Methods and apparatus for releasing a lead mill of a BHA from a whipstock in a wellbore include slideably releasing the BHA from the whipstock without relative rotation and without destruction of a retractable bolt. A system includes: a bias mechanism; a retractable bolt at least partially disposed in the bottom hole assembly and biased to a retracted position by the bias mechanism; and a retraction actuator capable of selectably opposing the bias of the retractable bolt. A method includes: coupling a whipstock to a BHA with a retention system, including: a retractable bolt biased to retract into the BHA; and a retraction actuator configured to resist the bias of the retractable bolt; and after the whipstock and BHA have been disposed in a wellbore, activating the retraction actuator so that retraction of the retractable bolt ensues.
Equipment and methods for coupling a top drive to one or more tools to facilitate data and/or signal transfer therebetween include a receiver assembly connectable to a top drive; a tool adapter connectable to a tool string, wherein a coupling between the receiver assembly and the tool adapter transfers at least one of torque and load therebetween; and a stationary data uplink comprising at least one of: a data swivel coupled to the receiver assembly; a wireless module coupled to the tool adapter; and a wireless transceiver coupled to the tool adapter. Equipment and methods include coupling a receiver assembly to a tool adapter to transfer at least one of torque and load therebetween, the tool adapter being connected to the tool string; collecting data at one or more points proximal the tool string; and communicating the data to a stationary computer while rotating the tool adapter.
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 19/00 - Manipulation de tiges, tubages, tubes ou autre objets analogues à l'extérieur du trou de forage, p.ex. dans la tour de forage; Appareils pour faire avancer les tiges ou les câbles
98.
TOOL COUPLER WITH DATA AND SIGNAL TRANSFER METHODS FOR TOP DRIVE
Equipment and methods for coupling a top drive to one or more tools to facilitate data and/or signal transfer therebetween include a receiver assembly connectable to a top drive; a tool adapter connectable to a tool string, wherein a coupling between the receiver assembly and the tool adapter transfers at least one of torque and load therebetween; and a stationary data uplink comprising at least one of: a data swivel coupled to the receiver assembly; a wireless module coupled to the tool adapter; and a wireless transceiver coupled to the tool adapter. Equipment and methods include coupling a receiver assembly to a tool adapter to transfer at least one of torque and load therebetween, the tool adapter being connected to the tool string; collecting data at one or more points proximal the tool string; and communicating the data to a stationary computer while rotating the tool adapter.
E21B 47/12 - Moyens pour la transmission de signaux de mesure ou signaux de commande du puits vers la surface, ou de la surface vers le puits, p.ex. pour la diagraphie pendant le forage
A tool coupler includes a first component having a tubular body and a locking member and a second component. The second component includes a housing having an opening for receiving the tubular body; a locking ring having a latch; and an axial channel; a recess for receiving the locking member, wherein the latch is positioned in the channel to retain the locking member in the recess.
E21B 17/046 - Accouplements; Joints entre tige et trépan, ou entre tiges avec nervures, goupilles ou mâchoires et rainures complémentaires ou similaires, p.ex. accrochage à baïonnette
E21B 19/16 - Branchement ou débranchement des accouplements de tubes ou de joints
100.
BOTTOM HOLE ASSEMBLY FOR CONFIGURING BETWEEN ARTIFICIAL LIFT SYSTEMS
A wellbore completion is configured for multiple forms of artificial lift. A downhole assembly on production tubing defines a production port communicating a throughbore with the wellbore annulus. A bypass, such as a snorkel or riser tube, on the assembly also communicates the throughbore between the packer and the production port with the annulus. A packer on the assembly seals in the annulus downhole of the production port and bypass. The assembly can then be configured for any selected artificial lift. To do this, at least one isolation, such as a sleeve insert, a sliding sleeve, a check valve, or a rupture disk, selectively prevents/allows communication via one or both of the production port and the bypass as needed. Additionally, removable lift equipment, including jet pump, gas lift valve, plunger assembly, rod pump, piston pump, or standing valve, is selectively inserted into the assembly's throughbore as needed.
brevets
