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.
An assembly is used for chemical injection through a wellhead (10) to a capillary line (102) in a well. A capillary hanger (150) installs in the wellhead to support the capillary line (102). A no-return valve (160) of the capillary hanger prevents fluid communication uphole from the supported capillary line (102). An injection module (104) mounts above a gate valve (50) on the wellhead and includes a movable mandrel (120) disposed therein. Hydraulic pressure applied to a piston chamber (121) in the module extends the mandrel through the open gate valve (50) so that a distal end (134) of the mandrel (120) can open the no-return valve (160). At this point, chemical injection introduced into the module can communicate through a flow bore (122) of the extended mandrel, through the open non-return valve (160), and on through the supported capillary line (102) in the well.
An apparatus can include a choke with a flow restrictor member having at least two positions, a flow coefficient Cv of the choke with the flow restrictor member in one position being less than with the flow restrictor member in the other position, and an operational device that displaces the flow restrictor member at a variable actuation rate, the actuation rate with the flow restrictor member in one position being less than with the flow restrictor in the other position. A method can include displacing a flow restrictor member, thereby decreasing a flow coefficient Cv of a choke, and decreasing a rate of change of the flow coefficient Cv in response to decreasing the flow coefficient Cv. A drilling system can include a choke with a flow restrictor member, and a continuously variable transmission which causes an actuation rate to vary based on a position of the flow restrictor member.
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
A gravel pack system includes a liner assembly and a deployment assembly. The liner assembly includes a sand control screen. The deployment assembly facilitates rotation of the liner assembly and circulation through the liner assembly while running the liner assembly into a wellbore using a work string. The deployment assembly includes a crossover tool that is operated to facilitate gravel packing without manipulation of the work string. The deployment assembly also includes a setting tool for setting a packer and/or a sand barrier at the top of the liner assembly.
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 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
A wellbore isolation assembly includes an outer component and an inner component. The outer component is disposed at a first location in a wellbore. The inner component is disposed at a second location in the wellbore. The inner component is moved from the second location into engagement with the outer component at the first location to form a barrier within the wellbore. When deployed in the wellbore, the barrier inhibits passage of fluids. The wellbore isolation assembly is then retrieved from the wellbore.
E21B 21/10 - Aménagements des vannes dans les systèmes de circulation des fluides de forage
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 43/10 - Mise en place de tubages, filtres ou crépines dans les puits
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
An elevator can include an elevator body, a set of ears on the elevator body configured for cooperative engagement with a set of bails, and another set of ears configured for cooperative engagement with another set of bails. A method of operating an elevator can include connecting a set of bails to a set of ears on an elevator body, and connecting another set of bails to another set of ears on the elevator body, the sets of bails being different from each other. A well system can include a lifting apparatus, an elevator including an elevator body, and one of two sets of bails connected between the lifting apparatus and the elevator. One set of ears on the elevator body being configured to cooperatively engage one set of bails, and another set of ears on the elevator body being configured to cooperatively engage the other set of bails.
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.
G01F 1/76 - Dispositifs pour mesurer le débit massique d'un fluide ou d'un matériau solide fluent
G01F 5/00 - Mesure d'une fraction du débit volumétrique
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 15/00 - MESURE DES VOLUMES, DES DÉBITS VOLUMÉTRIQUES, DES DÉBITS MASSIQUES OU DU NIVEAU DES LIQUIDES; COMPTAGE VOLUMÉTRIQUE - Détails des appareils des groupes ou accessoires pour ces derniers, dans la mesure où de tels accessoires ou détails ne sont pas adaptés à ces types particuliers d'appareils, p.ex. pour l'indication à distance
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
10.
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
11.
APPARATUS AND METHODS FOR DEPLOYING A SENSOR IN A DOWNHOLE TOOL
A downhole assembly includes a tubular body having a bore and a downhole tool connected to the tubular body. The downhole assembly also includes a sensor assembly having a carrier and a sensor. A sensor adapter is used to couple the sensor assembly to the tubular body. The sensor adapter includes an adapter body disposed in the bore of the tubular body; an adapter shaft for connection with the carrier; and a plurality of channels formed between the adapter shaft and the adapter body.
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
13.
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 tubular gripping apparatus includes a housing having a bore and a plurality of gripping members movable between a gripping position and a release position. The apparatus may also include a shield having a tubular inner body movable relative to an outer body. The tubular inner body is movable between a retracted position, in which the tubular inner body is positioned above the plurality of gripping members, and an extended position, in which the inner body is at least partially positioned interiorly of the plurality of gripping members.
A flow measurement apparatus can include a main flow passage, a variable flow restrictor, a bypass flow passage having an inlet connected with the main flow passage upstream of the variable flow restrictor and an outlet connected with the main flow passage downstream of the variable flow restrictor, and a mass flowmeter connected in the bypass flow passage between the inlet and the outlet. A method can include connecting a flow measurement apparatus, so that a fluid flow in a well also flows through the flow measurement apparatus, and varying a restriction to the fluid flow through the variable flow restrictor in response to a change in a flow rate of the fluid flow.
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 21/10 - Aménagements des vannes dans les systèmes de circulation des fluides de forage
E21B 34/02 - Aménagements des vannes pour les trous de forage ou pour les puits dans les têtes de puits
G01F 1/40 - Mesure du débit volumétrique ou du débit massique d'un fluide ou d'un matériau solide fluent, dans laquelle le fluide passe à travers un compteur par un écoulement continu en utilisant des effets mécaniques en mesurant la pression ou la différence de pression la pression ou la différence de pression étant produite par une contraction de la veine fluide - Détails de structure des dispositifs de contraction de la veine fluide
G01F 1/84 - Débitmètres massiques du type Coriolis ou gyroscopique
F16K 3/02 - Robinets-vannes ou tiroirs, c. à d. dispositifs obturateurs dont l'élément de fermeture glisse le long d'un siège pour l'ouverture ou la fermeture à faces d'obturation planes; Garnitures d'étanchéité à cet effet
16.
CONTROL ATTACHMENT FOR A TONG ASSEMBLY POSITIONING SYSTEM
A tong positioning system (100) includes a positioning device configured to move a tong assembly (400). The positioning device includes a first actuator (330), a second actuator (500), and a control attachment (200) attachable to the positioning device (300). The control attachment includes a shutoff valve (208) fluidly coupled to a hydraulic supply, a control valve block (230), and a control device (210). The control valve block includes a hydraulic input fluidly coupled to the shutoff valve, a hydraulic output fluidly coupled to a hydraulic return, a first valve fluidly coupled to the first actuator, the first valve configured to actuate the first actuator, and a second valve fluidly coupled to the second actuator, the second valve configured to actuate the second actuator. The control device is configured to control the first valve and to control the second valve to actuate the first and second actuators to move the tong assembly.
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 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 47/13 - Moyens pour la transmission de signaux de mesure ou signaux de commande du puits vers la surface, ou de la surface vers le puits, p.ex. pour la diagraphie pendant le forage par énergie électromagnétique, p.ex. gammes de fréquence radio
E21B 47/12 - Moyens pour la transmission de signaux de mesure ou signaux de commande du puits vers la surface, ou de la surface vers le puits, p.ex. pour la diagraphie pendant le forage
E21B 47/26 - Stockage des données en fond de puits, p.ex. dans une mémoire ou sur un support d'enregistrement
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
E21B 43/12 - Procédés ou appareils pour commander l'écoulement du fluide extrait vers ou dans les puits
An apparatus can include a telescoping arm (42) having a guiding means (44) and a pivot (70) at opposite ends, the telescoping arm (42) being rotatable about the pivot (70) relative to a spider (28), and the pivot being secured to the spider (28). The apparatus can include an actuator (48) operative to rotate the telescoping arm (42) about the pivot (70), an upper end the actuator (48) is connected to the telescoping arm (42), and a lower end of the actuator (48) is positioned within an outer circumference of the spider (28).
E21B 17/10 - Protecteurs contre l'usure; Dispositifs de centrage
E21B 19/087 - 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 au moyen d'un balancier
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 47/06 - 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
E21B 47/26 - Stockage des données en fond de puits, p.ex. dans une mémoire ou sur un support d'enregistrement
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
E21B 37/00 - Procédés ou appareils pour nettoyer les trous de forage ou les puits
25.
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 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
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
27.
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
29.
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 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.
Methods and apparatus for hydrocarbon monitoring are provided. A method that may be performed by a flowmeter or monitoring system includes receiving downhole measurements of a flowing fluid from a flowmeter; determining a standard phase fraction of the flowing fluid based on the downhole measurements from the flowmeter; receiving surface measurements of the flowing fluid; determining a surface phase fraction of the flowing fluid based on the surface measurements; comparing the standard phase fraction to the surface phase fraction; based on the comparison being greater than a predetermined threshold, using the surface measurements as a reference to adjust a speed of sound (SoS) of a first phase until a target value is achieved; and receiving additional downhole measurements of the flowing fluid from the flowmeter, wherein the flowmeter is operating using the adjusted SoS of the first phase.
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
A stage cementing system (20) includes a stage cementing assembly (22) having a stage tool (24). The stage tool has an outer mandrel (62), an inner mandrel (64) coupled to and disposed inside of the outer mandrel, an annular chamber (66) between the outer mandrel and the inner mandrel, a first outer port (74) through the outer mandrel, and longitudinally spaced first (68) and second (70) inner ports through the inner mandrel. The stage cementing system further includes an inner string assembly (40) configured to be located inside the inner mandrel. The inner string assembly has a tubular body (104) including a central throughbore (106) and longitudinally spaced first (140) and second (156) side ports, a lower external seal element (120) below the first and second side ports, a middle external seal element (118) between the first and second side ports, and an upper external seal element (116) above the first and second side ports..
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 34/10 - 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 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.
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 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.
E21B 19/16 - Branchement ou débranchement des accouplements de tubes ou de joints
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
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 setting tool can include a hydraulic setting mechanism that actuates in response to a level of a pressure differential between a central flow passage and an exterior of the setting tool, and a check valve assembly that permits flow between sections of the central flow passage in one direction but prevents flow in an opposite direction. One of the sections is in fluid communication with an exterior of the setting tool. A method of setting a well tool can include deploying the well tool and a setting tool into a well, and applying a pressure differential across a check valve assembly of the setting tool, thereby setting the well tool. In the deploying step, the setting tool includes the check valve 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
A stop collar assembly includes a collar (116) having inner and outer surfaces. The inner surface includes a taper (150). The outer surface includes a slope (156). The stop collar assembly further includes a slip (118) having a bottom end and a taper (186) adjoining the bottom end. The slip taper is configured to contact the collar taper. When the collar taper (150) is in contact with the slip taper (186), a distance (SI) from a central radial axis of the collar to the start of the slope is less than a distance (SE1) from the central radial axis to the slip bottom end, and the distance (SE1) from the central radial axis to the slip bottom end is less than a distance (El) from the central radial axis to the end of the slope.
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
42.
SPIDERS CAPABLE OF HANDLING WELL COMPONENTS OF MULTIPLE SIZES
A spider for handling/gripping well components of various sizes can include multiple slip assemblies distributed circumferentially about a central axis, each slip assembly including a slip carrier radially displaceable relative to the central axis, a slip displaceable relative to the slip carrier, and a slip actuator operable to displace the slip relative to the slip carrier, the slip actuator being disposed at least partially internal to the slip carrier. Each slip assembly may include a slip carrier actuator that radially displaces the slip carrier. A table assembly may mount to a well rig with an upper surface of the table assembly being flush with a rig floor of the well rig. Another spider can include a pipe guide assembly with multiple guides and guide actuators. Each guide actuator rotates a respective one of the pipe guides about a respective guide axis that is parallel to the central axis.
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.
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
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
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.
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.
E21B 33/035 - Têtes de puits; Leur mise en place spécialement adaptées aux installations sous l'eau
G06F 15/18 - dans lesquels un programme est modifié en fonction de l'expérience acquise par le calculateur lui-même au cours d'un cycle complet; Machines capables de s'instruire (systèmes de commande adaptatifs G05B 13/00;intelligence artificielle G06N)
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 33/04 - Têtes de tubage; Suspension des tubages ou des colonnes de production dans les têtes de puits
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 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
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 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.
E21B 19/16 - Branchement ou débranchement des accouplements de tubes ou de joints
49.
APPARATUS AND METHOD OF MEASURING COMPONENT CONCENTRATIONS OF NONHOMOGENEOUS MIXTURES IN MULTIPHASE FLOWS USING NEAR-INFRARED FILTER PHOTOMETRY APPARATUS AND METHOD OF MEASURING COMPONENT CONCENTRATIONS OF NONHOMOGENEOUS MIXTURES IN MULTIPHASE FLOWS USING NEAR-INFRARED FILTER PHOTOMETRY
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 21/85 - Analyse des fluides ou solides granulés en mouvement
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
50.
AUTOMATIC COMPENSATION FOR SURGE AND SWAB DURING PIPE MOVEMENT IN MANAGED PRESSURE DRILLING OPERATION
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
51.
STINGER FOR COMMUNICATING FLUID LINE WITH DOWNHOLE TOOL
A stinger is stabbed into a bore opening of a downhole tool to communicate fluid from a fluid line to the downhole tool. The stinger body defines a bore that communicates with the bore opening of the tool when the stinger body is installed in the downhole tool. An external surface of the stinger body can seal and lock inside an inside surface of the tool's bore opening when the stinger body is installed therein. The stinger body has a flow passage connected to the fluid line. A stinger port in the external surface of the stinger body is in communication with the flow passage and positions in fluid communication with a tool port inside the tool's bore opening so fluid can be communicated to the downhole tool.
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 17/18 - Tubes comprenant plusieurs passages pour les fluides
52.
SYSTEM AND METHOD FOR ELECTRICAL CONTROL OF DOWNHOLE WELL TOOLS
A system for use with a subterranean well can include a system controller with a computer, a power supply and at least one current sensor, multiple downhole well tools, each of the downhole well tools including a motor and a member displaceable by the motor; and an umbilical connected between the system controller and the downhole well tools, at least one conductor of the umbilical being connected to the motor of each of the downhole well tools. A downhole well tool example can include an actuator assembly configured to displace a member of the downhole well tool, the actuator assembly including a motor, a load yoke displaceable by the motor, and an elongated position indicator bar having at least one profile formed thereon. Friction between the load yoke and the position indicator bar varies as the load yoke displaces relative to the position indicator bar.
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 34/06 - Aménagements des vannes pour les trous de forage ou pour les puits dans les puits
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.
An integrated hydraulic fracture design model that utilizes elastic fluids with high proppant suspension and low required power for injection into a hydrocarbon-bearing, subterranean formation. The integrated physics-based approach utilizes a hybrid friction model to compute viscous and elastic behavior to estimate pressure losses at different pumping conditions coupled with a novel geomechanical model capable of modeling proppant transport with elastic fluids in planar hydraulic fractures and natural fractures. An integrated process to optimize hydraulic fracture design evaluates and quantifies the proppant-carrying capacity of elastic fluids and its impact on the proppant transport process, and low water requirements.
A well tool can include a downhole anchor with at least one outwardly extendable slip including longitudinally spaced apart grip structures, and a longitudinally extending beam which connects the grip structures to each other. The beam has a radial thickness which is greater than a lateral width of the beam. A slip retainer retains the slip, and a spring inwardly biases the slip relative to the slip retainer. The spring surrounds the slip and the slip retainer. An area moment of inertia of the beam with respect to a lateral axis through a centroid of the beam is greater than an area moment of inertia of the beam with respect to a radial axis through the centroid of the beam.
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.
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
58.
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
60.
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
A well tool assembly (40) can include a well screen (24) configured to filter fluid flow between an interior and an exterior of a tubular string, and an outflow control section (36) that permits the fluid flow in an outward direction and prevents the fluid flow in an inward direction, the outflow control section including at least two outflow control valves (62, 64) arranged in series. A method can include installing a well tool assembly including a well screen, flowing a fluid from an exterior to an interior of a tubular string through the well screen (24) and an inflow control valve (60) of the well tool assembly, and flowing another fluid from the interior to the exterior of the tubular string through the well screen and at least one outflow control valve (62, 64) of the well tool assembly.
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 43/12 - Procédés ou appareils pour commander l'écoulement du fluide extrait vers ou dans les puits
62.
PREVENTION OF GAS MIGRATION THROUGH DOWNHOLE CONTROL LINES
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
e.ge.ge.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 surface unit can operate as a longer stroke unit to reciprocate a rod string for a downhole pump in a well. The unit has an end weight that gives the walking beam and head a zero-imbalance about the unit's fulcrum point. The unit can also operate as a phased unit in which the counterweights of the crank arms lag behind the pivot connection and/or the crank point is disposed rearward of the equalizer bearing of the walking beam.
E21B 43/12 - Procédés ou appareils pour commander l'écoulement du fluide extrait vers ou dans les puits
E21B 43/30 - Disposition particulière des puits, p.ex. disposition rendant optimum l'espacement des 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
67.
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 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 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
68.
APPARATUS FOR CONNECTING DRILLING COMPONENTS BETWEEN RIG AND RISER
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 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 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
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 well barrier can include an annular seal element, an anti-extrusion backup having radially inward and radially outward portions, and a biasing device that exerts a biasing force against the radially outward portion of the anti- extrusion backup. A method of operating a well barrier can include setting the well barrier by decreasing a longitudinal distance between abutments of the well barrier, thereby compressing a seal element between the abutments, and unsetting the well barrier by increasing the longitudinal distance between the abutments and radially inwardly retracting an anti-extrusion backup positioned longitudinally between the seal element and one of the abutments. Another well barrier can include an annular seal element, an anti-extrusion backup, an abutment displaceable relative to the seal element to compress the seal element, a sleeve reciprocable relative to the abutment, and a biasing device that biases the sleeve toward the anti-extrusion backup.
A well tool can include an annular seal and a radial expansion mechanism having radially retracted and radially expanded configurations, the annular seal being longitudinally displaceable relative to the radial expansion mechanism in the radially retracted configuration. A method of setting a well tool can include positioning the well tool in a well, the well tool including an annular seal and a radial expansion mechanism, and then longitudinally displacing the annular seal to a radially outward position relative to the radial expansion mechanism. A well system can include a well tool including an annular seal, a radial expansion mechanism, an inner mandrel assembly and a setting sleeve, and a setting tool that produces a relative longitudinal displacement between the setting sleeve and the inner mandrel assembly, the annular seal radially outwardly overlying the radial expansion mechanism in response to the relative longitudinal displacement.
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.
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 downhole apparatus for use in a tubular can include: a mandrel having a first end shoulder; a first slip disposed on the mandrel adjacent the first end shoulder and abutting against a mule shoe; a cone disposed on the mandrel adjacent the first slip and movable relative to the first end shoulder to engage the first slip toward the tubular; a seal element disposed on the mandrel adjacent the cone and being expandable outward from the mandrel; and wherein at least one component selected from the group consisting of the mandrel, the first slip, the cone, the seal element, and the mule shoe is a filler-doped degradable component that comprise a degradable material and a filler.
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
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 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.
Systems and methods for predicting and optimizing the effects of acidizing treatment of carbonate rock are disclosed. The disclosed methods predict the conflicting effects of increased production (i.e., wormhole creation) and reduced rock compressive strength due to acid rock reactions. The mechanical stability of stimulated wellbores, such as horizontal wellbores, can be determined under different acidizing conditions, such as acid type and volume. The acidizing conditions can be optimized to maximize short and long-term production.
E21B 43/16 - Procédés de récupération assistée pour l'extraction d'hydrocarbures
E21B 43/26 - Procédés pour activer la production par formation de crevasses ou de fractures
E21B 43/28 - Dissolution de matières minérales autres que des hydrocarbures, p.ex. par un agent de lessivage alcalin ou acide
C09K 8/58 - Compositions pour les méthodes de récupération assistée pour l'extraction d'hydrocarbures, c. à d. pour améliorer la mobilité de l'huile, p.ex. fluides de déplacement
C09K 8/62 - Compositions pour la formation de crevasses ou de fractures
A method of making a connection between a first tubular and a second tubular includes gripping the first tubular using a power tong; gripping the second tubular using a backup tong; applying a torque to the first tubular using a power tong; and moving the power tong at a predetermined speed to compensate for a weight of the power tong.
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 system for tong assembly operation includes a mode switch for shifting the tong assembly between a first mode of operation and a second mode of operation, the mode switch having a first portion associated with the first mode and a second portion associated with the second mode; a first target coupled to the first portion, the first target movable to a first position corresponding to the first mode of operation; a second target coupled to the second portion, the second target movable to a second position corresponding to the second mode of operation; a first sensor configured to identify the first position of the first target; and a second sensor configured to identify the second position of the second target.
A method of connecting or disconnecting a first tubular to a second tubular includes engaging the first tubular with a power tong; engaging the second tubular with a backup tong; and rotating the first tubular relative to the second tubular. The method also includes, while rotating, monitoring a distance between the backup tong and the power tong and comparing the distance to a first threshold value; and stopping rotation of the first tubular when the distance equals to the first threshold value. According to one embodiment, a tong assembly includes a power tong, a backup tong, a sensor configured to measure a distance between the power tong and the backup tong, and a controller configured to compare the distance to a threshold value.
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
83.
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
85.
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 downhole apparatus (10) comprises a landing arrangement (12) comprising a collet (18) and an actuation arrangement (14) comprising an actuation piston (22). The actuation arrangement (14) is operable to reconfigure the downhole apparatus (10) from the first configuration to a second configuration in which the landing arrangement (12) defines a radially retracted position, permitting the apparatus (10) to be run through a seat (S).
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
87.
TECHNIQUES FOR DETERMINING FORMATION COMPOSITION FROM MEASURED NUCLEAR 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 wellhead (10) with a casing head (20) has tubing (15) in its therethrough. A mating component, such as a pack-off (40), installs in the wellhead on the end of the tubing above a casing hanger (30). The bore (42) of the pack-off defines circumferential grooves-each having a canted spring (100A, 100B) disposed therein. The canted springs engaged between the groove and the tubing and restricting relative rotation between the pack-off and the tubing.
A sleeve can be used as a stop collar on tubing. A fusible element disposed about the inside or outside surface of the collar can be accessed by electrodes via the at least one access point in the collar. An insulator insulates the fusible element from the collar, while the electrodes apply electric current to the fusible element. A fusible material of the fusible element is heated to melting in response to the applied electric current and affixes the collar to the tubing with a metallurgical bond formed from the melting and re-solidifying of the fusible material inside a space between the first circumferential surface of the collar and the opposing circumferential surface of the tubing. The fusible material can be heated to melting directly with the electric current, or an ignitable material activated with the electric current can melt the fusible material.
A whipstock is manufactured for a downhole assembly. A preform of the whipstock defines a face in an outer surface angling from a distal end of the preform toward a proximal end of the preform. A tubing blank disposed on the preform is formed about the outer surface of the preform using differential pressure, and the formed tubing blank is incorporated as at least part of the whipstock of the downhole assembly, which can include at least one of an anchor and a packer. The formed tubing blank can constitute the entire length of the whipstock, or may constitute a section thereof to be connected to other sections. The integrity of the formed tubing blank can be strengthened using hard banding, cold working, filling a hollow of the formed blank, or preconfiguring longitudinal ridges on the formed blank.
A method is disclosed of manufacturing a side pocket mandrel (70) for use with a gas lift valve downhole on a tubing string. A plurality of separate components (72a-b, 74a-b, 76) of the mandrel are manufactured. A face (73a-b) on at least one end of each of the separate components is configured for solid-state joining with a face on another of the separate components. Joints (100) are then formed between the separate components by moving the face of at least one of the separate components in a solid state joining process relative to the face of at least one other of the separate components. For example, linear friction, rotary friction, or spin friction welding can be used by moving one of the faces against another. Also, an induction heater can preheat the ends to a suitable temperature to reduce the need for friction heating.
E21B 43/12 - Procédés ou appareils pour commander l'écoulement du fluide extrait vers ou dans les puits
B23K 20/12 - Soudage non électrique par percussion ou par une autre forme de pression, avec ou sans chauffage, p.ex. revêtement ou placage la chaleur étant produite par friction; Soudage par friction
B23K 20/233 - Soudage non électrique par percussion ou par une autre forme de pression, avec ou sans chauffage, p.ex. revêtement ou placage tenant compte des propriétés des matériaux à souder sans couche ferreuse
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
95.
WEAR BUSHING INSTALLATION AND RETRIEVAL IN DRILLING OPERATIONS
A wear busing running tool can include an actuator with a mandrel and an interior flow passage, an engagement sub including engagement devices inwardly and outwardly displaceable in response to displacement of the mandrel by the actuator, and a jetting sub including nozzles that direct fluid from the interior flow passage to an exterior of the running tool, and a valve that controls fluid flow through the nozzles in response to displacement of the mandrel by the actuator. A method of running a wear bushing can include engaging the wear bushing with a running tool, including engaging a shear member with the wear bushing, deploying the wear bushing and the running tool into the well, thereby positioning the wear bushing in a wellhead, and applying set down weight to the running tool, thereby shearing the shear member and permitting the running tool to displace relative to the wear bushing.
E21B 17/12 - Dispositifs pour placer ou retirer les manchons protecteurs
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
96.
WEAR BUSHING DEPLOYMENT AND RETRIEVAL TOOL FOR SUBSEA WELLHEAD
An apparatus deploys and retrieves a wear bushing in a wellhead during the same trip, such as when using a bottom hole assembly for drilling. Arms in the form of pistons, levers, dogs, etc. can be moved between retracted and extended conditions on the apparatus using actuations from remote communications. When extended, the arms engage inside the wear bushing or inside an adapter disposed in the bushing. When retracted, the arms lie within the exterior of the tool to avoid wear and damage when the drillstring is used for drilling or other operations. During deployment, the bushing supported on the extended arms is seated in the wellhead. The arms are then retracted through remote activation, and the bottom hole assembly is run further downhole. During retrieval, the retracted arms are extended through remote activation and engage in the bushing so the drillstring can lift the bushing from the wellhead.
E21B 17/12 - Dispositifs pour placer ou retirer les manchons protecteurs
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
97.
DIFFERENTIAL FLOW MEASUREMENT WITH CORIOLIS FLOWMETER
In a drilling system for drilling a borehole with drilling fluid, a flow loop communicates the drilling fluid, and a differential pressure device in the flow loop at a measurement location produces a pressure drop in flow. The measurement location can be between the borehole and a drilling choke or between a mud pump and the borehole. Piping diverts a portion of the flow at the measurement location so a flowmeter can measure the diverted flow portion. A processing unit receives a measured parameter from the flowmeter and determines a diverted flow rate of the diverted portion therefrom to correlate it to a value of the main flow rate through the flow loop at the measurement location.
G01F 1/34 - Mesure du débit volumétrique ou du débit massique d'un fluide ou d'un matériau solide fluent, dans laquelle le fluide passe à travers un compteur par un écoulement continu en utilisant des effets mécaniques en mesurant la pression ou la différence de pression
G01F 1/40 - Mesure du débit volumétrique ou du débit massique d'un fluide ou d'un matériau solide fluent, dans laquelle le fluide passe à travers un compteur par un écoulement continu en utilisant des effets mécaniques en mesurant la pression ou la différence de pression la pression ou la différence de pression étant produite par une contraction de la veine fluide - Détails de structure des dispositifs de contraction de la veine fluide
G01F 1/80 - Débitmètres massiques directs fonctionnant en mesurant la pression, la force, le couple ou la fréquence d'un écoulement de fluide auquel a été donné un mouvement de rotation
G01F 5/00 - Mesure d'une fraction du débit volumétrique
G01F 1/74 - Dispositifs pour la mesure du débit d'un matériau fluide ou du débit d'un matériau solide fluent en suspension dans un autre fluide
98.
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).
A fracturing operation stimulate a region of a well by alternating between pumping liquid intervals and injecting gas intervals to the region. A given liquid interval can include slick water with or without proppant. The gas interval can include produced gas, and a given interval can be injected at pressures above or below fracture initiation pressures. In a depleted region, the stimulation can energize an existing fracture and can carry the proppant into the energized fracture. In an under-developed region, the stimulation can create a new fracture and can carry proppant into the new fracture. The liquid delivers the proppant, and turbulence from the injected gas at the fracture can help further carry the proppant therein. A diverter then temporarily seals the energized or new fracture so the injected gas temporarily sealed therein can interface with residual formation fluid therein, providing for enhanced oil recovery.
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.
brevets
