An elevator for use with a subterranean well can include an elevator housing, a slip assembly axially displaceable relative to the elevator housing, the slip assembly including multiple slips configured to grip an outer surface of a tubular disposed in the slip assembly, the slip assembly having open and closed configurations, and a load indicator configured to prevent actuation of the slip assembly from the closed configuration to the open configuration when at least a predetermined load is supported by the elevator housing. A method of handling tubulars can include supporting a tubular with an elevator, thereby applying at least a predetermined load to the elevator, and a load indicator of the elevator preventing a slip assembly of the elevator from being actuated to an open configuration while at least the predetermined load is applied to the elevator.
An elevator (14) for use with a subterranean well can include an elevator housing (34), a slip assembly (38) axially displaceable relative to the elevator housing, the slip assembly including multiple slips (40) configured to grip an outer surface of a tubular (32) disposed in the slip assembly, the slip assembly having open and closed configurations, and a load indicator (64) configured to prevent actuation of the slip assembly from the closed configuration to the open configuration when at least a predetermined load is supported by the elevator housing. A method of handling tubulars can include supporting a tubular with an elevator, thereby applying at least a predetermined load to the elevator, and a load indicator of the elevator preventing a slip assembly of the elevator from being actuated to an open configuration while at least the predetermined load is applied to the elevator.
A system monitors a completion, which has components disposed at depths in a wellbore. Operational events associated with the components are stored in memory. The system interrogates an optical fiber disposed along the assembly in acoustic communication with the components by injecting input optical signals into the fiber using an optical source. An optical detector detects return optical signals backscattered along the fiber, and a processing unit processes the return optical signals according to a plurality of spatial resolutions for the components along the fiber. Signatures for each of the components are determined at the spatial resolutions along the fiber, and baselines of the signatures over a time span are generated for each of the components. A deviation from the baseline is detected for one of the components, and the detected deviation is correlated to an associated one of the operational events for the component.
E21B 47/135 - Moyens pour la transmission de signaux de mesure ou signaux de commande du puits vers la surface, ou de la surface vers le puits, p. ex. pour la diagraphie pendant le forage par énergie électromagnétique, p. ex. gammes de fréquence radio utilisant des ondes lumineuses, p. ex. ondes infrarouges ou ultraviolettes
E21B 47/008 - Surveillance des systèmes de pompe de fond de trou, p. ex. pour la détection de conditions appelées "cognement sur le fluide"
E21B 47/09 - Localisation ou détermination de la position d'objets dans les trous de forage ou dans les puitsIdentification des parties libres ou bloquées des tubes
4.
MONITORING DOWNHOLE COMPONENTS OF COMPLETION ASSEMBLY USING DISTRIBUTED ACOUSTIC SENSING
A system monitors a completion, which has components (26a, 26b) disposed at depths in a wellbore. Operational events associated with the components are stored in memory (86). The system interrogates an optical fiber (50) disposed along the assembly in acoustic communication with the components by injecting input optical signals into the fiber using an optical source (72). An optical detector (74) detects return optical signals backscattered along the fiber, and a processing unit (82) processes the return optical signals according to a plurality of spatial resolutions for the components along the fiber. Signatures for each of the components are determined at the spatial resolutions along the fiber, and baselines of the signatures over a time span are generated for each of the components. A deviation from the baseline is detected for one of the components, and the detected deviation is correlated to an associated one of the operational events for the component.
E21B 47/113 - Localisation des fuites, intrusions ou mouvements du fluide utilisant des signaux électriquesLocalisation des fuites, intrusions ou mouvements du fluide utilisant un rayonnement lumineux
A liner hanger can include slips configured to anchor the liner hanger in a well, a tubular mandrel, a tubular outer housing outwardly surrounding the mandrel, an engagement member that releasably secures the slips against longitudinal displacement relative to the mandrel, and another engagement member that releasably secures the outer housing against longitudinal displacement relative to the mandrel. A method of setting a liner hanger in a subterranean well can include: applying a differential pressure from an interior to an exterior of the liner hanger, thereby displacing a retainer sleeve relative to a mandrel of the liner hanger, and applying another differential pressure from the interior to the exterior of the liner hanger, thereby displacing an outer housing of the liner hanger relative to the mandrel. The outer housing is prevented from displacing relative to the mandrel until after the retainer sleeve is displaced relative to the mandrel.
A liner hanger can include slips configured to anchor the liner hanger in a well, a tubular mandrel, a tubular outer housing outwardly surrounding the mandrel, an engagement member that releasably secures the slips against longitudinal displacement relative to the mandrel, and another engagement member that releasably secures the outer housing against longitudinal displacement relative to the mandrel. A method of setting a liner hanger in a subterranean well can include: applying a differential pressure from an interior to an exterior of the liner hanger, thereby displacing a retainer sleeve relative to a mandrel of the liner hanger, and applying another differential pressure from the interior to the exterior of the liner hanger, thereby displacing an outer housing of the liner hanger relative to the mandrel. The outer housing is prevented from displacing relative to the mandrel until after the retainer sleeve is displaced relative to the mandrel.
E21B 43/10 - Mise en place de tubages, filtres ou crépines dans les puits
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
A liner hanger (18) can include slips (26), a mandrel (52), an outer housing (58) rigidly secured to the mandrel, a collet sleeve (78) connected to the slips, and an annular piston (68) in an annulus (60) between the mandrel and the outer housing, the piston supporting the collets and thereby preventing displacement of the slips relative to the mandrel. Another liner hanger can include collets supported by an outer housing, and an annular piston supporting an engagement member and thereby preventing displacement of the slips relative to the mandrel. Another liner hanger can include a piston releasably secured to a mandrel, a collet sleeve secured against longitudinal displacement relative to the mandrel, and the piston including a support surface supporting an engagement member and thereby preventing displacement of slips relative to the mandrel.
A method for cementing a casing string allows for a deactivation fluid to be injected into a toe of a wellbore in sufficient quantities without displacing cement accumulated in an annulus around the casing string. The method includes landing a first isolation device within a flow path to isolate a shoe track from an annular isolation apparatus and a communication tool. A seal member of the annular isolation apparatus is radially extended around the casing string to fluidly isolate an annulus above the seal member from a toe of the wellbore. A cement slurry is pumped through at least one radial port into the annulus above the seal member without passing through the shoe track. The deactivation fluid is pumped through a bypass mechanism of the first isolation device and into the shoe track while the toe of the wellbore is fluidly isolated from the annulus above the seal member.
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
Examples are disclosed herein for sensing one or more fluid parameters of a flowing fluid. A flowmeter can include high and low sensitivity coils. The low sensitivity coils can include optical coils for sensing one or more fluid flow parameters of flowing fluid. The high sensitivity coils can include optical coils for sensing the one or more fluid flow parameters of the flowing fluid. The low sensitivity coils can be selected so that an instrument receives data from the low sensitivity coils indicative of the one or more fluid flow parameters over a first period of time. The high sensitivity coils can be selected so that the instrument receives data from the high sensitivity coils indicative of the one or more fluid flow parameters over a second period of time.
G01F 1/661 - Mesure du débit volumétrique ou du débit massique d'un fluide ou d'un matériau solide fluent, dans laquelle le fluide passe à travers un compteur par un écoulement continu en mesurant la fréquence, le déphasage, le temps de propagation d'ondes électromagnétiques ou d'autres types d'ondes, p. ex. en utilisant des débitmètres à ultrasons en utilisant la lumière
F17D 3/18 - Dispositions pour la surveillance ou la commande des opérations de fonctionnement pour mesurer la quantité de produit transféré
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
A pressure-operated valve assembly includes an outer mandrel defining a tubing string bore, an inner mandrel arranged within the tubing string bore, a first atmospheric chamber at least partially defined by the outer mandrel, and a second atmospheric chamber at least partially defined between the outer and inner mandrels. A valve chamber is defined in the inner mandrel and in fluid communication with the tubing string bore via a valve port and with a wellbore annulus via an annulus port. An atmospheric chamber port is provided in the valve chamber and in fluid communication with the second atmospheric chamber. A hydrostatically insensitive valve is arranged within the valve chamber and includes a piston providing a head exposed to both annulus and tubing string bore pressure, and movable to expose the atmospheric chamber port to flood the second atmospheric chamber and simultaneously cause the first atmospheric chamber to collapse.
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 liner hanger can include slips, a mandrel, an outer housing rigidly secured to the mandrel, a collet sleeve connected to the slips, and an annular piston in an annulus between the mandrel and the outer housing, the piston supporting the collets and thereby preventing displacement of the slips relative to the mandrel. Another liner hanger can include collets supported by an outer housing, and an annular piston supporting an engagement member and thereby preventing displacement of the slips relative to the mandrel. Another liner hanger can include a piston releasably secured to a mandrel, a collet sleeve secured against longitudinal displacement relative to the mandrel, and the piston including a support surface supporting an engagement member and thereby preventing displacement of slips relative to the mandrel.
Examples are disclosed herein for sensing one or more fluid parameters of a flowing fluid. A flowmeter can include high and low sensitivity coils. The low sensitivity coils can include optical coils for sensing one or more fluid flow parameters of flowing fluid. The high sensitivity coils can include optical coils for sensing the one or more fluid flow parameters of the flowing fluid. The low sensitivity coils can be selected so that an instrument receives data from the low sensitivity coils indicative of the one or more fluid flow parameters over a first period of time. The high sensitivity coils can be selected so that the instrument receives data from the high sensitivity coils indicative of the one or more fluid flow parameters over a second period of time.
G01F 1/661 - Mesure du débit volumétrique ou du débit massique d'un fluide ou d'un matériau solide fluent, dans laquelle le fluide passe à travers un compteur par un écoulement continu en mesurant la fréquence, le déphasage, le temps de propagation d'ondes électromagnétiques ou d'autres types d'ondes, p. ex. en utilisant des débitmètres à ultrasons en utilisant la lumière
G01F 1/66 - Mesure du débit volumétrique ou du débit massique d'un fluide ou d'un matériau solide fluent, dans laquelle le fluide passe à travers un compteur par un écoulement continu en mesurant la fréquence, le déphasage, le temps de propagation d'ondes électromagnétiques ou d'autres types d'ondes, p. ex. en utilisant des débitmètres à ultrasons
A pressure-operated valve assembly includes an outer mandrel defining a tubing string bore, an inner mandrel arranged within the tubing string bore, a first atmospheric chamber at least partially defined by the outer mandrel, and a second atmospheric chamber at least partially defined between the outer and inner mandrels. A valve chamber is defined in the inner mandrel and in fluid communication with the tubing string bore via a valve port and with a wellbore annulus via an annulus port. An atmospheric chamber port is provided in the valve chamber and in fluid communication with the second atmospheric chamber. A hydrostatically insensitive valve is arranged within the valve chamber and includes a piston providing a head exposed to both annulus and tubing string bore pressure, and movable to expose the atmospheric chamber port to flood the second atmospheric chamber and simultaneously cause the first atmospheric chamber to collapse.
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
14.
HYDRO-MECHANICAL SOUNDING DEVICE FOR USE WITH ACOUSTIC TELEMETRY SYSTEM
An acoustic telemetry system used with a wellbore assembly in a wellbore includes a hydro-mechanical sounding devices, relays, and a receiver. The sounding device includes a housing defining a chamber with an inlet port and at least one outlet port. A piston disposed in the chamber is movable against a strike face in the chamber in response to a hydraulic pressure differential. The impact of the piston against the strike face can produce an acoustic vibration, which can have defined characteristics. One or more relays disposed on the tubing electronically generate an acoustic signal in response to the acoustic vibration produced by the device. The acoustic signal can then be telemetered to a receiver at surface to determine a positive indication of an operation downhole.
E21B 47/18 - Moyens pour la transmission de signaux de mesure ou signaux de commande du puits vers la surface, ou de la surface vers le puits, p. ex. pour la diagraphie pendant le forage utilisant des ondes acoustiques à travers le fluide du puits
15.
HYDRO-MECHANICAL SOUNDING DEVICE FOR USE WITH ACOUSTIC TELEMETRY SYSTEM
An acoustic telemetry system used with a wellbore assembly in a wellbore includes a hydro-mechanical sounding devices, relays, and a receiver. The sounding device includes a housing defining a chamber with an inlet port and at least one outlet port. A piston disposed in the chamber is movable against a strike face in the chamber in response to a hydraulic pressure differential. The impact of the piston against the strike face can produce an acoustic vibration, which can have defined characteristics. One or more relays disposed on the tubing electronically generate an acoustic signal in response to the acoustic vibration produced by the device. The acoustic signal can then be telemetered to a receiver at surface to determine a positive indication of an operation downhole.
E21B 47/18 - Moyens pour la transmission de signaux de mesure ou signaux de commande du puits vers la surface, ou de la surface vers le puits, p. ex. pour la diagraphie pendant le forage utilisant des ondes acoustiques à travers le fluide du puits
An isolation valve has a valve body, which is mountable on or integrally formed with a tubular and which defines a valve pocket. A first flow path portion extends within the valve body between a tube inlet (connectable to an inlet tube) and a valve inlet port (in communication with the valve pocket). A second flow path portion extends within the valve body between a valve outlet port (in communication with the valve pocket) and a tube outlet (connectable to an outlet tube). A valve rod is disposed within the valve pocket of the valve body. The valve rod is moveable within the valve pocket between an open position (in which the valve inlet port and valve outlet port are in communication with each other) and a closed position (in which the valve inlet port and the valve outlet port are isolated from each other).
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
F16K 3/26 - 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 en forme de surfaces de solides de révolution avec corps de tiroir cylindrique le passage du fluide se faisant par le corps du tiroir
17.
GUIDANCE AND EVENT PREDICTION FOR WELL DRILLING OPERATIONS
A method for use with a subterranean well drilling operation can include training a predictive model with historical well data to predict a probability of a historical wellbore event occurring, then inputting to the trained predictive model parameters of a target well to be drilled, and the predictive model predicting a probability of a wellbore event occurring in the target well. A system for use with a subterranean well drilling operation can include a predictive model trained to predict at least one historical wellbore event, based on historical well data. The predictive model can be configured to predict a probability of a wellbore event occurring in a target well. The predictive model can be configured to provide guidance for drilling the target well.
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 forage commandés par ordinateurSystèmes spécialement adaptés à la surveillance de plusieurs variables ou conditions de forage
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
G06N 3/00 - Agencements informatiques fondés sur des modèles biologiques
18.
Formation testing with controlled pressure drilling
A formation testing method can include deploying a drill string including a packer and a circulating tool into a well, setting the packer, thereby blocking fluid flow through an annulus, and opening the circulating tool, thereby permitting fluid communication between the annulus and an interior flow passage of the drill string. The opening step can include displacing a radio frequency identification tag into the circulating tool. A formation testing system can include a drill string with a drill bit, a circulating tool and a packer. The packer is configured to seal off an annulus, and the circulating tool is selectively operable to permit fluid communication between the annulus and an interior flow passage of the drill string in response to a radio frequency identification tag being deployed into the circulating tool.
E21B 49/10 - Prélèvement d'échantillons de fluides ou test des fluides dans les trous de forage ou dans les puits utilisant des appareils d'échantillonnage ou de test de fluide venant s'appliquer latéralement contre la paroi du 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
A method for use with a subterranean well drilling operation can include training a predictive model with historical well data to predict a probability of a historical wellbore event occurring, then inputting to the trained predictive model parameters of a target well to be drilled, and the predictive model predicting a probability of a wellbore event occurring in the target well. A system for use with a subterranean well drilling operation can include a predictive model trained to predict at least one historical wellbore event, based on historical well data. The predictive model can be configured to predict a probability of a wellbore event occurring in a target well. The predictive model can be configured to provide guidance for drilling the target well.
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 forage commandés par ordinateurSystèmes spécialement adaptés à la surveillance de plusieurs variables ou conditions de forage
20.
IMPACT JAR DELAY, ACTIVATION INDICATOR, SHOCK ABSORBER, AND RELATCH ASSIST
An impact jar apparatus including a dynamic portion connectable to an upper tool string portion, a static portion connectable to a lower tool string portion, and a hydraulic manifold, an activation indicator, a relatch assist, and/or a shock absorber. The hydraulic manifold fluidly communicates with an annulus between the dynamic and static portions. The hydraulic manifold adjusts a delay between application of a trigger tension and consequent activation of the impact jar apparatus. The activation indicator, including a wire coil in the static portion and magnets carried by the dynamic portion, generates a magnetic field whereby a voltage pulse is generated in the wire coil in response to the magnetic field passing the wire coil upon activation of the impact jar apparatus. The relatch assist urges the dynamic and static portions toward a latched position. The shock absorber absorbs axial shock generated by activation of the impact jar apparatus.
E21B 31/113 - Repêchage ou dégagement d'objets dans les trous de forage ou dans les puits en utilisant des moyens de percussion pour dégager les parties coincées, p. ex. des coulisses de battage fonctionnant hydrauliquement
A method of cementing a tubular string in a wellbore can include applying a predetermined pressure differential from a flow passage extending axially through the tubular string to an annulus surrounding the tubular string, thereby opening a rupture disk of a cementing stage tool connected in the tubular string, and then flowing a fluid through the flow passage and into the annulus via the rupture disk, thereby displacing an opening plug into engagement with an opening sleeve of the cementing stage tool. A cementing stage tool can include a longitudinal flow passage, an outer housing assembly, an opening sleeve that prevents fluid flow between the flow passage and a housing port in a run-in configuration, and a rupture disk that permits fluid flow between the flow passage and the housing port in response to a predetermined pressure differential applied from the flow passage to the housing port.
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
22.
FORMATION TESTING WITH CONTROLLED PRESSURE DRILLING
A formation testing method can include deploying a drill string including a packer and a circulating tool into a well, setting the packer, thereby blocking fluid flow through an annulus, and opening the circulating tool, thereby permitting fluid communication between the annulus and an interior flow passage of the drill string. The opening step can include displacing a radio frequency identification tag into the circulating tool. A formation testing system can include a drill string with a drill bit, a circulating tool and a packer. The packer is configured to seal off an annulus, and the circulating tool is selectively operable to permit fluid communication between the annulus and an interior flow passage of the drill string in response to a radio frequency identification tag being deployed into the circulating tool.
E21B 21/08 - Commande ou surveillance de la pression ou de l'écoulement du fluide de forage, p. ex. remplissage automatique des trous de forage, commande automatique de la pression au fond
E21B 49/08 - Prélèvement d'échantillons de fluides ou test des fluides dans les trous de forage ou dans les puits
E21B 47/12 - Moyens pour la transmission de signaux de mesure ou signaux de commande du puits vers la surface, ou de la surface vers le puits, p. ex. pour la diagraphie pendant le forage
Power-operated downhole tools for use in the oil and gas
industry, namely, modular multi-function cement-through
systems comprising cutters, mills, or spears for anchoring
to a well casing.
24.
Impact Jar Delay, Activation Indicator, Shock Absorber, and Relatch Assist
An impact jar apparatus including a dynamic portion connectable to an upper tool string portion, a static portion connectable to a lower tool string portion, and a hydraulic manifold, an activation indicator, a relatch assist, and/or a shock absorber. The hydraulic manifold fluidly communicates with an annulus between the dynamic and static portions. The hydraulic manifold adjusts a delay between application of a trigger tension and consequent activation of the impact jar apparatus. The activation indicator, including a wire coil in the static portion and magnets carried by the dynamic portion, generates a magnetic field whereby a voltage pulse is generated in the wire coil in response to the magnetic field passing the wire coil upon activation of the impact jar apparatus. The relatch assist urges the dynamic and static portions toward a latched position. The shock absorber absorbs axial shock generated by activation of the impact jar apparatus.
E21B 31/113 - Repêchage ou dégagement d'objets dans les trous de forage ou dans les puits en utilisant des moyens de percussion pour dégager les parties coincées, p. ex. des coulisses de battage fonctionnant hydrauliquement
A wet-mate connection is used in a well and comprises first and second connection assemblies and an actuator. The first connection assembly includes at least one first connector for at least one first control line. The second connection assembly is configured to connect with the first connection assembly and includes at least one second connector for at least one second control line. The second connector is movable on the second connection assembly between a retracted condition and an extended condition. In the extended condition, the second connector can mate with the first connector to communicate the first and second control lines with one another. The actuator is disposed on the second connection assembly and is configured to move the second connector at least from the retracted condition to the extended condition.
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
26.
AXIALLY AND ROTATIONALLY LOCKED MODULAR VALVE ASSEMBLY SYSTEM
A modular system of plunger valve assemblies provides for axially and rotationally locking joints between upper and lower valve housings. Also provided are rotationally locking joints between adjacent valve assemblies.
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 17/046 - AccouplementsJoints entre tige et trépan, ou entre tiges avec nervures, goupilles ou mâchoires et rainures complémentaires ou similaires, p. ex. accrochage à baïonnette
F16K 15/06 - Soupapes, clapets ou valves de retenue à corps de soupapes rigides guidés par tige-guide
27.
AXIALLY AND ROTATIONALLY LOCKED MODULAR VALVE ASSEMBLY SYSTEM
A modular system of plunger valve assemblies provides for axially and rotationally locking joints between upper and lower valve housings. Also provided are rotationally locking joints between adjacent valve assemblies.
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
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 setting tool disposed on tubing runs a packer into casing. During a setting process, a plug is engaged on a seat of an intensifying piston disposed in the tool. Tubing pressure applied against the seated plug moves the intensifying piston, which produces intensified pressure on fluid in a first volume of the intensifying piston communicated to a second volume of a setting piston. In response, the setting piston moves on the tool toward the packer's packing assembly. At some point in the process, the seated plug can be released from the seat. Additionally in the process, the second volume can fill with actuation fluid drawn through a fill valve from an annular space between the setting tool and the casing. The intensifying piston can then be reset as the actuation fluid is communicated from the second volume to the first volume.
E21B 23/06 - Appareils pour déplacer, mettre en place, verrouiller, libérer ou retirer, les outils, les packers ou autres éléments dans les trous de forage pour le montage des packers
E21B 23/04 - Appareils pour déplacer, mettre en place, verrouiller, libérer ou retirer, les outils, les packers ou autres éléments dans les trous de forage mis en œuvre à l'aide de moyens fluides, p. ex. actionnés par explosion
A rotating control device can include a groove formed on a housing, and an elastomeric ring isolating inner and outer portions of the groove, the elastomeric ring permitting fluid communication between the inner and outer portions of the groove in response to a pressure differential from the inner to the outer portion of the groove. A method can include forming a circumferentially extending groove, providing fluid communication between the groove and an annular area isolated between rotary seals, and positioning an elastomeric ring in the groove, the elastomeric ring preventing fluid flow from an exterior of the groove to the annular area, and permitting fluid flow from the annular area to the exterior of the groove. Another rotating control device can include an elastomeric ring in a groove, and a passage in a housing that provides fluid communication between the groove and an annular area between rotary seals.
E21B 33/00 - Étanchement ou bouchage des trous de forage ou des puits
F16J 15/3284 - Joints d'étanchéité entre deux surfaces mobiles l'une par rapport à l'autre par joints élastiques, p. ex. joints toriques caractérisés par leur structureEmploi des matériaux
A rotating control device can include a groove formed on a housing, and an elastomeric ring isolating inner and outer portions of the groove, the elastomeric ring permitting fluid communication between the inner and outer portions of the groove in response to a pressure differential from the inner to the outer portion of the groove. A method can include forming a circumferentially extending groove, providing fluid communication between the groove and an annular area isolated between rotary seals, and positioning an elastomeric ring in the groove, the elastomeric ring preventing fluid flow from an exterior of the groove to the annular area, and permitting fluid flow from the annular area to the exterior of the groove. Another rotating control device can include an elastomeric ring in a groove, and a passage in a housing that provides fluid communication between the groove and an annular area between rotary seals.
A tubular string can include helical threads on respective tubulars, and a structural formation on at least one of the threads. The formation is configured to produce a change in torque as the threads are threaded together. A method of making up a threaded connection between tubulars can include producing a structural formation on at least one of threads of the respective tubulars, engaging the threads, and applying torque to the threaded connection, thereby causing the tubulars to shoulder up. The formation causes a change in the torque a predetermined number of turns prior to the shoulder up.
A tubular connection position measurement system can include an acoustic transmitter (38) secured with a rotary table (16), and an acoustic receiver (40) secured with the rotary table. Another tubular connection position measurement system can include an acoustic transmitter (38), an acoustic receiver (40), and a controller (46) configured to adjust a position of a tong assembly (28), based on a transit time of an acoustic signal transmitted in a tubular and received by the acoustic receiver. A method of determining a tubular connection position can include transmitting an acoustic signal through a tubular, a portion of the tubular being positioned above a rig floor (18), receiving a reflection of the acoustic signal, and determining a height (H) of the portion of the tubular above the rig floor, based on a transit time of the transmitted and reflected acoustic signal through the portion of the tubular.
A tubular string can include helical threads on respective tubulars, and a structural formation on at least one of the threads. The formation is configured to produce a change in torque as the threads are threaded together. A method of making up a threaded connection between tubulars can include producing a structural formation on at least one of threads of the respective tubulars, engaging the threads, and applying torque to the threaded connection, thereby causing the tubulars to shoulder up. The formation causes a change in the torque a predetermined number of turns prior to the shoulder up.
A method of cementing a tubular string in a wellbore can include applying a predetermined pressure differential from a flow passage extending axially through the tubular string to an annulus surrounding the tubular string, thereby opening a rupture disk of a cementing stage tool connected in the tubular string, and then flowing a fluid through the flow passage and into the annulus via the rupture disk, thereby displacing an opening plug into engagement with an opening sleeve of the cementing stage tool. A cementing stage tool can include a longitudinal flow passage, an outer housing assembly, an opening sleeve that prevents fluid flow between the flow passage and a housing port in a run-in configuration, and a rupture disk that permits fluid flow between the flow passage and the housing port in response to a predetermined pressure differential applied from the flow passage to the housing port.
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 34/06 - Aménagements des vannes pour les trous de forage ou pour les puits dans les puits
E21B 34/10 - Aménagements des vannes pour les trous de forage ou pour les puits dans les puits actionnés par un fluide de commande provenant de l'extérieur du trou de forage
E21B 34/14 - Aménagements des vannes pour les trous de forage ou pour les puits dans les puits actionnés par le mouvement des outils, p. ex. obturateurs à manchons actionnés par des pistons ou par des outils à câble
A gas lift device includes a housing, a valve, and a nozzle. The housing defines a chamber and defines an inlet and an outlet in communication with the chamber. The valve in the chamber permits fluid communication from the inlet toward the outlet and prevents fluid communication in the reverse. The nozzle disposed in the chamber has a converging section, a throat, and a diverging section, which extend along a longitudinal axis of the chamber. A surface of the converging section converges inwardly from the chamber to the throat to funnel fluid communication from the inlet to the throat. A flow restriction of the throat restricts the fluid communication from the converging section to the diverging section. A surface of the diverging section diverges outwardly from the throat toward the outlet. Vanes extend inwardly in the diverging section and spiral about the longitudinal axis.
A tubular connection position measurement system can include an acoustic transmitter secured with a rotary table, and an acoustic receiver secured with the rotary table. Another tubular connection position measurement system can include an acoustic transmitter, an acoustic receiver, and a controller configured to adjust a position of a tong assembly, based on a transit time of an acoustic signal transmitted in a tubular and received by the acoustic receiver. A method of determining a tubular connection position can include transmitting an acoustic signal through a tubular, a portion of the tubular being positioned above a rig floor, receiving a reflection of the acoustic signal, and determining a height of the portion of the tubular above the rig floor, based on a transit time of the transmitted and reflected acoustic signal through the portion of the tubular.
E21B 47/095 - Localisation ou détermination de la position d'objets dans les trous de forage ou dans les puitsIdentification des parties libres ou bloquées des tubes par détection d'anomalies acoustiques, p. ex. à l'aide de pulsations de pression de boue
E21B 41/00 - Matériel ou accessoires non couverts par les groupes
A method of cementing a tubular string in a wellbore can include applying a predetermined pressure differential from a flow passage extending axially through the tubular string to an annulus surrounding the tubular string, thereby opening a rupture disk of a cementing stage tool connected in the tubular string, and then flowing a fluid through the flow passage and into the annulus via the rupture disk, thereby displacing an opening plug into engagement with an opening sleeve of the cementing stage tool. A cementing stage tool can include a longitudinal flow passage, an outer housing assembly, an opening sleeve that prevents fluid flow between the flow passage and a housing port in a run-in configuration, and a rupture disk that permits fluid flow between the flow passage and the housing port in response to a predetermined pressure differential applied from the flow passage to the housing port.
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
A method for use with a subterranean well can include operating a human interface controller to control a well operation, thereby producing an operational force in the well operation, and applying a feedback force to an input structure of the human interface controller, the feedback force being based on the operational force. A system for use with a subterranean well can include a human interface controller configured to receive human input to control a well operation, and a control system configured to produce an operational force in the well operation in response to the human input. The control system is further configured to produce a feedback force in the human interface controller in opposition to the human input.
G05G 9/047 - Mécanismes de commande manuelle équipés d'un seul organe de commande travaillant avec plusieurs organes commandés, p. ex. en sélection ou simultanément l'organe de commande étant manœuvré de différentes manières indépendantes, chacune de ces manœuvres individuelles entraînant un seul organe commandé dans lesquels la manœuvre de l'organe de commande peut être effectuée de plusieurs manières simultanément l'organe de commande étant manœuvré à la main autour d'axes orthogonaux, p. ex. manches à balai
E21B 3/02 - Moyens d'entraînement de surface pour forage par rotation
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 forageAppareils pour faire avancer les tiges ou les câbles
E21B 19/06 - Élévateurs, c.-à-d. dispositifs agrippant tiges ou tubes
E21B 19/16 - Branchement ou débranchement des accouplements de tubes ou de joints
39.
SYSTEM AND METHOD FOR AUTOMATED CONFIGURATION OF HANDLING EQUIPMENT AND DOWNHOLE COMPONENTS
System and methods disclosed herein store sizing parameters for sized members used with downhole components and stores dimensions of the downhole components to be handled at the wellsite. The sizing parameter for a respective sized member defines how the respective sized member is sized for use with the downhole components. Machine-readable indicia is encoded with the sizing parameters and physically associated with the sized members. When handling a current downhole component, the sizing parameter associated with current sized member is determined by reading the machine-readable indicia The sizing parameter associated with the read indicia is then compared to the stored the dimensions of the downhole components to be handled. An automated response is then produced based on the comparison. The sized members can be gripping elements used in a spider or an elevator, jaws used on a power tong, or features disposed on a downhole tool.
G05B 19/4155 - Commande numérique [CN], c.-à-d. machines fonctionnant automatiquement, en particulier machines-outils, p. ex. dans un milieu de fabrication industriel, afin d'effectuer un positionnement, un mouvement ou des actions coordonnées au moyen de données d'un programme sous forme numérique caractérisée par le déroulement du programme, c.-à-d. le déroulement d'un programme de pièce ou le déroulement d'une fonction machine, p. ex. choix d'un programme
G06K 19/06 - Supports d'enregistrement pour utilisation avec des machines et avec au moins une partie prévue pour supporter des marques numériques caractérisés par le genre de marque numérique, p. ex. forme, nature, code
G06K 19/07 - Supports d'enregistrement avec des marques conductrices, des circuits imprimés ou des éléments de circuit à semi-conducteurs, p. ex. cartes d'identité ou cartes de crédit avec des puces à circuit intégré
40.
SYSTEM AND METHOD FOR AUTOMATED CONFIGURATION OF HANDLING EQUIPMENT AND DOWNHOLE COMPONENTS
System and methods disclosed herein store sizing parameters for sized members used with downhole components and stores dimensions of the downhole components to be handled at the wellsite. The sizing parameter for a respective sized member defines how the respective sized member is sized for use with the downhole components. Machine-readable indicia are encoded with the sizing parameters and physically associated with the sized members. When handling a current downhole component, the sizing parameter associated with current sized member is determined by reading the machine-readable indicia. The sizing parameter associated with the read indicia is then compared to the stored the dimensions of the downhole components to be handled. An automated response is then produced based on the comparison. The sized members can be gripping elements used in a spider or an elevator, jaws used on a power tong, or features disposed on a downhole tool.
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 forageAppareils pour faire avancer les tiges ou les câbles
E21B 41/00 - Matériel ou accessoires non couverts par les groupes
E21B 19/16 - Branchement ou débranchement des accouplements de tubes ou de joints
A wet-mate connection is used in a well and comprises first and second connection assemblies and an actuator. The first connection assembly includes at least one first connector for at least one first control line. The second connection assembly is configured to connect with the first connection assembly and includes at least one second connector for at least one second control line. The second connector is movable on the second connection assembly between a retracted condition and an extended condition. In the extended condition, the second connector can mate with the first connector to communicate the first and second control lines with one another. The actuator is disposed on the second connection assembly and is configured to move the second connector at least from the retracted condition to the extended condition.
A wet-mate connection is used in a well and comprises first and second connection assemblies and an actuator. The first connection assembly includes at least one first connector for at least one first control line. The second connection assembly is configured to connect with the first connection assembly and includes at least one second connector for at least one second control line. The second connector is movable on the second connection assembly between a retracted condition and an extended condition. In the extended condition, the second connector can mate with the first connector to communicate the first and second control lines with one another. The actuator is disposed on the second connection assembly and is configured to move the second connector at least from the retracted condition to the extended condition.
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
43.
APPARATUS AND METHODS FOR DEPLOYING SENSOR IN 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.
E21B 47/01 - Dispositifs pour supporter des instruments de mesure sur des trépans, des tubes, des tiges ou des câbles de forageProtection des instruments de mesure dans les trous de forage contre la chaleur, les chocs, la pression ou similaire
E21B 23/03 - Appareils pour déplacer, mettre en place, verrouiller, libérer ou retirer, les outils, les packers ou autres éléments dans les trous de forage pour mettre en place des outils sur les supports ou dans les retraits ou poches excentrées ou pour les en retirer
44.
Synchronized Actuator Having Multiple Motors for Downhole Well Tool
A downhole tool, such an interval control valve, for use in a well has multiple motors and two drive assemblies to displace a yoke. A member, such as a sliding sleeve, of the downhole tool is connected to the yoke and can be actuated in response to the displacement of the yoke. The drive assemblies include first and second rotatable screws, and the yoke is disposed on the screws. Each motor can produce drive to rotate a respective screw. A respective gear is rotatable in association with at least the rotation of its associated screw. An intermediate gear is engaged between these two gears. The intermediate gear interconnects the rotation of the two screws, forcing them to rotate at the same speed. Likewise, the intermediate gear balances the drive of the motors, forcing the two screws to rotate at the same speed.
A variable-frequency drive includes a rectifier, a filter, an inverter, a capacitor bank, and control circuitry. The rectifier converts AC power from a power source to DC power on a DC bus for filtering by the filter. The inverter converts the DC power to three-phase AC power for output to the electric motor. The capacitor bank has one or more capacitors connected to the DC bus. The capacitor bank can store regenerative power on the DC bus from the inverter and can supply the stored DC power to the DC bus for conversion to the three-phase AC power to drive the electric motor. The control circuitry pre-charges the capacitor bank from the AC power of the power source. The control circuitry monitors one or more parameters of the variable-frequency drive and detects one or more fault conditions associated with the one or more monitored parameters.
H02P 29/024 - Détection d’un défaut, p. ex. court circuit, rotor bloqué, circuit ouvert ou perte de charge
H02J 7/00 - Circuits pour la charge ou la dépolarisation des batteries ou pour alimenter des charges par des batteries
H02J 7/34 - Fonctionnement en parallèle, dans des réseaux, de batteries avec d'autres sources à courant continu, p. ex. batterie tampon
H02M 5/458 - Transformation d'une puissance d'entrée en courant alternatif en une puissance de sortie en courant alternatif, p. ex. pour changement de la tension, pour changement de la fréquence, pour changement du nombre de phases avec transformation intermédiaire en courant continu par convertisseurs statiques utilisant des tubes à décharge ou des dispositifs à semi-conducteurs pour transformer le courant continu intermédiaire en courant alternatif utilisant des dispositifs du type triode ou transistor exigeant l'application continue d'un signal de commande utilisant uniquement des dispositifs à semi-conducteurs
46.
Managing regenerative energy of rod pump system without dynamic braking resistor
A variable-frequency drive includes a rectifier, a filter, an inverter, a capacitor bank, and control circuitry. The rectifier converts AC power from a power source to DC power on a DC bus for filtering by the filter. The inverter converts the DC power to three-phase AC power for output to the electric motor. The capacitor bank has one or more capacitors connected to the DC bus. The capacitor bank can store regenerative power on the DC bus from the inverter and can supply the stored DC power to the DC bus for conversion to the three-phase AC power to drive the electric motor. The control circuitry pre-charges the capacitor bank from the AC power of the power source. The control circuitry monitors one or more parameters of the variable-frequency drive and detects one or more fault conditions associated with the one or more monitored parameters.
H02P 27/08 - Dispositions ou procédés pour la commande de moteurs à courant alternatif caractérisés par le type de tension d'alimentation utilisant une tension d’alimentation à fréquence variable, p. ex. tension d’alimentation d’onduleurs ou de convertisseurs utilisant des convertisseurs de courant continu en courant alternatif ou des onduleurs avec modulation de largeur d'impulsions
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
H02P 25/032 - Moteurs à mouvement alternatif, oscillant ou vibrant
47.
SYSTEM AND METHOD FOR VERIFICATION OF WELL SERVICE DESIGN
Systems and methods monitor equipment used in performing well services. Machine-readable indicia (e.g., RFID tags) for the equipment are encoded with coded identifiers, each of which includes information about product line, operational classification, and unique identification. The encoded indicia are physically associated with the equipment, and tracking information is associated in the system with the coded identifiers. The system compiles a design list to implement a given service using equipment. The system then remotely tracks the equipment using the coded identifiers of the encoded indicia. In particular, the equipment in the design list is dispatched to the site by verifying the encoded indicia for the equipment, a dispatched list of the encoded indicia is received for the equipment obtained at the site, and the dispatched list is verified against the design list. Additional tracking of the equipment can be performed with the coded identifiers and encoded indica.
Systems and methods monitor equipment used in performing well services. Machine-readable indicia (e.g., RFID tags) for the equipment are encoded with coded identifiers, each of which includes information about product line, operational classification, and unique identification. The encoded indicia are physically associated with the equipment, and tracking information is associated in the system with the coded identifiers. The system compiles a design list to implement a given service using equipment. The system then remotely tracks the equipment using the coded identifiers of the encoded indicia. In particular, the equipment in the design list is dispatched to the site by verifying the encoded indicia for the equipment, a dispatched list of the encoded indicia is received for the equipment obtained at the site, and the dispatched list is verified against the design list. Additional tracking of the equipment can be performed with the coded identifiers and encoded indica.
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.
Systems and methods are provided for evaluating a foamer for use in an oil and gas well for unloading of a liquid. The systems and methods provide for methods including: (a) combining (i) an aqueous phase, a hydrocarbon phase, or both an aqueous phase and a hydrocarbon phase in a predetermined proportion with (ii) a foamer to obtain a liquid, wherein the foamer is in a predetermined concentration in the liquid; (b) sparging the liquid with a gas at a predetermined gas flow rate to create a foam from at least some of the liquid and at least some of the gas; and (c) during or after the step of sparging, determining the amount of the liquid in the foam, wherein the step of determining is performed one or more times.
G01N 7/16 - Analyse des matériaux en mesurant la pression ou le volume d'un gaz ou d'une vapeur en permettant au matériau d'émettre un gaz ou une vapeur, p. ex. la vapeur d'eau, et en mesurant une différence de pression ou de volume en chauffant le matériau
E21B 43/16 - Procédés de récupération assistée pour l'extraction d'hydrocarbures
G01N 33/00 - Recherche ou analyse des matériaux par des méthodes spécifiques non couvertes par les groupes
51.
SYSTEMS AND METHODS TO EVALUATE A FOAMER FOR UNLOADING LIQUID IN OIL AND GAS WELLS OF MATURE FIELDS
Systems and methods are provided for evaluating a foamer for use in an oil and gas well for unloading of a liquid. The systems and methods provide for methods including: (a) combining (i) an aqueous phase, a hydrocarbon phase, or both an aqueous phase and a hydrocarbon phase in a predetermined proportion with (ii) a foamer to obtain a liquid, wherein the foamer is in a predetermined concentration in the liquid; (b) sparging the liquid with a gas at a predetermined gas flow rate to create a foam from at least some of the liquid and at least some of the gas; and (c) during or after the step of sparging, determining the amount of the liquid in the foam, wherein the step of determining is performed one or more times.
E21B 49/08 - Prélèvement d'échantillons de fluides ou test des fluides dans les trous de forage ou dans les puits
E21B 49/00 - Test pour déterminer la nature des parois des trous de forageEssais de couchesProcédés ou appareils pour prélever des échantillons du terrain ou de fluides en provenance des puits, spécialement adaptés au forage du sol ou aux puits
E21B 21/14 - Procédés ou appareils pour nettoyer les trous de forage par jet de fluide, p. ex. en utilisant l'air d'échappement du moteur utilisant des liquides et des gaz, p. ex. des mousses
A tong positioning system includes a positioning device configured to move a tong assembly. The positioning device includes a first actuator, a second actuator, and a control attachment attachable to the positioning device. The control attachment includes a shutoff valve fluidly coupled to a hydraulic supply, a control valve block, and a control device. 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.
Methods comprising: injecting into a wellbore in a subterranean formation a multi-particle lost circulation material composition comprising a base fluid and a particle blend comprising substantially cylindrical particles and substantially spherical particles and wherein said particle blend comprises: degradable particles of at least three different sizes and wherein a first-sized particles and a second-sized particles are substantially cylindrical and a third-sized particles are substantially spherical.
C09K 8/504 - Compositions à base d'eau ou de solvants polaires
C09K 8/506 - Compositions à base d'eau ou de solvants polaires contenant des composés organiques
C09K 8/516 - Compositions pour le plâtrage des parois de trous de forage, c.-à-d. compositions pour la consolidation temporaire des parois des trous de forage caractérisées par leur forme ou par la forme de leurs composants, p. ex. matériaux encapsulés
E21B 33/138 - Plâtrage de la paroi du trou de forageInjections dans la formation
54.
Methods of using multi-particle lost circulation material in highly porous or fractured formations
Methods comprising: injecting into a wellbore in a subterranean formation a multi-particle lost circulation material composition comprising a base fluid and a particle blend comprising substantially cylindrical particles and substantially spherical particles and wherein said particle blend comprises: degradable particles of at least three different sizes and wherein a first-sized particles and a second-sized particles are substantially cylindrical and a third-sized particles are substantially spherical.
E21B 21/00 - Procédés ou appareils pour nettoyer les trous de forage par jet de fluide, p. ex. en utilisant l'air d'échappement du moteur
C09K 8/516 - Compositions pour le plâtrage des parois de trous de forage, c.-à-d. compositions pour la consolidation temporaire des parois des trous de forage caractérisées par leur forme ou par la forme de leurs composants, p. ex. matériaux encapsulés
E21B 33/138 - Plâtrage de la paroi du trou de forageInjections dans la formation
A pressure control assembly can include an outer housing and a rotating control device including a bearing assembly with a rotatable inner barrel, a pressure sensor and one or more magnetic field generators, and at least two seal elements configured to seal between the inner barrel and a tubular positioned in the pressure control assembly. A magnetic field detector secured to the outer housing is configured to receive signals from the magnetic field generators, the signals being indicative of outputs of the pressure sensor. A method can include securing a magnetic field detector to an outer housing, installing the rotating control device in the outer housing, the rotating control device comprising a rotatable inner barrel, a pressure sensor and multiple magnetic field generators, and transmitting signals indicative of outputs of the pressure sensor from the magnetic field generators to the magnetic field detector.
A subsea assembly can include a pressure control device having an annular seal configured to seal off an annulus formed between an outer housing and a tubular string, a connector, and a guide configured to guide the tubular string into an internal flow passage extending through the subsea assembly, the pressure control device being connected between the connector and the guide. A method can include assembling a subsea assembly with a pressure control device and a connector, the pressure control device including an outer housing and an annular seal, lowering the subsea assembly through water from a rig to a subsea wellhead installation, connecting the subsea assembly to the subsea wellhead installation, and positioning a tubular string in the subsea assembly, so that the annular seal seals against an external surface of the tubular string, the tubular string being exposed to the water between the rig and the subsea assembly.
E21B 33/038 - Connecteurs utilisés sur les têtes de puits, p. ex. pour relier l'obturateur anti-éruption et la colonne montante dans l'eau
E21B 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 37/00 - Procédés ou appareils pour nettoyer les trous de forage ou les puits
A pressure control assembly can include an outer housing and a rotating control device including a bearing assembly with a rotatable inner barrel, a pressure sensor and one or more magnetic field generators, and at least two seal elements configured to seal between the inner barrel and a tubular positioned in the pressure control assembly. A magnetic field detector secured to the outer housing is configured to receive signals from the magnetic field generators, the signals being indicative of outputs of the pressure sensor. A method can include securing a magnetic field detector to an outer housing, installing the rotating control device in the outer housing, the rotating control device comprising a rotatable inner barrel, a pressure sensor and multiple magnetic field generators, and transmitting signals indicative of outputs of the pressure sensor from the magnetic field generators to the magnetic field detector.
E21B 21/08 - Commande ou surveillance de la pression ou de l'écoulement du fluide de forage, p. ex. remplissage automatique des trous de forage, commande automatique de la pression au fond
A pressure control assembly can include an outer housing and a rotating control device including a bearing assembly with a rotatable inner barrel, a pressure sensor and one or more magnetic field generators, and at least two seal elements configured to seal between the inner barrel and a tubular positioned in the pressure control assembly. A magnetic field detector secured to the outer housing is configured to receive signals from the magnetic field generators, the signals being indicative of outputs of the pressure sensor. A method can include securing a magnetic field detector to an outer housing, installing the rotating control device in the outer housing, the rotating control device comprising a rotatable inner barrel, a pressure sensor and multiple magnetic field generators, and transmitting signals indicative of outputs of the pressure sensor from the magnetic field generators to the magnetic field detector.
E21B 47/06 - Mesure de la température ou de la pression
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
(1) Power-operated downhole tools for use in the oil and gas industry, namely, modular multi-function cement-through systems comprising cutters, mills, or spears for anchoring to a well casing.
An annulus flow control tool can include an inner mandrel with a longitudinal bypass flow path, a sleeve on the inner mandrel, the sleeve being displaceable on the inner mandrel between bypass open and bypass closed positions, and at least one annular seal carried externally on the sleeve. A method of controlling annulus flow can include connecting an annulus flow control tool in a tubular string, the annulus flow control tool including a bypass flow path and at least one external annular seal, deploying the tubular string into the well, sealingly engaging a well surface with the annular seal, flowing a fluid through the tubular string into the well, thereby causing another fluid in an annulus between the tubular string and the well surface to flow through the bypass flow path, and closing the bypass flow path, the annulus flow control tool thereby blocking flow through the annulus.
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 33/126 - PackersBouchons à cuvette ou jupe élastiques actionnées par pression d'un fluide
61.
Non-intrusive rheometer for use in well operations
A method of determining viscosity can include connecting a bypass flow passage in parallel with a main flow passage, connecting a mass flowmeter and a variable flow restrictor in the bypass flow passage, and connecting at least one viscometer to the bypass flow passage. A rheology measurement apparatus can include a bypass flow passage connected in parallel with a main flow passage, a mass flowmeter connected in the bypass flow passage, and a pipe viscometer connected in the bypass flow passage. Another bypass flow passage may be connected in parallel with the main flow passage, with another mass flowmeter connected in the second bypass flow passage.
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 forage commandés par ordinateurSystèmes spécialement adaptés à la surveillance de plusieurs variables ou conditions de forage
G01N 11/08 - Recherche des propriétés d'écoulement des matériaux, p. ex. la viscosité, la plasticitéAnalyse des matériaux en déterminant les propriétés d'écoulement en mesurant l'écoulement du matériau à travers un passage étroit, p. ex. un tube, une ouverture en mesurant la pression nécessaire à la production d'un écoulement connu
62.
VALVE ASSEMBLY FOR DOWNHOLE PUMP OF RECIPROCATING PUMP SYSTEM
A downhole pump used for a reciprocating pump includes a barrel and a plunger. The barrel couples to a tubing string and has a standing valve. The plunger couples to a rod string and has a traveling valve. One or both of the valves can include an assembly comprising a housing and an insert. The insert allowing for flow therethrough has a ball stop and a ball passage. Positioned in housing, one end of the insert engages a tapered sidewall in the housing. The insert is secured with metallic material metallurgically affixed between the insert and the housing. For example, brazing material can be brazed at the end of the insert to metallurgically affix the insert in the passage. A ball is positioned in the insert, and a seat is positioned adjacent an end of the insert. The assembly is then incorporated into components of the pump.
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
F16K 15/04 - Soupapes, clapets ou valves de retenue à corps de soupapes rigides guidés en forme de sphère
F16K 27/02 - Structures des logementsMatériaux utilisés à cet effet des soupapes de levage
An annulus flow control tool can include an inner mandrel (44) with a longitudinal bypass flow path (64), a sleeve (52) on the inner mandrel (44), the sleeve being displaceable on the inner mandrel (44) between bypass open and bypass closed positions, and at least one annular seal (50) carried externally on the sleeve.
E21B 33/124 - Unités à bouchons espacés longitudinalement pour isoler les espaces intermédiaires
E21B 34/00 - Aménagements des vannes pour les trous de forage ou pour 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
64.
NON-INTRUSIVE RHEOMETER FOR USE IN WELL OPERATIONS
A method of determining viscosity can include connecting a bypass flow passage in parallel with a main flow passage, connecting a mass flowmeter and a variable flow restrictor in the bypass flow passage, and connecting at least one viscometer to the bypass flow passage. A rheology measurement apparatus can include a bypass flow passage connected in parallel with a main flow passage, a mass flowmeter connected in the bypass flow passage, and a pipe viscometer connected in the bypass flow passage. Another bypass flow passage may be connected in parallel with the main flow passage, with another mass flowmeter connected in the second bypass flow passage.
G01N 11/04 - Recherche des propriétés d'écoulement des matériaux, p. ex. la viscosité, la plasticitéAnalyse des matériaux en déterminant les propriétés d'écoulement en mesurant l'écoulement du matériau à travers un passage étroit, p. ex. un tube, une ouverture
G01N 11/08 - Recherche des propriétés d'écoulement des matériaux, p. ex. la viscosité, la plasticitéAnalyse des matériaux en déterminant les propriétés d'écoulement en mesurant l'écoulement du matériau à travers un passage étroit, p. ex. un tube, une ouverture en mesurant la pression nécessaire à la production d'un écoulement connu
65.
Electronic limit barrier for hydraulic power tongs
A system includes hydraulic power tongs mounted to a rig floor and including a primary tong and one or more controls for operating the primary tong, an electronic limit barrier device including one or more sensors operable to determine a distance between the hydraulic power tongs and an operator on the rig floor, and a hydraulic control valve in communication with the electronic limit barrier device and fluidly coupled to the hydraulic power tongs. The electronic limit barrier device is programmed to compare the distance to a pre-defined cutoff distance, and release hydraulic fluid from the hydraulic power tongs upon determining that the distance is less than or equal to the pre-defined cutoff distance.
A long-stroke pumping unit includes a tower; a counterweight assembly movable along the tower; a crown mounted atop the tower; a sprocket supported by the crown and rotatable relative thereto; and a belt. The unit further includes a motor having a stator mounted to the crown and a rotor torsionally connected to the sprocket; and a sensor for detecting position of the counterweight assembly. The pumping unit may include a dynamic control system for controlling a speed of a motor.
F04B 49/20 - Commande des "machines", pompes ou installations de pompage ou mesures de sécurité les concernant non prévues dans les groupes ou présentant un intérêt autre que celui visé par ces groupes en modifiant la vitesse d'entraînement
67.
APPARATUS AND METHOD FOR ASSEMBLING AND DEPLOYING WHIPSTOCK ASSEMBLY
An apparatus or cradle having top and bottom supports is used to assemble, transport, and deploy a bottom hole assembly. The cradle supports at least a whipstock and mill of the assembly during assembly and transport. At the rig, the assembly and at least the mill support are lifted, and a portion of the assembly is through a rotary table of the rig. The assembly is then supported on the rig by engaging a base of the cradle on the rotary table. A milling tool is connected to the mill of the assembly, and the assembly is disconnected from the at least one support of the cradle. The assembly and the milling tool can then be run through the rotary table for deployment downhole.
E21B 7/06 - Modification de la direction du trou de forage
E21B 19/00 - Manipulation de tiges, tubages, tubes ou autre objets analogues à l'extérieur du trou de forage, p. ex. dans la tour de forageAppareils pour faire avancer les tiges ou les câbles
68.
DRILLING SYSTEM AND METHOD USING DYNAMICALLY DETERMINED DRILLING WINDOW
Control of a drilling system (10) drilling a wellbore (12) is improved using a hydraulics model corrected for pressure losses. A surface backpressure of the outlet and a standpipe pressure of the inlet are measured with sensors (240) 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 forage commandés par ordinateurSystèmes spécialement adaptés à la surveillance de plusieurs variables ou conditions de forage
69.
Apparatus and method for assembling and deploying whipstock assembly
An apparatus or cradle having top and bottom supports is used to assemble, transport, and deploy a bottom hole assembly. The cradle supports at least a whipstock and mill of the assembly during assembly and transport. At the rig, the assembly and at least the mill support are lifted, and a portion of the assembly is through a rotary table of the rig. The assembly is then supported on the rig by engaging a base of the cradle on the rotary table. A milling tool is connected to the mill of the assembly, and the assembly is disconnected from the at least one support of the cradle. The assembly and the milling tool can then be run through the rotary table for deployment downhole.
A method of utilizing a hydraulics model (48) with a well operation can include the steps of inputting well parameters to the hydraulics model, assigning nodes (70) to respective well locations, the hydraulics model being configured to determine corresponding pressures at the respective nodes, and unevenly spacing the nodes along a wellbore (14). A well equipment control system (40) for use with a subterranean well can include a hydraulics model (48) configured to determine pressures at respective nodes along a wellbore, the nodes being unevenly spaced along the wellbore, and an actuator (44) configured to actuate well equipment (42) at least in part based on the hydraulics model pressure determinations.
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 41/00 - Matériel ou accessoires non couverts par les groupes
E21B 47/06 - Mesure de la température ou de la pression
71.
DRILLING SYSTEM AND METHOD USING DYNAMICALLY DETERMINED DRILLING WINDOW
Control of a drilling system drilling a wellbore is improved using a hydraulics 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 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 forage commandés par ordinateurSystèmes spécialement adaptés à la surveillance de plusieurs variables ou conditions de forage
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 47/022 - Détermination de l'inclinaison ou de la direction du trou de forage, p. ex. à l'aide de géomagnétisme
E21B 47/09 - Localisation ou détermination de la position d'objets dans les trous de forage ou dans les puitsIdentification des parties libres ou bloquées des tubes
A debris catcher assembly includes a debris filter assembly having a selectively operable valve. such as a rupture disk, to allow a secondary flow path should the debris filter assembly become clogged with debris.
E21B 27/00 - Récipients pour ramasser ou déposer des substances dans les trous de forage ou les puits, p. ex. cuillers pour ramasser de la boue ou du sableTrépans comportant des moyens pour ramasser des substances, p. ex. trépans à clapet
E21B 37/00 - Procédés ou appareils pour nettoyer les trous de forage ou les puits
E21B 43/34 - Aménagements pour séparer les matériaux produits par le puits
E21B 43/38 - Aménagements pour séparer les matériaux produits par le puits dans le puits
A convertible valve assembly includes an upper and lower plunger valve, connected to one another to operate in unison, and a retainer assembly for holding the valves in a bi-directional configuration and releasing the valves to a unidirectional configuration upon application of a downhole hydraulic pressure.
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 convertible valve assembly has an upper and lower plunger valve connected to one another so that they reciprocate together. A retainer assembly holds the valves in a bi-directional configuration, allowing fluid flow in both directions through the valves. The retainer assembly then releases the valves to a unidirectional configuration upon application of a downhole hydraulic pressure, so that fluid can flow only one direction through the valve assembly.
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 debris catcher assembly includes a debris filter assembly having a selectively operable valve, such as a rupture disk, to allow a secondary flow path should the debris filter assembly become clogged with debris.
E21B 27/00 - Récipients pour ramasser ou déposer des substances dans les trous de forage ou les puits, p. ex. cuillers pour ramasser de la boue ou du sableTrépans comportant des moyens pour ramasser des substances, p. ex. trépans à clapet
E21B 21/06 - Dispositions pour traiter les fluides de forage à l'extérieur du trou de forage
E21B 34/06 - Aménagements des vannes pour les trous de forage ou pour les puits dans les puits
76.
APPARATUS AND METHOD TO FORM CENTRALIZER BLADES ON WELLBORE TUBULAR
A tubular is prepared for downhole use to include integrated centralizer feature disposed thereon. Blade elements are disposed about a surface of the tubular. An interconnection, such as a band, connected between the blade elements can be used to wrap them circumferentially about the tubular. The blade elements are then affixed to the surface of the tubular to produce the integrated centralizer features by coating a spray welding material over at least a portion of the plurality of blade elements and over at least an adjacent portion of the surface of the tubular. The blade elements can be hollow vanes or fins so they are collapsible when a restriction is encountered downhole to avoid a stuck pipe situation.
A system (10) can include a tong assembly (12), a tong positioning device (28) configured to adjust a vertical height of the tong assembly, one or more calibration marker (42) secured to the tong assembly, and a camera (38) disposed at a camera position at which the calibration marker is within a field of view (40) of the camera. A method of vertically positioning a tong assembly can include taking a digital image of a tong assembly and one or more calibration marker, identifying a pixel position of the calibration marker in the digital image, and adjusting a height of the tong assembly based in part on the pixel position of the calibration marker.
A system can include a tong assembly, a tong positioning device configured to adjust a vertical height of the tong assembly, one or more calibration marker secured to the tong assembly, and a camera disposed at a camera position at which the calibration marker is within a field of view of the camera. A method of vertically positioning a tong assembly can include taking a digital image of a tong assembly and one or more calibration marker, identifying a pixel position of the calibration marker in the digital image, and adjusting a height of the tong assembly based in part on the pixel position of the calibration marker.
G06T 7/73 - Détermination de la position ou de l'orientation des objets ou des caméras utilisant des procédés basés sur les caractéristiques
E21B 19/16 - Branchement ou débranchement des accouplements de tubes ou de joints
G06T 7/50 - Récupération de la profondeur ou de la forme
G06V 10/44 - Extraction de caractéristiques locales par analyse des parties du motif, p. ex. par détection d’arêtes, de contours, de boucles, d’angles, de barres ou d’intersectionsAnalyse de connectivité, p. ex. de composantes connectées
G06V 10/56 - Extraction de caractéristiques d’images ou de vidéos relative à la couleur
A tubular shear assembly for use with a subterranean well can include a tubular shear device configured to shear a tubular string that extends into the well. The tubular shear device can include a body, a fixed shear jaw, and a rotary shear jaw configured to rotate relative to the body and the fixed shear jaw to shear the tubular string. A method of retrieving a tubular string from a subterranean well can include displacing a tubular shear device, including positioning the tubular string between a fixed shear jaw of the tubular shear device and a rotary shear jaw of the tubular shear device, and rotating the rotary shear jaw relative to the fixed shear jaw, thereby shearing the tubular string.
B23D 21/00 - Machines ou dispositifs pour le cisaillage ou le tronçonnage de tubes
B23D 17/00 - Machines à cisailler ou dispositifs de cisaillage taillant au moyen de lames articulées sur un seul axe
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 forageAppareils pour faire avancer les tiges ou les câbles
E21B 41/00 - Matériel ou accessoires non couverts par les groupes
80.
RETRIEVAL OF TUBULAR STRINGS FROM SUBTERRANEAN WELLS
A tubular shear assembly for use with a subterranean well can include a tubular shear device configured to shear a tubular string that extends into the well. The tubular shear device can include a body, a fixed shear jaw, and a rotary shear jaw configured to rotate relative to the body and the fixed shear jaw to shear the tubular string. A method of retrieving a tubular string from a subterranean well can include displacing a tubular shear device, including positioning the tubular string between a fixed shear jaw of the tubular shear device and a rotary shear jaw of the tubular shear device, and rotating the rotary shear jaw relative to the fixed shear jaw, thereby shearing the tubular string.
E21B 29/00 - Découpage ou destruction de tubes, packers, bouchons ou câbles, situés dans les trous de forage ou dans les puits, p. ex. découpage de tubes endommagés, de fenêtresDéformation des tubes dans les trous de forageRemise en état des tubages de puits sans les retirer du sol
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 forageAppareils pour faire avancer les tiges ou les câbles
81.
Apparatus and methods for deploying sensor in 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.
E21B 47/01 - Dispositifs pour supporter des instruments de mesure sur des trépans, des tubes, des tiges ou des câbles de forageProtection des instruments de mesure dans les trous de forage contre la chaleur, les chocs, la pression ou similaire
E21B 23/03 - Appareils pour déplacer, mettre en place, verrouiller, libérer ou retirer, les outils, les packers ou autres éléments dans les trous de forage pour mettre en place des outils sur les supports ou dans les retraits ou poches excentrées ou pour les en retirer
82.
Apparatus and method to form centralizer blades on wellbore tubular
A tubular is prepared for downhole use to include integrated centralizer feature disposed thereon. Blade elements are disposed about a surface of the tubular. An interconnection, such as a band, connected between the blade elements can be used to wrap them circumferentially about the tubular. The blade elements are then affixed to the surface of the tubular to produce the integrated centralizer features by coating a spray welding material over at least a portion of the plurality of blade elements and over at least an adjacent portion of the surface of the tubular. The blade elements can be hollow vanes or fins so they are collapsible when a restriction is encountered downhole to avoid a stuck pipe situation.
Methods, tools, and systems for determining two-phase borehole fluid holdup using pulsed neutron (PN) measurements are described. Embodiments of the techniques involve using formation models that are extended/extrapolated (or remodeled) to a value of 100 p.u., which correlates to the borehole environment where there is no formation matrix present. Those models can be used to determine the fractional relationship of oil and water in the borehole based on carbon and oxygen ratios provided by the PN measurement.
E21B 49/08 - Prélèvement d'échantillons de fluides ou test des fluides dans les trous de forage ou dans les puits
G01V 5/10 - Prospection ou détection au moyen de rayonnement ionisant, 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
84.
PULSED NEUTRON DETERMINATION OF BOREHOLE FLUID HOLD-UP
Methods, tools, and systems for determining two-phase borehole fluid holdup using pulsed neutron (PN) measurements are described. Embodiments of the techniques involve using formation models that are extended/ extrapolated (or remodeled) to a value of 100 p.u., which correlates to the borehole environment where there is no formation matrix present. Those models can be used to determine the fractional relationship of oil and water in the borehole based on carbon and oxygen ratios provided by the PN measurement.
G01V 5/10 - Prospection ou détection au moyen de rayonnement ionisant, 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
85.
Determination of neutron porosity and bulk density from a pulsed neutron tool
Methods and systems for determining bulk density and/or neutron porosity of a formation are described herein. The methods and systems use a pulsed neutron (PN) tool and may be performed with a tool having a single gamma detector though tools with multiple detectors may be used as well. The PN tool may be a geochemical logging tool. The methods and systems involve partitioning the time spectrum into pluralities of bins that are indicative of non-clay mineral elements and of shale/clay to the overall bulk density.
G01V 5/10 - Prospection ou détection au moyen de rayonnement ionisant, 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
86.
Determination of formation water salinity using time resolved chlorine capture gamma spectroscopy
Methods and systems for determining formation salinity using pulsed neutron (PN) tools are described. Embodiments of the described methods involve binning chlorine yields or chlorine count rates arising from capture events into early and late capture regimes, which may be used to attribute the events to either the borehole or the formation.
G01V 5/10 - Prospection ou détection au moyen de rayonnement ionisant, 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 cementing operation cements casing in a borehole. A bottom plug pumped down the casing ahead of cement lands at a float valve. Circulation of the cement is established through the bottom plug to a shoe track downhole from the float valve. A top plug pumped down the casing behind the cement lands on the bottom plug. An internal component of the float valve is released by building-up pressure in the casing behind the internal component up to a release threshold. The internal component can latch at the shoe. At least some of the cement in the shoe track is displaced from the casing's shoe to the borehole by pumping the plugs and the internal component to the shoe. With the cement displaced out of the shoe track, the time required to drill out the assembly can be greatly reduced.
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 cimentBouchons à cet effet
88.
Float valve producing turbulent flow for wet shoe track
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 an 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 cimentBouchons à cet effet
E21B 17/00 - Tiges ou tubes de forageTrains de tiges souplesTiges d'entraînementMasses-tigesTiges de pompageTubagesColonnes de production
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 34/06 - 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
A flow measurement apparatus can include a main flow passage having a flowmeter, a bypass flow passage connected in parallel with the main flow passage, the bypass flow passage having a flow restrictor, a mass flowmeter, and at least one sensor configured to measure a pressure differential across the mass flowmeter, and a control system configured to determine at least one rheological parameter of a non-Newtonian fluid based on outputs of the sensor and the mass flowmeter. A method for measuring a rheological fluid property of a non-Newtonian fluid can include measuring a volumetric flow rate through a flowmeter connected in a main flow passage, measuring a differential pressure across a mass flowmeter in a bypass flow passage, measuring a mass flow rate through the bypass flow passage, and determining the rheological fluid property from the differential pressure and the mass flow rate through the bypass flow passage.
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 47/10 - Localisation des fuites, intrusions ou mouvements du fluide
G01F 1/76 - Dispositifs pour mesurer le débit massique d'un fluide ou d'un matériau solide fluent
G01F 1/84 - Débitmètres massiques du type Coriolis ou gyroscopique
G01F 1/88 - Débitmètres massiques indirects, p. ex. mesurant le débit volumétrique et la densité, la température ou la pression avec mesure de la différence de pression pour déterminer le débit volumétrique
G01N 11/04 - Recherche des propriétés d'écoulement des matériaux, p. ex. la viscosité, la plasticitéAnalyse des matériaux en déterminant les propriétés d'écoulement en mesurant l'écoulement du matériau à travers un passage étroit, p. ex. un tube, une ouverture
90.
DETERMINATION OF NEUTRON POROSITY AND BULK DENSITY FROM A PULSED NEUTRON TOOL
Methods and systems for determining bulk density and/or neutron porosity of a formation are described herein. The methods and systems use a pulsed neutron (PN) tool and may be performed with a tool having a single gamma detector though tools with multiple detectors may be used as well. The PN tool may be a geochemical logging tool. The methods and systems involve partitioning the time spectrum into pluralities of bins that are indicative of non-clay mineral elements and of shale/clay to the overall bulk density.
G01V 5/10 - Prospection ou détection au moyen de rayonnement ionisant, 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
91.
DETERMINATION OF FORMATION WATER SALINITY USING TIME RESOLVED CHLORINE CAPTURE GAMMA SPECTROSCOPY
Methods and systems for determining formation salinity using pulsed neutron (PN) tools are described. Embodiments of the described methods involve binning chlorine yields or chlorine count rates arising from capture events into early and late capture regimes, which may be used to attribute the events to either the borehole or the formation.
G01V 5/10 - Prospection ou détection au moyen de rayonnement ionisant, 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
92.
Extended reach power track tool used on coiled tubing
A traction tool is operable with fluid flow from coiled tubing for use in a wellbore. The traction tool includes a mandrel, a driver, at least one piston, and a motor. The driver is rotatably disposed on the mandrel and can be movable between retracted and extended conditions when the at least one piston is actuated. The driver in the extended condition is configured to engage inside the wellbore. The piston is adjacent to the driver and is actuated by the fluid flow from the mandrel. The motor is also actuated by the fluid flow from the mandrel. The motor imparts rotation to the piston and the drive, which can be supported by bearings on the tool's mandrel. Tracks on the driver arranged at an angle transverse to a longitudinal axis of the tool allow the rotating driver to spiral inside the wellbore and advance the traction tool.
E21B 23/00 - Appareils pour déplacer, mettre en place, verrouiller, libérer ou retirer, les outils, les packers ou autres éléments dans les trous de forage
E21B 4/18 - Ancrage ou avancement dans le trou de forage
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
93.
EXTENDED REACH POWER TRACK TOOL USED ON COILED TUBING
A traction tool (100a) is operable with fluid flow from on coiled tubing (20) for use in a wellbore (10). The traction tool includes a mandrel (102), a driver (110), at least one piston (120a-b), and a motor (140). The driver is rotatably disposed on the mandrel and can be movable between retracted and extended conditions when the at least one piston is actuated. The driver (110) in the extended condition is configured to engage inside the wellbore. The piston (120a-b) is adjacent to the driver and is actuated by the fluid flow from the mandrel. The motor (140) is also actuated by the fluid flow from the mandrel. The motor (140) imparts rotation to the piston and the drive, which can be supported by bearings (129b) on the tool's mandrel. Tracks (116) on the driver arranged at an angel transverse to a longitudinal axis of the tool allow the rotating driver to spiral inside the wellbore and advance the traction tool.
E21B 4/18 - Ancrage ou avancement dans le trou de forage
E21B 17/20 - Tubes de forage flexibles ou articulés
E21B 19/22 - Manipulation de tubes ou de tiges enroulés, p. ex. de tubes de forage flexibles
E21B 23/00 - Appareils pour déplacer, mettre en place, verrouiller, libérer ou retirer, les outils, les packers ou autres éléments dans les trous de forage
E21B 23/14 - Appareils pour déplacer, mettre en place, verrouiller, libérer ou retirer, les outils, les packers ou autres éléments dans les trous de forage pour déplacer un câble ou un outil manœuvré par câble, p. ex. pour les opérations de diagraphie ou de perforation dans les puits déviés
94.
METHOD FOR COUNTING RESTRICTIONS IN A SUBTERRANEAN WELLBORE
A tool counts the number of radial restrictions or seats in a series of frac valves along a completion string. At a pre-selected count, the tool radially expands a landing mechanism and lands on the next-reached frac 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 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 47/01 - Dispositifs pour supporter des instruments de mesure sur des trépans, des tubes, des tiges ou des câbles de forageProtection des instruments de mesure dans les trous de forage contre la chaleur, les chocs, la pression ou similaire
95.
Method for counting restrictions in a subterranean wellbore
A tool counts the number of radial restrictions or seats in a series of frac valves along a completion string. At a pre-selected count, the tool radially expands a landing mechanism and lands on the next-reached frac valve.
E21B 43/26 - Procédés pour activer la production par formation de crevasses ou de fractures
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 47/09 - Localisation ou détermination de la position d'objets dans les trous de forage ou dans les puitsIdentification des parties libres ou bloquées des tubes
A completion string for running gas-lift operations in a hydrocarbon well has a bypass string with a central bore for flowing production fluids to the surface and an annular passageway for flowing gas-lift gas downwards to a gas-lift assembly in the wellbore.
A completion string for running gas-lift operations in a hydrocarbon well, where a portion of the wellbore is compromised and unable to effectively contain gas for a gas-lift operation, has a bypass string with a central bore for flowing production fluids to the surface and an annular passageway for flowing gas-lift gas downwards to a gas-lift assembly in the wellbore.
Systems and methods for diagnosis of a water source of a water production problem in a well include: measuring flow and water/oil ratio (WOR) of a fluid mixture produced from a well; accepting the measured flow and the WOR over a period of time; calculating the derivative in time of WOR (WOR') over the period of time; accepting a selection of or making a comparison of the WOR or WOR' over time to a particular WOR or WOR' case history from a library of WOR and WOR' case histories that correlate with various types of water sources in a library of potential water sources; accepting an additional type of information about the well selected from the group consisting of reservoir properties, completion history, production history, injection history, and interventions history; and weighting and scoring to suggest a diagnosis of a likely water source from the library of potential water sources.
Systems and methods for diagnosis of a water source of a water production problem in a well include: measuring flow and water/oil ratio (WOR) of a fluid mixture produced from a well; accepting the measured flow and the WOR over a period of time; calculating the derivative in time of WOR (WOR′) over the period of time; accepting a selection of or making a comparison of the WOR or WOR′ over time to a particular WOR or WOR′ case history from a library of WOR and WOR′ case histories that correlate with various types of water sources in a library of potential water sources; accepting an additional type of information about the well selected from the group consisting of reservoir properties, completion history, production history, injection history, and interventions history; and weighting and scoring to suggest a diagnosis of a likely water source from the library of potential water sources.
A method of injecting gas into a well can include flowing the gas through a gas flow passage extending through a housing connected to a wellhead installation, the gas thereby flowing through the wellhead installation and into an annulus in the well, and maintaining fluid pressure applied to a piston of a gas injection valve while the gas flows into the annulus. A gas injection system can include a housing having a gas flow passage extending longitudinally through the housing, and being configured to connect to a wellhead installation, and a gas injection valve including a pivotably mounted flapper closure member. The flapper closure member in an open position permits gas flow between the gas flow passage and the wellhead installation, and the flapper closure member in a closed position prevents the gas flow from the wellhead installation through the gas flow passage.
E21B 33/068 - Têtes de puitsLeur mise en place comportant des dispositions pour introduire des objets dans les puits ou pour les en retirer, ou pour y introduire des fluides
E21B 34/02 - Aménagements des vannes pour les trous de forage ou pour les puits dans les têtes de puits
