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Небесная энциклопедия

Космические корабли и станции, автоматические КА и методы их проектирования, бортовые комплексы управления, системы и средства жизнеобеспечения, особенности технологии производства ракетно-космических систем

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Мониторинг СМИ

Мониторинг СМИ и социальных сетей. Сканирование интернета, новостных сайтов, специализированных контентных площадок на базе мессенджеров. Гибкие настройки фильтров и первоначальных источников.

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Применить Всего найдено 2744. Отображено 100.
06-02-2014 дата публикации

Fracturing System and Method

Номер: US20140034294A1
Автор: Hofman Raymond, Jackson Steve, Muscroft William Sloane, Rojas Daniel Jesus
Принадлежит: SUMMIT DOWNHOLE DYNAMICS, LTD.

A system and method comprising at least one ported sleeve assembly and a flapper assembly positioned downwell of the ported sleeve assembly. The system provides for the use of multiple ported sleeve assemblies for each stage of a hydrocarbon producing well that can be opened with a single element, and multiple stages, each have the ability to be opened with a single element size. 1 a housing having a plurality of ports disposed radially therethrough;', 'a first sleeve at least partially within said housing and moveable between a first position and a second position, wherein in said first position said first sleeve is radially positioned between said plurality of ports and said flowpath, said first sleeve having an upper end, a first exterior surface having a first walking jay slot formed therein, and a first engagement surface having a first inner diameter;', 'a first guiding member fixed relative to said housing and positionable within said first walking jay slot; and', 'a first compression spring positioned between said upper end of said first sleeve and said ported housing; and, 'at least one sleeve assembly positionable in said tubing string, said at least one sleeve assembly comprising a flapper seal;', 'a flapper plate rotatable between an opened position and a closed position, wherein in said closed position said flapper plate is engaged against said flapper seal to prevent fluid flow through said flapper seal in a downwell direction;', 'a second sleeve moveable between a first position and a second position, wherein in said first position at least a portion of said second sleeve is radially positioned between said flapper plate and the flowpath, said second sleeve having an upper end, a second exterior surface having a second walking jay slot formed therein, and a second engagement surface having a second inner diameter;', 'a second guiding member fixed relative to said flapper seal and positionable within said second walking jay slot; and', 'a second ...

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Номер записи: 1
01-01-2015 дата публикации

Well Bore Stimulation Valve

Номер: US20150000921A1
Автор: Anton Kenneth J., Harris Michael J.
Принадлежит: Team Oil Tools LP

Stimulation valves for a well tubular having a cylindrical housing adapted for assembly into a tubular for a well. The valves have ports allowing fluid communication between a central conduit and the exterior of the housing and a valve body adapted for movement from a closed position to an open position allowing fluid communication through the ports. A ball seat is mounted in the valve conduit above the ports. The ball seat has an initial ball-catch state in which a ball may be received in the ball seat to move the valve body from its closed position to its open position. The ball seat is adapted to transition to a ball-pass state and release the ball as the valve body is moved to the open position. The ball seat remains in the ball-pass state after the transition from the ball-catch state. 1. A stimulation valve for a well tubular , said stimulation valve comprising:(a) a cylindrical housing adapted for assembly into a tubular for a well and defining a conduit for passage of fluids through said housing and one or more ports allowing fluid communication between said conduit and the exterior of said housing;(b) a valve body adapted for movement from a closed position restricting fluid communication through said ports to an open position allowing fluid communication through said ports; and(c) a ball seat mounted in said valve conduit above said ports, said ball seat having an initial ball-catch state and being operatively connected to said valve body whereby a ball may be received in said ball seat to move said valve body from its closed position to its open position;(d) wherein said ball seat is adapted to transition to a ball-pass state as said valve body is moved from said closed position to said open position whereby said ball may be released from said ball seat after said valve body has moved to its open position; and(e) wherein said ball seat remains in said ball-pass state after said transition from said ball-catch state.2. The stimulation valve of claim 1 , ...

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Номер записи: 2
01-01-2015 дата публикации

MULTI-STAGE WELL SYSTEM AND TECHNIQUE

Номер: US20150000935A1
Автор: Godfrey Matthew, PABON Jahir, ROWATT JOHN DAVID
Принадлежит:

A technique that is usable with a well includes communicating an untethered object in a passageway downhole in the well and using a cross-sectional dimension of the object and an axial dimension of the object to select a seat assembly of a plurality of seat assemblies to catch the object to form an obstruction in the well. 1. A system usable with a well , comprising:a string comprising a passageway;plurality of assemblies disposed on the string such that the passageway extends through the assemblies, the plurality of assemblies comprising a first assembly and a second assembly; andan untethered object adapted to be communicated through the passageway and be sufficiently radially compressed in response to engaging the first assembly to cause the object to pass through the first assembly and having a dimension to cause the object to be engaged by the second assembly to sufficiently restrict radial compression of the object to cause the object to be retained by the second assembly.2. The system of claim 1 , wherein the object comprises a pivot connection and a member to rotate about the pivot connection to radially compress a first part of the object to allow the object to be sufficiently compressed to pass through the first assembly claim 1 , the member is adapted to radially expand a second part of the object in response to the rotation about the pivot connection claim 1 , and the second assembly is adapted to restrict the radial expansion of the second part to restrict radial compression of the object.3. The system of claim 2 , wherein the object has an axial length claim 2 , the first assembly comprises a first seat and a second seat spaced a sufficient distance relative to the axial length to allow the sufficient radial compression of the object claim 2 , and the second assembly comprises a first seat and a second seat spaced a sufficient distance relative to the axial length to cause the sufficient radial restriction of the compression.4. The system of claim 3 , ...

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Номер записи: 3
01-01-2015 дата публикации

BIDIRECTIONAL DOWNHOLE ISOLATION VALVE

Номер: US20150000982A1
Автор: Harrall Simon J., KING Kyle Allen, McDowell Christopher L., Noske Joe
Принадлежит:

An isolation valve for use in a wellbore includes: a tubular housing; an upper flapper disposed in the housing and pivotable relative thereto between an open position and a closed position; an upper piston operable to open or close the upper flapper; a lower flapper disposed in the housing and pivotable relative thereto between an open position and a closed position; a lower piston operable to open the lower flapper; an opener passage in fluid communication with the pistons and an opener hydraulic coupling; and a closer passage in fluid communication with the pistons and a closer hydraulic coupling. 1. An isolation valve for use in a wellbore , comprising:a tubular housing;an upper flapper disposed in the housing and pivotable relative thereto between an open position and a closed position;an upper piston operable to open or close the upper flapper;a lower flapper disposed in the housing and pivotable relative thereto between an open position and a closed position;a lower piston operable to open the lower flapper;an opener passage in fluid communication with the pistons and an opener hydraulic coupling; anda closer passage in fluid communication with the pistons and a closer hydraulic coupling.2. The isolation valve of claim 1 , wherein the upper flapper opens upwardly and the lower flapper opens downwardly.3. The isolation valve of claim 2 , further comprising:an opener detent operable to resist opening of the lower flapper; anda closer detent operable to resist closing of the upper flapper.4. The isolation valve of claim 3 , wherein each detent comprises:a choke passage having a flow restrictor disposed therein; anda bypass passage having a check valve disposed therein.5. The isolation valve of claim 3 , further comprising:an upper flapper spring biasing the upper flapper toward the open position,wherein the upper piston is operable to close the upper flapper.6. The isolation valve of claim 5 , wherein lower ends of the opener and closer passages are located above ...

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Номер записи: 4
05-01-2017 дата публикации

DOWNHOLE ACTUATION BALL, METHODS AND APPARATUS

Номер: US20170002628A1
Автор: Emerson John Lee, van Petegem Ronald
Принадлежит:

An actuation ball for a downhole tool, the actuation ball includes an outer annular body encircling a bore; and a core releasably installed in the bore, such that the core can be removed to permit back flow through the bore. 1. An actuation ball for a downhole tool , the actuation ball comprising:a core;an outer body through which fluid can flow if the core is removed; anda mechanical connection between the core and the outer body, the mechanical connection configured to permit separation of the core from the outer body.2. The actuation ball of wherein the mechanical connection is configured to hold the core in the body for actuation of the downhole tool and to permit separation of the core from the outer body after actuation of the downhole tool.3. The actuation ball of wherein the actuation ball has a leading end and a trailing end and the core has a forward end exposed on the outer surface of the leading end and the core has a piston face end exposed on the trailing end and the mechanical connection is configured to hold the core in the outer body against dislodgement towards the leading end while permitting separation of the core from the outer body by movement of the core towards the trailing end.4. The actuation ball of wherein the mechanical connection is configured to permit separation of the core from the outer body in response to a force applied against the forward end that is greater than a second force applied against the piston face end.5. The actuation ball of wherein mechanical connection is a snap connection.6. The actuation ball of wherein the mechanical connection is a wedge lock connection.7. The actuation ball of wherein the outer body has a bore extending therethrough and the bore has a tapering inner diameter that tapers from a trailing end toward a leading end; the core has tapering side walls that fit within bore and define an outer diameter that substantially matches the tapering inner diameter; and a seal formed between the frustoconical ...

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Номер записи: 5
05-01-2017 дата публикации

DETECTION AND MITIGATION OF DETRIMENTAL OPERATING CONDITIONS DURING PUMPJACK PUMPING

Номер: US20170002636A1
Автор: II Victor, Sauers, Williams Bertrand Jeffery
Принадлежит:

A motor-driven pumpjack is operated continuously while receiving sensory feedback from one or more sensors. In response to feedback indicating a detrimental operating condition, and while continuing to operate the pumpjack, one or more speed adjustments are made to specific control periods within the motor pumping cycle. The automated control optimizes flow while reacting to detrimental and changing conditions. 1. A method of operating a pumpjack continuously over a sequence of pump stroke cycles , the method comprising:energizing an electric motor to operate the pumpjack over a first pump stroke cycle, according to a first motor speed profile comprising a plurality of target motor speeds corresponding to each of a plurality of discrete control periods within the first pump stroke cycle;receiving sensory feedback during the first pump stroke cycle from one or more sensors mounted to monitor at least one operating condition of the pumpjack, the sensory feedback comprising data collected during operation of the motor according to the first motor speed profile;detecting, while continuing to operate the pumpjack, a detrimental operating condition within the first pump stroke cycle based on the sensory feedback;in response to detecting the detrimental operating condition, determining one or more speed adjustment values corresponding to a limited subset of the plurality of discrete control periods;altering the first motor speed profile based on the one or more adjustment values to provide a second motor speed profile; andoperating the electric motor over a second pump stroke cycle, according to the second motor speed profile.2. The method of claim 1 , wherein the first motor speed profile comprises a predetermined default setting.3. The method of claim 1 , wherein the first motor speed profile comprises an altered version of a motor speed profile utilized in a previous pump stroke cycle of the sequence.4. The method of claim 1 , wherein the plurality of discrete control ...

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Номер записи: 6
05-01-2017 дата публикации

HEAVY OIL SAMPLING METHODS AND SYSTEMS

Номер: US20170002655A1
Автор: Ayyad Hazim, Jamal Sarah
Принадлежит:

The present disclosure relates to a formation sampling method that includes disposing a downhole tool that has an expandable packer and an extendable probe within a wellbore disposed in a subterranean formation, pumping formation fluid into the downhole tool through the extendable probe to move heavy oil from within the subterranean formation towards the wellbore, detecting arrival of the heavy oil at the wellbore, and performing formation sampling with the expandable packer in response to detecting the arrival of the heavy oil at the wellbore. 1. A formation sampling method comprising:disposing a downhole tool comprising an expandable packer and an extendable probe within a wellbore disposed in a subterranean formation;pumping formation fluid into the downhole tool through the extendable probe to move heavy oil from within the subterranean formation towards the wellbore;detecting arrival of the heavy oil at the wellbore; andperforming formation sampling with the expandable packer in response to detecting the arrival of the heavy oil at the wellbore.2. The formation sampling method of claim 1 , wherein comprising confirming a presence of mobile heavy oil within the subterranean formation prior to disposing the downhole tool within the wellbore.3. The formation sampling method of claim 2 , wherein confirming the presence of mobile heavy oil comprises performing a combination of NMR scanning and dielectric scanning.4. The formation sampling method of claim 2 , wherein disposing the downhole tool within the wellbore comprises conveying the downhole tool within the wellbore to dispose the extendable probe at a location in the wellbore corresponding to the presence of mobile heavy oil.5. The formation sampling method of claim 1 , comprising monitoring properties of the formation fluid within the downhole tool while pumping the formation fluid into the downhole tool through the extendable probe.6. The formation sampling method of claim 5 , wherein monitoring properties of ...

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Номер записи: 7
07-01-2016 дата публикации

INFLATABLE SEAL WITH FABRIC EXPANSION RESTRICTION

Номер: US20160002995A1
Автор: Burns Timothy Vincent, Naedler Mark Henry, Sheely Brett Thomas
Принадлежит:

A diverter flowline seal assembly for use in subsea drilling. The seal assembly includes a seal body having an inner diameter end and an outer diameter end formed of an inflatable elastomeric material having a first modulus. The inner diameter end of the seal body includes two diametrically opposed axially inward lip portions and two diametrically opposed axially outward base portions. Integrated with the inflatable elastomeric material at the base portions of the inner diameter end of the seal body is a material having a modulus that is higher than the modulus of the inflatable elastomeric material so as to prevent the radial expansion of the lip portions and the base portions of the inner diameter end of the seal body. 1. A sealing assembly comprising:a generally C-shaped seal body having an inner diameter end and an outer diameter end formed of an inflatable elastomeric material having a first modulus, wherein the inner diameter end of the seal body includes diametrically opposed axially inward lip portions and diametrically opposed axially outward base portions; andat least one layer of a reinforcing material having a second modulus bonded to the axially outward base portions of the seal body, the second modulus being higher than the first modulus;wherein the at least one layer of a reinforcing material prevents radial expansion of the axially inward lip portions and the axially outward base portions of the inner diameter end of the seal body; andwherein the outer diameter end of the seal body is free to expand radially.2. The sealing assembly of claim 1 , wherein the seal body and the at least one layer of a reinforcing material do not include any metallic components.3. The sealing assembly of claim 1 , wherein the reinforcing material is a fabric comprising a material selected from the group consisting of cotton fibers claim 1 , carbon fibers claim 1 , nylon fibers claim 1 , polyester fibers claim 1 , aramid fibers claim 1 , fiberglass and a metallic band.4. ...

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Номер записи: 8
07-01-2016 дата публикации

INTERVENTIONLESS DOWNHOLE SCREEN AND METHOD OF ACTUATION

Номер: US20160003002A1
Автор: Aitken Liam Andrew
Принадлежит:

An interventionless downhole screen that is resistant to plugging during run-in-hole operations and a method for remotely actuating the screen. The screen includes a perforated sleeve that is slideably disposed coaxially with a perforated tubular member. When running, the sleeve is in a closed positioned with its openings offset from the apertures in the tubular member, thereby blocking flow through the screened openings, while a check valve through the tubular member allows fluid ingress. To actuate for production, the tubular member is pressurized, which moves a piston into ratcheting engagement with the sleeve. A subsequent depressurization allows the piston to return to its original position, carrying with it the sleeve to an open position where the sleeve and tubing perforations are aligned for allowing fluid flow into the tubular member. 1. A downhole tool comprising:a tubular member with a wall defining an interior and an exterior, said wall having an aperture formed therethrough;a sleeve coaxially disposed so as to abut and be in sliding engagement with said tubular member, said sleeve having a wall with an opening formed therethrough; andan actuator coupled between said tubular member and said sleeve and arranged to move said sleeve with respect to said tubular member from a shut position where said opening is offset from said aperture thereby substantially restricting fluid communication between said opening and said aperture and an open position where said opening and said aperture are aligned so as to permit fluid communication therebetween.2. The downhole tool of further comprising:a mesh disposed so as to filter flow from said exterior to said interior through said aperture.3. The downhole tool of wherein:in said shut position, said opening is radially aligned with but axially offset from said aperture.4. The downhole tool of wherein:said sleeve is disposed about the exterior of said tubular member.5. The downhole tool of wherein:said actuator is ...

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Номер записи: 9
07-01-2016 дата публикации

TOOLS AND METHODS FOR USE IN COMPLETION OF A WELLBORE

Номер: US20160003003A1
Автор: Getzlaf Donald, Nipper Robert, Stromquist Marty, Willems Timothy H.
Принадлежит:

A ported tubular is provided for use in casing a wellbore, to permit selective access to the adjacent formation during completion operations. A system and method for completing a wellbore using the ported tubular are also provided. Ports within the wellbore casing may be opened, isolated, or otherwise accessed to deliver treatment to the formation through the ports, using a tool assembly deployed on tubing or wireline. 1. A method for shifting a sliding sleeve in a wellbore , comprising: providing a valve continuous with a wellbore tubular , the valve comprising a ported housing and a port closure sleeve slidably disposed within the ported housing; providing a tool assembly comprising: a locating device and a resettable sealing member; deploying the tool assembly within the wellbore on wireline; locating the resettable sealing assembly within the port closure sleeve; setting the sealing member across the sliding sleeve; and applying a downward force to the sealing member to slide the sleeve with respect to the ported housing.2. The method as in claim 1 , wherein the step of setting the sealing member comprises application of a radially outward force with the sealing member to the sleeve so as to frictionally engage the sleeve with the sealing member.3. The method as in claim 2 , wherein the sleeve comprises an inner surface of uniform diameter along its length claim 2 , free of any profile.4. The method as in claim 2 , wherein the sleeve has an inner diameter consistent with the inner diameter of the wellbore tubular.5. The method as in claim 1 , wherein the step of applying a downward force to the sealing member comprises delivering fluid to the wellbore to increase the hydraulic pressure above the sealing member.6. The method as in claim 5 , wherein the port closure sleeve is initially retained in a closed position with respect to the ported housing by a hydraulic pressure above the sealing member generated by the fluid delivery is sufficient to exceed a threshold ...

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Номер записи: 10
07-01-2016 дата публикации

PRESSURE EQUALIZATION FOR DUAL SEAT BALL VALVE

Номер: US20160003004A1
Автор: Inglis Peter D. W., Robb Ewan Ogilvie
Принадлежит: Halliburton Energy Services, Inc.

A ball valve comprising a housing comprising a fluid passage, a first seat surface, a second seat surface, and a ball rotatably movable within the housing between an open position allowing flow through the fluid passage of the housing and a closed position preventing flow through the fluid passage of the housing, wherein the ball contacts the first seat surface and the second seat surface to form one or more seals within the ball valve, wherein the ball comprises a fluid passage and a fluid path, wherein the fluid path fluidly connects a space between the first seat surface and the second seat surface with the fluid passage of the housing, with the fluid passage of the ball, or both, when the ball is in the open position. 1. A ball valve comprising:a housing comprising a fluid passage;a first seat surface;a second seat surface; anda ball rotatably movable within the housing between an open position allowing flow through the fluid passage of the housing and a closed position preventing flow through the fluid passage of the housing, wherein the ball contacts the first seat surface and the second seat surface to form one or more seals within the ball valve, wherein the ball comprises a fluid passage and a fluid path, wherein the fluid path fluidly connects a space between the first seat surface and the second seat surface with the fluid passage of the housing, with the fluid passage of the ball, or both, when the ball is in the open position.2. The ball valve of claim 1 , wherein the fluid path comprises a hole formed in the ball.3. The ball valve of claim 1 , wherein the fluid path comprises a groove formed on a surface of the ball.4. The ball valve of claim 1 , further comprising:a seat member associated with the first seat surface and the second seat surface, wherein the first seat surface and the second seat surface are fixed relative to each other.5. The ball valve of claim 4 , further comprising a biasing device arranged to bias the first seat surface claim 4 , ...

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Номер записи: 11
05-01-2017 дата публикации

ELECTRICALLY ACTUATED SAFETY VALVE AND METHOD

Номер: US20170002945A1
Автор: Phelps Nicholas Brandon
Принадлежит: BAKER HUGHES INCORPORATED

An electrically actuated safety valve includes a flapper. A flow tube in operable communication with the flapper; an electric actuation system including an electric holding configuration connecting a prime mover to the flow tube. A method for operating a safety valve. 1. An electrically actuated safety valve comprising:a flapper;a flow tube in operable communication with the flapper;an electric actuation system including an electric holding configuration connecting a prime mover to the flow tube.2. The safety valve as claimed in wherein the electric holding configuration is a solenoid assembly.3. The safety valve as claimed in wherein the solenoid assembly comprises a collet and a collet sleeve.4. The safety valve as claimed in wherein the solenoid assembly includes a spring.5. The safety valve as claimed in further including a flow tube rod that is pressure balanced.6. The safety valve as claimed in wherein the electric actuation system comprises:a motor;a follower operatively attached to the motor;a shaft translatable in the follower and in operable communication with the electric holding configuration.7. The safety valve as claimed in further including a piston ring claim 6 , the ring including a feature configured to interact with the electric holding configuration.8. The safety valve as claimed in wherein the feature is a nipple.9. The safety valve as claimed in wherein a chamber in which the electric actuation system is housed is volume balanced.10. A method for operating a safety valve comprising:powering an electric holding configuration;rotating an electric motor and linear actuator operably attached to the electric holding configuration;translating the electric holding configuration;translating a piston ring with the electric holding configuration; to open or close a flapper of the safety valve.11. The method as claimed in further including automatically releasing the piston ring from the electric holding configuration upon interruption of power to the ...

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Номер записи: 12
04-01-2018 дата публикации

Customized Drilling Tools

Номер: US20180002986A1
Автор: Gan Xiaoge, SONG Huimin, Zhang Youhe
Принадлежит:

A bit includes a bit body having at least one blade coupled to the bit body. The blade has a plurality of cutting elements at a nose region and a shoulder region of the blade. A plurality of fluid outlets are positioned on the blade such that at least 30% of the cutting elements have a fluid outlet within a distance that is two or three times a cutting element diameter away from a cutting face of the cutting element. 1. A bit for removing material from a formation , the bit comprising:a bit body;a blade coupled to the bit body, the blade defining a nose region and a shoulder region;a plurality of cutting elements coupled to the blade in the nose region and the shoulder region, at least one cutting element of the plurality of the cutting elements having a cutting face having a diameter; anda plurality of fluid outlets, the plurality of fluid outlets positioned such that at least 30% of the plurality of cutting elements have at least one fluid outlet positioned an outlet distance equal to or less than three times the diameter of the cutting element away from the cutting face of the at least one cutting element.2. The bit of claim 1 , further comprising a nozzle positioned in the bit body.3. The bit of claim 1 , the bit having three or fewer primary blades.4. The bit of claim 1 , the plurality of cutting elements being arranged at least in a row of primary cutting elements on the blade and at least one row of secondary cutting elements on the blade claim 1 , the at least one row of secondary cutting elements positioned rotationally behind the row of primary cutting elements.5. The bit of claim 4 , at least one fluid outlet of the plurality of fluid outlets being positioned between the row of primary cutting elements and the at least one row of secondary cutting elements.6. The bit of claim 1 , at least 10% of the fluid outlets being positioned an outlet distance equal to or less than 50% the diameter of the cutting element away from the cutting face of at least one of ...

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Номер записи: 13
04-01-2018 дата публикации

Apparatus for Switching off and Deviating A Circulating Liquid Flow without Water Hammering

Номер: US20180002996A1
Автор: Peveri Luigi, Silva Gian Marco
Принадлежит:

An apparatus for switching off and deviating a circulating liquid flow without water hammering, comprising an apparatus body () including an inlet channel () which is split into two outlet channels () in which respective flow valves () are arranged; said apparatus body comprises moreover a discharging channel () coupled to said outlet channels through respective discharging valves (); said outlet channels being moreover coupled to respective pressure measuring chambers (); a balancing valve () communicating two middle zones () respectively formed in the outlet channels. 1. An apparatus for switching off and deviating a circulating liquid flow without water hammering , characterized in that said apparatus comprises an apparatus body including an inlet channel whith is split into two outlet channels in which respective flow valves are arranged; said apparatus body comprises moreover a discharging channel coupled to said outlet channels through respective discharging valves; said outlet channels being moreover coupled to respective pressure measuring chambers; a balancing valve communicating two middle zones respectively formed in the outlet channels.2. An apparatus claim 1 , according to claim 1 , characterized in that said valves split an inner space of said apparatus body into four zones claim 1 , the two flow valves communicating with a delivery zone claim 1 , the balancing valve communicating the middle zones with one another claim 1 , and the two discharging valves communicating with the discharging zone.3. An apparatus claim 1 , according to claim 1 , characterized in that said apparatus comprises a central control unit for driving and controlling the operation of said valves as well as of pressure switches associated with the pressure measuring chambers.4. An apparatus claim 1 , according to claim 1 , characterized in that said apparatus is connected in series in a main mud circulating line coupled upstream of a probe manifold claim 1 , without modifying or ...

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Номер записи: 14
04-01-2018 дата публикации

Methods and systems for stimulating and restimulating a well

Номер: US20180003003A1
Автор: Peter Kris Cleven
Принадлежит: Individual

Embodiments disclosed herein describe fracturing methods and systems, wherein pressure differentials and fluid flow rates may be utilized to stimulate multiple zones, sleeves, or ports with the same tool.

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Номер записи: 15
04-01-2018 дата публикации

MULTI-ZONE FRACTURING WITH FULL WELLBORE ACCESS

Номер: US20180003004A1
Автор: Merron Matt James, Norman Tyler J., WALTON Zachary W.
Принадлежит:

A system and method for fracturing multiple zones along a length of a wellbore during a single run are provided. A single magnetic shifter device may be lowered on coiled tubing to shift open multiple sleeve assemblies set along the wellbore to expose different fracture zones for desired fracturing treatments. The sleeve assemblies may each include a magnetic sensing system designed to detect a magnetic field output from the shifter device. The magnetic sensing system may output a control signal to an electro-hydraulic lock to collapse a baffle component of the sleeve assembly. Once the baffle is collapsed, an isolation component of the shifter device may engage the collapsed baffle to form a plug through the wellbore. Pressure applied from the surface may push the baffle and a sliding sleeve of the sleeve assembly downward, thereby exposing fracturing ports through the casing of the wellbore. 1. A sleeve assembly for use in a wellbore , the sleeve assembly comprising:a magnetic sensor system for detecting a magnetic field output from a magnetic shifting device moving through the sleeve assembly;a collapsible baffle that is moveable from a radially open position to a radially collapsed position in response to the magnetic sensing system detecting the magnetic field from the magnetic shifting device, wherein the radially collapsed position is sized for receiving an isolation component moving through the sleeve assembly; anda sliding sleeve disposed adjacent the collapsible baffle and moveable to expose ports for providing access to a formation from inside the wellbore, in response to force from the isolation component engaged with the collapsible baffle.2. The sleeve assembly of claim 1 , further comprising:an oil chamber piston sleeve disposed partially in a chamber, wherein the oil chamber piston sleeve is moveable through the chamber in response to a release of hydraulic fluid into the chamber; andan electro-hydraulic lock for releasing hydraulic fluid into the ...

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Номер записи: 16
04-01-2018 дата публикации

Downhole Shifting Tool

Номер: US20180003005A1
Автор: Conaway Seth Alan, Dorban Andrew, Huh Michael
Принадлежит:

A downhole tool includes a deactivation member, a latching member, a release member, and a biasing member. The deactivation member includes an outer protrusion. The latching member is positioned radially-outward from the deactivation member. The latching member includes an inner protrusion and an outer protrusion. The release member includes a sleeve extending axially toward the outer protrusion of the latching member. The biasing member exerts an axial force on the latching member. 1. A downhole tool , comprising:a deactivation member comprising an outer protrusion;a latching member positioned radially-outward from the deactivation member, wherein the latching member comprises an inner protrusion and an outer protrusion;a release member comprising a sleeve extending axially toward the outer protrusion of the latching member; anda biasing member configured to exert an axial force on the latching member.2. The downhole tool of claim 1 , wherein the latching member is configured to move from a first position to a second position with respect to the deactivation member claim 1 , wherein the inner protrusion of the latching member is on a first side of the outer protrusion of the deactivation member when the latching member is in the first position claim 1 , and wherein the inner protrusion of the latching member is on a second side of the outer protrusion of the deactivation member when the latching member is in the second position.3. The downhole tool of claim 2 , wherein the axial force exerted on the latching member is greater when the latching member is in the second position than when the latching member is in the first position.4. The downhole tool of claim 3 , wherein the axial force pushes the latching member toward the first position.5. The downhole tool of claim 2 , wherein the outer protrusion of the deactivation member comprises a first face that faces a first face of the inner protrusion of the latching member when the latching member is in the first ...

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Номер записи: 17
04-01-2018 дата публикации

HIGH FLOW INJECTION SCREEN SYSTEM WITH SLEEVES

Номер: US20180003010A1
Автор: Davis Jason Earl, Richards William Mark
Принадлежит:

An apparatus has been described, including a tubular housing including opposing first and second end portions and defining an interior surface, an exterior surface, and an internal flow passage; an open inflow area extending radially through the tobular housing and adapted to distribute the radial flow of a fluid from the internal flow passage to the wellbore; a closure member extending within the tubular housing and adapted to cover the open inflow area; and a filter defining a plurality of gaps, the filter concentrically disposed about the exterior surface of the tubular housing and extending axially along at least the open inflow area. In an exemplary embodiment, the open inflow area includes a plurality of openings formed radially through the tubular housing and defining a tubular injection interval extending axially along the tubular housing. A system and assembly have also been described, each incorporating elements of the above described apparatus. 1. An apparatus adapted to extend within a wellbore that traverses a subterranean formation , the apparatus comprising:a tubular housing comprising opposing first and second end portions and defining an interior surface, an exterior surface, and an internal flow passage;an open inflow area extending radially through the tubular housing and adapted to distribute the radial flow of a fluid from the internal flow passage to the wellbore;a closure member extending within the tubular housing and adapted to cover the open inflow area; anda filter defining a plurality of gaps, the filter concentrically disposed about the exterior surface of the tubular housing and extending axially along at least the open inflow area.2. The apparatus of claim 1 , wherein the open inflow area comprises a plurality of openings formed radially through the tubular housing;wherein the plurality of openings define a tubular injection interval extending axially along the tubular housing, the tubular injection interval having a length; andwherein ...

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Номер записи: 18
04-01-2018 дата публикации

Downhole Communications Using Selectable Frequency Bands

Номер: US20180003041A1
Автор: Roberson Mark W.
Принадлежит:

A system that is positionable in a wellbore in a subterranean formation can include a first transceiver that is positionable external to a casing string in the wellbore. The first transceiver can wirelessly transmit data via a signal within a frequency band that is selected based on a fluid property of a fluid in the wellbore and a property of the subterranean formation. The system can also include a second transceiver that is positionable externally 1. A system that is positionable in a wellbore in a subterranean formation , the system comprising:a first transceiver that is positionable external to a casing string in the wellbore for wirelessly transmitting data via a signal within a frequency band that is selected based on a fluid property of a fluid in the wellbore and a property of the subterranean formation; anda second transceiver that is positionable externally the casing string and operable to receive the signal.2. The system of claim 1 , wherein the first transceiver is operable to transmit the data via the signal and via another signal within another frequency band substantially simultaneously.3. The system of claim 1 , wherein the fluid comprises a combination of a wellbore servicing fluid and a formation fluid.4. The system of claim 1 , wherein the first transceiver comprises:a processing device; and receive a sensor signal from a sensor;', 'determine the fluid property based on the sensor signal;', 'determine the property of the subterranean formation based on the sensor signal; and', 'select the frequency band based on the fluid property and the property of the subterranean formation by consulting a lookup table stored in the memory device in which a plurality of fluid properties and a plurality of subterranean formation properties are mapped to a plurality of frequency bands., 'a memory device in which instructions executable by the processing device are stored for causing the processing device to5. The system of claim 1 , wherein the first ...

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Номер записи: 19
04-01-2018 дата публикации

SYSTEM AND METHODS FOR PRETESTS FOR DOWNHOLE FLUIDS

Номер: US20180003049A1
Автор: Gisolf Adriaan, Palaghita Tudor Ioan, Parks Stephen Dennis, Partouche Ashers
Принадлежит:

A method including positioning a downhole acquisition tool in a wellbore in a geological formation; performing a pretest sequence to gather at least one of pressure or mobility information based on downhole acquisition from a sample line, a guard line, or both while the downhole acquisition tool is within the wellbore. The pretest sequence includes controlling a valve assembly to a first valve configuration that may allow the fluid to flow into the downhole tool via one or more flowlines toward a pretest system. The one or more flowlines include the sample line only, the guard line only, or both the sample line and the guard line; and drawing in the fluid through the one or more flowlines. The method also includes controlling the valve assembly to a second valve configuration. The second valve configuration is different from the first valve configuration and may block the one or more flowlines from drawing in the fluid. 1. A method comprising:positioning a downhole acquisition tool in a wellbore in a geological formation; controlling a valve assembly to a first valve configuration that enables the fluid to flow into the downhole tool via one or more flowlines toward a pretest system, wherein the one or more flowlines comprises the sample line only, the guard line only, or both the sample line and the guard line; and drawing in the fluid through the one or more flowlines; and', 'controlling the valve assembly to a second valve configuration, wherein the second valve configuration is different from the first valve configuration and is configured to block the one or more flowlines from drawing in the fluid., 'performing a pretest sequence to gather at least one of pressure or mobility information based on downhole acquisition from a sample line, a guard line, or both while the downhole acquisition tool is within the wellbore, wherein the pretest sequence comprises2. The method of claim 1 , wherein drawing in the fluid comprises using a pump to draw in the fluid.3. The ...

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Номер записи: 20
02-01-2020 дата публикации

REVERSE-CIRCULATION DRILLING ASSEMBLIES AND METHODS OF USING SAME

Номер: US20200003021A1
Автор: Drenth Christopher L., Lachance Anthony
Принадлежит:

A reverse-circulation drilling assembly having an overshot subassembly and a head subassembly. In the event retrieval of the drilling assembly by reverse-circulation fails, the drilling assembly can be retrieved using a secondary overshot. 1. A reverse-circulation drilling assembly having a longitudinal axis and comprising:an overshot subassembly having a proximal portion, a distal portion, and a check valve assembly positioned axially between the proximal and distal portions, wherein the distal portion comprises a latch assembly; anda head subassembly having a latch assembly, a valve assembly, and a proximal portion that defines a receptacle configured to receive a portion of the distal portion of the overshot subassembly, wherein the proximal portion of the head subassembly further comprises a latch retracting case that is configured for axial movement relative to the longitudinal axis to effect movement of the latch assembly about and between a retracted position and a deployed position in which the latch assembly engages an inner surface of a drill string, wherein the latch retracting case is coupled to the valve assembly and configured to effect movement of the valve assembly about and between a closed position and an open position that permits fluid flow through the head subassembly,wherein the latch assembly of the overshot subassembly is configured for movement from a retracted position to a deployed position to engage the proximal portion of the head subassembly when the distal portion of the overshot subassembly is received within the receptacle, andwherein the check valve assembly of the overshot subassembly is biased to the closed position and configured to move from the closed position to the open position upon landing of the drilling assembly within a borehole.2. The reverse-circulation drilling assembly of claim 1 , wherein the latch retracting case of the head subassembly is configured to effect movement of the check valve assembly to the open ...

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Номер записи: 21
02-01-2020 дата публикации

APPARATUS, SYSTEMS, AND METHODS FOR FRACTURING A GEOLOGICAL FORMATION

Номер: US20200003038A1
Автор: Anders Edward O.
Принадлежит:

The present disclosure relates, according to some embodiments, to apparatus, systems, and methods of fracturing a geological structure including the application of kinetic energy (e.g., from high velocity frack fluid) to a subterranean structure. In some embodiments, the present disclosure relates to apparatus, systems, and methods for delivery of high velocity fluid to a well using a down hole valve and/or throttling system. The present disclosure relates to apparatus, systems, and methods of generating pressure using accumulators (e.g., high pressure accumulators) at the surface of a well. 119-. (canceled)20. A method of kinetically fracking a subterranean structure , the method comprising: (i) providing a fracking fluid at a pressure of about 8,000 psi to about 15,000 psi, wherein the fracking fluid is substantially free of proppant;', '(ii) adding at least one proppant to the fracking fluid; and', '(iii) injecting the fracking fluid with proppant into the interior channel;, '(a) providing a fracking string inside a perforated wellbore liner having an interior cavity, the fracking string having an interior channel and spaced-apart apertures connecting the interior string channel and the liner cavity, comprising the steps of(b) accelerating the fracking fluid in the interior channel in a downhole direction to a velocity of from about 10 to about 150 feet per second; and(c) abruptly decelerating fracking fluid flow.21. A method of kinetically fracking a subterranean structure according to claim 20 , wherein the fracking fluid is provided in an overburdened pressure zone at a pressure of about 15 claim 20 ,000 psi.22. A method of kinetically fracking a subterranean structure according to claim 20 , further comprising repeating steps (b) and (c).23. A method of kinetically fracking a subterranean structure according to claim 20 , wherein abruptly decelerating fracking fluid flow further comprises closing the string apertures claim 20 , sealing the interior liner ...

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Номер записи: 22
07-01-2016 дата публикации

Non-electronic air chamber pressure sensor

Номер: US20160003701A1
Автор: Paul David Ringgenberg
Принадлежит: Halliburton Energy Services Inc

An apparatus for use in a wellbore having a housing having at least one chamber capable of receiving a fluid, a sealed annular volume, and a non-electronic pressure sensor disposed in the sealed annular volume. The non-electronic sensor includes a sealed, compressible container. Positioned within the sealed, compressible container are first and second magnets that are separated by a first distance when a fluid within the sealed annular volume is at a first pressure. When the fluid in the sealed annular volume is at a second pressure, the first and second magnets are separated by a second distance.

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Номер записи: 23
07-01-2021 дата публикации

DRILL STEM TESTING

Номер: US20210003003A1
Автор: Alipour Kallehbasti Mehdi, Jones Christopher Michael, LeBlanc Michel Joseph, Proett Mark Anton, Van Zuilekom Anthony Herman
Принадлежит:

Systems and techniques for determining properties of a formation comprising are disclosed. A test tool attached to test string comprising a fluid conduit is deployed to a test position within a wellbore. The deployment includes hydraulically isolating a portion of the wellbore proximate the test tool to form an isolation zone containing the test position. A fluid inflow test is performed within the isolation zone and an initial formation property and a fluid property are determined based on the fluid inflow test. A fluid injection test is performed within the isolation zone including applying an injection fluid through the test string into the isolation zone, wherein the flow rate or pressure of the injection fluid application is determined based, at least in part, on the at least one of the formation property and fluid property, The fluid injection test further includes measuring pressure within the isolation zone to determine a pressure transient associated with the injection of the injection fluid. A property of the formation is determined based on the determined pressure transient. 1. A method for determining properties of a formation comprising:performing a fluid inflow test within an isolation zone of a wellbore;determining a first formation property based, at least in part, on the fluid inflow test; and applying an injection fluid into the isolation zone, wherein a flow parameter for the injection fluid application is determined based, at least in part, on the first formation property; and', 'measuring pressure within the isolation zone to determine a pressure transient associated with the application of the injection fluid., 'performing a fluid injection test within the isolation zone including2. The method of claim 1 , further comprising determining a second formation property based on the determined pressure transient.3. The method of claim 2 , wherein said determining a second formation property comprises determining at least one of a formation flow ...

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Номер записи: 24
03-01-2019 дата публикации

Tool Assembly and Process for Drilling Branched or Multilateral Wells with Whip-Stock

Номер: US20190003258A1
Автор: Klam Kyle, Lewis John Chute
Принадлежит: Modern Wellbore Solutions Ltd.

Downhole tool assembly comprises a whipstock engageable with a flow control device. The whipstock comprises a channel. A core is removably mounted in the channel. The flow control device comprises a valve with a shiftable sleeve for selectively directing fluid flow. In a process of drilling and operating a branched well, the whipstock is anchored at a junction in a first well. A second well is drilled from the junction in a direction defined by the work face of the whipstock. After drilling, the core is removed to open the channel in the whipstock. The valve can be set to direct fluid flow to the second well so a fluid pressure can be applied to the second well. The valve can also be set to direct fluid flow through the channel to the first well, so a fluid pressure can be applied to the first well. 1. A downhole tool assembly for drilling and operating a branched well , the assembly comprising: 'a whipstock body having a channel defined therethrough and comprising a first coupling structure, and', 'a whipstock comprising'} a second coupling structure for coupling with the first coupling structure to engage the whipstock body, and', 'a valve comprising a shiftable sleeve for selectively directing fluid flow to the branched well or to the channel in the whipstock body when the first and second coupling structures are coupled to each other., 'a flow control device comprising, 'a core removably mounted in the channel, the core having a work face for orienting a drill to drill the branched well; and'}2. The assembly of claim 1 , wherein the valve is a hydraulically or mechanically-actuated valve and comprises:a tubular body defining a conduit connecting an input port to a first output port and a second output port, wherein the second output port is configured to be in flow communication with the channel in the whipstock body when the first and second coupling structures are coupled to each other, wherein the shiftable sleeve is mounted in the conduit and is actuatable ...

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Номер записи: 25
03-01-2019 дата публикации

Fixed Cutter Drill Bits Including Nozzles with End and Side Exits

Номер: US20190003262A1
Автор: Bradford, III John Francis, Omidvar Navid, Rahmani Reza
Принадлежит: National Oilwell DHT, L.P.

A drill bit includes a bit body and an internal plenum in the bit body. In addition, the drill bit includes a first flow passage extending from the internal plenum to a bit face. Still further, the drill bit includes a nozzle assembly secured to the bit body at a downhole end of the flow passage. The nozzle assembly has a central axis and includes an outer sleeve and an inner nozzle extending axially through the outer sleeve. The inner nozzle has a first end, a second end opposite the first end, and a radially inner surface extending axially from the first end to the second end. The radially inner surface defines a second flow passage. The inner nozzle also includes a choke disposed along the second flow passage and a side outlet extending radially from the outer surface to the inner surface. 1. A drill bit for drilling a borehole in earthen formations , the bit having an uphole end and a downhole end , the bit comprising:a bit body having a bit face disposed at the downhole end;an internal plenum extending from the uphole end into the bit body;a first flow passage extending from the internal plenum to the bit face;a nozzle assembly secured to the bit body at a downhole end of the first flow passage, wherein the nozzle assembly is configured to distribute drilling fluid about the bit face; an outer sleeve;', 'an inner nozzle extending axially through the outer sleeve, wherein the inner nozzle has a first end, a second end opposite the first end, a radially outer surface extending axially from the first end to the second end, and a radially inner surface extending axially from the first end to the second end;', 'wherein the radially inner surface defines a second flow passage extending axially from the first end to the second end, wherein the second flow passage has an inlet at the first end and an outlet at the second end;', a choke disposed along the second flow passage;', 'a side outlet extending radially from the radially outer surface to the radially inner ...

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Номер записи: 26
03-01-2019 дата публикации

Manual Pipe Valve Connector for Jointed Pipe Connections with Quick Release Check Valve Assembly and Uses Thereof

Номер: US20190003265A1
Автор: McLaughlin Stuart
Принадлежит:

The present invention provides a novel clutch connector assembly for jointed pipe, threaded pipe, coiled tubing or any threaded or non-threaded pipe for a bottom hole assembly that eliminates the need to use screw threads to mate two pipes or mechanical assemblies, harbors a spring-loaded mechanical locking system in addition in to a pressure-activated, component protectant system, requires no significant tools, other than an Allen wrench or similar screw setting device, permits distributed torque loading, allows for movement in either a clockwise or counter clockwise rotational direction through interlocking castellations and presents a removeable and replaceable valve assembly preventing retrograde hydrocarbon advancement through a drilling pipe. 1. A locking assembly system for locking together threaded or non-threaded pipe sections , tubing and bottom hole assemblies , comprising:a tubular male sub connector exhibiting a neck portion for insertion into a female sub connector, distally, a recessed circumferential region for acceptance of a spring-loaded locking dog mechanism exhibited about said neck portion, external castellations and a cylindrical base harboring an indented, flat area for manually connecting said base to a drill pipe and a “box” threaded connector, proximately, therein;said tubular female sub connector exhibiting an externally manifested “pin” threaded connector, distally, a cylindrical mid region for with an indented, flat area for manually connecting said female sub connector to a drill pipe, an external helical thread and set of windows harboring spring-loaded locking dogs, centrally, and castellation projections created via transverse indentations across the thickness of said female sub connector's tubular circumference, proximally;said set of spring-loaded locking dogs set within said female sub connector windows and spanning the female sub connector's thickness that utilize compression springs exhibiting a naturally outward manifested ...

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Номер записи: 27
03-01-2019 дата публикации

METHOD FOR REMOVING A DOWNHOLE PLUG

Номер: US20190003273A1
Автор: Bigrigg Scott A., Sims Bryan J.
Принадлежит: BAKER HUGHES INCORPORATED

A method of removing a downhole zonal isolation device includes removing the downhole zonal isolation device arranged in a wellbore with a bottom hole assembly (BHA) of a downhole string formed from a plurality of tubulars, and introducing a downhole fluid through a screen assembly mounted to the drill string uphole relative to the BHA. 1. A method of removing a downhole zonal isolation device comprising:removing the downhole zonal isolation device arranged in a wellbore with a bottom hole assembly (BHA) of a downhole string formed from a plurality of tubulars; andintroducing a downhole fluid through a screen assembly mounted to the drill string uphole relative to the BHA.2. The method of claim 1 , wherein introducing the downhole fluid includes pumping off the BHA.3. The method of claim 2 , further comprising: pulling the downhole string in an uphole direction for a selected distance claim 2 , and hanging one of the plurality of tubulars in the borehole.4. The method of claim 1 , further comprising: opening a flow path through screen assembly after drilling through the downhole plug.5. The method of claim 4 , wherein opening the flow path includes applying pressure to a drop ball arranged in the drill string.6. The method of claim 1 , further comprising: closing a selective back pressure valve arranged downhole of the screen assembly and uphole of the BHA.7. The method of claim 6 , wherein closing the selective back pressure valve includes releasing a first flapper and a second flapper arranged in the drill string.8. The method of claim 7 , wherein releasing the first flapper and the second flapper includes sliding the back pressure valve in an uphole direction.9. The method of claim 1 , wherein removing the downhole zonal isolation device includes drilling through a plug.10. The method of claim 8 , wherein drilling through the plug includes drilling through a cast iron bridge plug. In the drilling and completion industry boreholes are formed to provide access to a ...

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Номер записи: 28
03-01-2019 дата публикации

SINGLE-TRIP, OPEN-HOLE WELLBORE ISOLATION ASSEMBLY

Номер: US20190003279A1
Автор: ARDOIN Kevin Wendell, SCHULDES Roberto Francisco
Принадлежит:

A method of isolating an open-hole section of a wellbore includes positioning, a liner, a valve, and a liner hanger that are attached to a working string adjacent an interface between the open-hole section and a cased section of the wellbore. The method includes injecting cement through the liner and the valve to form a first balanced cement plug within the open-hole section of the wellbore. Generally, the liner, the valve, and the liner hanger are secured within the balanced cement plug. After the balanced cement plug is set, the liner hanger is actuated and the liner, the valve, and the liner hanger are detached from the working string, which causes the valve to close and creates a mechanical barrier between the balanced cement plug and the working string. Additionally, the mechanical barrier is covered in cement to form another balanced cement plug. 1. A method of isolating an open-hole section of a wellbore , the method comprising:extending a liner that is attached to a working string into the open-hole section of the wellbore, the liner having an interior flow passage; flows through a valve that separates a first portion of the interior flow passage from a second portion of the interior flow passage; and', 'fills a first annulus formed between the liner and the open-hole section of the wellbore to plug the open-hole section of the wellbore; and, 'injecting a first hardenable fluid into the working string so that the first hardenable fluidclosing the valve to fluidically isolate the first portion of the interior flow passage from the second portion of the interior flow passage.2. The method of claim 1 , further comprising setting a liner stabilizer attached to the liner to fluidically isolate a first portion of a second annulus formed between the liner and a cased section of the well from a second portion of the second annulus.3. The method of claim 2 , further comprising detaching the liner from the working string.4. The method of claim 3 , further comprising ...

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Номер записи: 29
03-01-2019 дата публикации

Methods of Sealing a Hydrocarbon Well

Номер: US20190003280A1
Автор: Baumert Brandon Max, Witt Joseph W.
Принадлежит:

Methods of sealing a hydrocarbon well containing a control line. The hydrocarbon well includes a casing string extending within a wellbore and defining a casing conduit, production tubing extending within the casing conduit and defining a tubing conduit, and at least one control line extending within an annular space. The methods include fluidly isolating a downhole region of the tubing conduit from an uphole region of the tubing conduit and actuating a shape charge device. The actuating includes forming a plurality of openings within the production tubing and severing the at least one control line. The methods also include positioning a diversion structure within the uphole region of the tubing conduit, pumping a sealing material into the annular space at the sealing material injection region, and curing the sealing material to form a fluid seal that extends within the annular space and the uphole region of the tubing conduit. 1. A method of sealing a hydrocarbon well , the method comprising:fluidly isolating a downhole region of a tubing conduit from an uphole region of the tubing conduit, wherein the hydrocarbon well includes a wellbore extending within a subterranean formation, a casing string extending within the wellbore and defining a casing conduit, production tubing extending within the casing conduit and defining the tubing conduit, and at least one control line extending within an annular space defined between the casing string and the production tubing; (i) forming a plurality of openings within the production tubing with a plurality of projectiles of the shape charge device by accelerating the plurality of projectiles through the production tubing and into the annular space; and', '(ii) severing the at least one control line at a plurality of locations with at least a subset of the plurality of projectiles;, 'actuating a shape charge device that is positioned within a target portion of the uphole region of the tubing conduit, wherein the actuating ...

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Номер записи: 30
03-01-2019 дата публикации

Downhole Valve Apparatus

Номер: US20190003283A1
Автор: Atkins James Edward, Buckland Jonathan Peter, Linklater James
Принадлежит:

A valve assembly for use in a wellbore of an oil, gas or water well, having a valve seat to seat a valve closure member such as a ball, and a control member that is adapted to cycle the valve assembly between first and second configurations of the valve assembly when the ball is seated on the seat. The valve assembly may be adapted to return the valve assembly to the first configuration when the valve closure member is seated on the seat, and may repeatedly, continuously and/or sequentially cycle from first to second configurations and back to first configuration to open and close an outlet port while the same valve member is seated on the seat. The valve seat may comprise first and second seat members and retain the ball in a cleft between the first and second seat members. 1. A valve assembly for use in a wellbore of an oil , gas or water well , the valve assembly having a bore with an axis , the assembly having a valve seat adapted to seat a valve closure member , the assembly comprising an outlet port and a control sleeve adapted to cycle the valve assembly between a first configuration and a second configuration of the valve assembly , wherein in the first configuration of the valve assembly , the control sleeve is configured to obturate the outlet port and to restrict fluid communication between the bore and the outlet port; and wherein in the second configuration the control sleeve is configured to allow at least partial fluid communication between the bore and the outlet port; and wherein the valve assembly is repeatedly cyclable between the first and second configurations of the valve assembly , while the valve closure member is seated on the valve seat , by changes in fluid pressure acting on the seated valve closure member.2. A valve assembly as claimed in claim 1 , wherein the valve assembly is biased into the first configuration and is adapted to be switched into the second configuration by the application of fluid pressure on the seated valve closure ...

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Номер записи: 31
03-01-2019 дата публикации

Mechanically Adjustable Inflow Control Device

Номер: US20190003284A1
Автор: Coulston Stephen
Принадлежит: BAKER HUGHES INCORPORATED

An adjustable inflow control device features a mechanically rotatable sleeve that advances or retreats axially when rotated in opposed directions to cover or uncover a labyrinth flow path from an inlet to an outlet. When used for inflow the outlet is into a tubular string to a surface location. The more the sleeve is retracted away from the labyrinth path the less resistance to flow is offered and vice versa. Another way to mechanically alter the flow resistance is to have an outer housing with a spiral groove and an axially movable inner mandrel with another spiral groove. The mandrel can be axially advanced with rotation when connected with a thread. Advancing the mandrel so that there is more overlap between the spiral patterns increases resistance to a give flow rate and vice versa. A gap between the mandrel and housing allows the mandrel to rotate and translate. 1. An adjustable flow control device between a tubular string and a surrounding annular space , comprising:a housing having a first port to the annular space and a second spaced apart port to the tubular string;a labyrinth flow path between said first and second ports;a rotatably mounted member in said housing, whereupon rotation of said member changes resistance to a predetermined flow between said ports.2. The device of claim 1 , wherein:said member translates while rotating.3. The device of claim 1 , wherein:said member comprises a sleeve.4. The device of claim 1 , wherein:said member is engaged to said housing for said rotation with a driving thread form.5. The device of claim 1 , wherein:said member is engaged to said housing with a j-slot mechanism having slots of different lengths.6. The device of claim 1 , wherein:movement of said member engages a seal between said member and said housing to selectively close flow between said ports.7. The device of claim 1 , wherein:axial movement of said member varies the length of said labyrinth passage between said ports.8. The device of claim 1 , wherein: ...

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Номер записи: 32
03-01-2019 дата публикации

Apparatus and method for treating a reservoir using re-closeable sleeves, and actuating the sleeves with bi-directional slips

Номер: US20190003285A1
Автор: Don Getzlaf, Tim Johnson
Принадлежит: NCS Multistage Inc

There is provided a bottomhole assembly for deployment within a wellbore string disposed within a wellbore, the wellbore string including a port and a flow control member, wherein the flow control member is displaceable relative to the port for effecting opening and closing of the port, comprising: a first mandrel; a second mandrel including a locator for becoming disposed within a locate profile of the wellbore string such that resistance to displacement of the second mandrel, relative to the locate profile, is effected, and such that locating of the bottomhole assembly within the wellbore string is thereby effected; a shifting tool including a first gripper surface and a second gripper surface; a first shifting tool actuator, translatable with the first mandrel; and a second shifting tool actuator, translatable with the first mandrel; wherein: the shifting tool is displaceable in response to urging by the first shifting tool actuator that is effected by downhole displacement of the first mandrel relative to the second mandrel, such that the first gripper surface is displaced outwardly to a first gripper surface gripping position for becoming disposed in gripping engagement with the flow control member; the shifting tool is displaceable in response to urging by the second shifting tool actuator that is effected by uphole displacement of the first mandrel relative to the second mandrel, such that the second gripper surface is displaced outwardly to a second gripper surface gripping position for becoming disposed in gripping engagement with the flow control member; and the second mandrel includes a retainer for limiting displacement of the shifting tool, relative to second mandrel, in both of downhole and uphole directions.

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Номер записи: 33
03-01-2019 дата публикации

METHOD FOR REMOVING A DOWNHOLE PLUG

Номер: US20190003286A1
Автор: Bigrigg Scott A., Sims Bryan J.
Принадлежит: BAKER HUGHES INCORPORATED

A method of cleaning out a wellbore includes removing the downhole zonal isolation device arranged in a wellbore with a bottom hole assembly (BHA) of a downhole string formed from a plurality of tubulars, pumping off the BHA, removing downhole fluids from the wellbore without removing the downhole string following pumping off the BHA, circulating fluid near a toe of the wellbore, and removing downhole particles from the wellbore through the downhole string. 1. A method of cleaning out a wellbore comprising:removing the downhole zonal isolation device arranged in a wellbore with a bottom hole assembly (BHA) of a downhole string formed from a plurality of tubulars;pumping off the BHA;removing downhole fluids from the wellbore without removing the downhole string following pumping off the BHA;circulating fluid near a toe of the wellbore; andremoving downhole particles from the wellbore through the downhole string.2. The method of claim 1 , further comprising: pulling the downhole string in an uphole direction for a selected distance claim 1 , and hanging one of the plurality of tubulars in the borehole after pumping off the BHA.3. The method of claim 2 , further comprising: shifting the drill string towards the toe of the wellbore prior to circulating the fluid near the toe of the wellbore.4. The method of claim 1 , wherein removing downhole fluids from the wellbore includes opening a screen assembly and passing the downhole fluids through a screen of the screen assembly into the drill string.5. The method of claim 1 , wherein circulating fluid includes passing fluid into the wellbore toward the toe of the wellbore about the downhole string.6. The method of claim 5 , wherein passing fluid into the wellbore includes introducing the fluid into the downhole string at the toe of the wellbore.7. The method of claim 6 , wherein introducing fluid into the wellbore includes withdrawing downhole particulate from the toe of the wellbore with the fluid.8. The method of claim 1 , ...

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Номер записи: 34
03-01-2019 дата публикации

APPARATUS AND METHOD FOR PREVENTING PARTICLE INTERFERENCE OF DOWNHOLE DEVICES

Номер: US20190003296A1
Автор: FIELDER, III Robert P., Meier Kyle, Sheline Evan
Принадлежит:

A device and method for inhibiting particle (e.g., sand) accumulation on down hole equipment, such as an ESP, particularly when the equipment is not in use. The device and methods permit the equipment to start and stop with fewer break downs and at greater efficiency. The device includes a central tubular section connecting the equipment to the production tubing string. The tubular section is surrounded by an annulus and a number of ports in the tubular section angled to allow fluid communication between the tubular section and the annulus during operation, but prevent particles from flowing from the annulus into the tubular section when not in use. A check valve between the tube and ESP assists in isolating the ESP from sand. 1. A device for preventing particle interference with downhole lifting equipment in a well bore having a production tubing string , comprising:a tube positioned between the downhole lifting equipment and the surface and in fluid communication with the downhole lifting equipment and the production tubing string;a housing positioned around the tube defining an annulus portion between the tube and the housing;an upper check valve connected to a proximal end of the tube nearest the surface that is biased into a closed position to prevent flow into the tube through the proximal end;a lower check valve connected to a distal end of the tube that is biased into a closed position to prevent flow out of the tube through the distal end; anda plurality of ports disposed through the tube that are configured to permit flow from the tube into the annulus, wherein the ports are spaced along the tube and oriented at a downward angle relative to the longitudinal axis of the tube.2. The device of claim 1 , wherein the downward angle of the ports is between 30 degrees and 60 degrees relative to the longitudinal axis of the tube.3. The device of claim 1 , wherein the largest number of ports are positioned nearest the distal end.4. The device of claim 3 , wherein ...

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Номер записи: 35
12-01-2017 дата публикации

ELASTIC PIPE CONTROL WITH MANAGED PRESSURE DRILLING

Номер: US20170009543A1
Автор: Bakri Yassin Ibrahim Emad, Lovorn James Randolph, Samuel Robello
Принадлежит:

Disclosed embodiments include systems and methods for improving the accuracy of bottom hole pressure control. One example embodiment includes a torque and drag model that calculates the elasticity of the drill string, which is included in a managed pressure drilling control system. The addition of the torque and drag calculations provide more accurate surge/swab effect calculations based on pipe movement corrected for elasticity effects. The results of these calculations will be used in a real-time hydraulics model to determine a setpoint pressure which will be utilized by a MPD choke system. Further, the real-time torque and drag models are calibrated to actual hole conditions in real-time using survey, temperature, pressure and downhole tool data to calculate friction factors in a wellbore. 1. A method comprising:obtaining at least one fluid property of an input fluid to a well and of a return fluid from the well;calculating an elasticity parameter of a drill string within the well based at least in part on the at least one fluid property;calculating a wellhead setpoint pressure that results in a predetermined downhole pressure at a predetermined location in the well, the calculation based at least in part on the elasticity parameter and the at least one fluid property; andcontrollably regulating the flow of the return fluid to maintain the calculated wellhead setpoint pressure.2. The method of claim 1 , wherein the at least one fluid property comprises at least one of: fluid density claim 1 , oil/water ratio claim 1 , chlorides content claim 1 , electric stability claim 1 , shear stress of the fluid claim 1 , gel strength claim 1 , plastic viscosity claim 1 , yield point claim 1 , and combinations thereof.3. The method of claim 1 , wherein calculating the elasticity parameter further comprises using a torque and drag model to calculate the elasticity of the drill string.4. The method of claim 3 , further comprising calibrating the torque and drag model to ...

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Номер записи: 36
12-01-2017 дата публикации

PRESSURE RELEAVING MEANS

Номер: US20170009556A1
Автор: George Grant, Ingraham Derek, McCarthy Matthew
Принадлежит: Schlumberger Canada Limited

A packer and method and apparatus for releasing pressure within a pressurized annulus around the packer. The apparatus comprises a central tubular member having a central bore therethrough extending between first and second ends, an outer plug slidably locatable within a first end of the tubular member and having a central bore therethrough and an inner plug slidably locatable within the central bore of the outer plug. The method comprises longitudinally retracting the inner plug from sealed engagement within the central bore of the outer plug member so as to permit fluid to flow therethrough and engaging the outer plug with a retraction body operably connected to the inner plug extending adapted to engage the inner plug after a predetermined length of travel so as to draw the outer plug out of the central tubular member thereafter. 1. An apparatus for releasing pressure within a pressurized annulus around a tool string of a well bore comprising:a central tubular member having a central bore therethrough extending between first and second ends;an outer plug slidably locatable within a first end of the tubular member and having a central bore therethrough; andan inner plug slidably locatable within the central bore of said outer plug.2. The apparatus of further comprising a first end cap operably connected to the second plug such that axial movement of the end cap retracts said second plug from said central bore of said fist plug.3. The apparatus of further comprising a retraction member operably connected to and movable with said inner plug claim 2 , said retracting member being adapted to engage said inner plug after a predetermined length of travel so as to draw said outer plug out of the central tubular member thereafter.4. The apparatus of wherein said retraction member comprises a retraction sleeve surrounding said inner plug along a parallel axis therewith.5. The apparatus of wherein said retraction sleeve includes fluid flow passages therethrough6. The ...

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Номер записи: 37
11-01-2018 дата публикации

Secondary hydrocarbon-fluid recovery enhancement

Номер: US20180010035A1
Автор: Cato Russell Mcdaniel, Pubudu H. Gamage, William Walter Shumway
Принадлежит: Halliburton Energy Services Inc

A chelating agent can be used to enhance secondary hydrocarbon-fluid recovery during waterflooding operations. A composition can include a fluid and a chelating agent. The chelating agent can increase the viscosity of the fluid, which can enhance the efficacy of the waterflooding operations. The chelating agent can also form complexes with divalent cations in precipitates and solids formed by the divalent cations. The complexes can keep the cations in a soluble form until the composition exits the production well, which can prevent precipitates from forming in the production well and blocking pore throats in the production well.

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Номер записи: 38
14-01-2016 дата публикации

Method and Apparatus For Treating A Well

Номер: US20160010426A1
Автор: Love Douglas N.
Принадлежит: Texian Resources

A tool for forming a valve seat within a well that is capable of catching an obstruction will prevent flow of fluid downstream of the seat. According to one embodiment of the invention, the seat is formed by expanding a sleeve with a ring positioned around its periphery or as a subsequent step in the process. As the sleeve is expanded over the ring, the seat is formed. Once the seat is formed, an obstruction in the form of a ball or dart is dropped down to the seat. In another embodiment, the sleeve acts as a stop for a secondary valve seat which catches the obstruction. 1. A tool for forming a valve seat within an oil and/or gas well capable of capturing an obstruction to thereby prevent flow of fluids downhole of the valve seat comprising:a. a sleeve formed of expansible material;b. a valve seat formed as part of the sleeve; andc. a ring member surrounding the sleeve.2. The tool for forming a valve seat as claimed in further including a thin strip of no-slip metallic material impregnated on an outer surface of the sleeve.3. The tool for forming a valve seat as claimed in further including a cap closing a downhole portion of the sleeve so that the tool can be pumped down into the well to a predetermined location.4. The tool for forming a valve seat as claimed in further including an explosive charge positioned within the sleeve to expand the sleeve when the charge is detonated claim 1 , thereby forming the valve seat.5. The tool for forming a seat as claimed in further comprising a frangible mandrel supporting the explosive charge.6. The tool for forming a seat as claimed in wherein the explosive charge is detonation cord.7. The tool as claimed in wherein the thin strip of no-slip metallic material includes an elastomeric sealing agent.8. The tool as claimed in wherein the ring is positioned around the sleeve approximately at the midpoint of the sleeve.9. The tool as claimed in wherein the valve seat is formed by expanding the sleeve over the ring.10. The tool as ...

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Номер записи: 39
14-01-2016 дата публикации

WELL INTERVENTION PRESSURE CONTROL VALVE

Номер: US20160010428A1
Автор: Bivens Eric, Hunter Timothy Holiman, STEWART Takao
Принадлежит:

A system comprising a control valve comprising a flapper either activated or inactivated, when activated the flapper may be closed or open and, when inactivated the flapper is open, a first sleeve transitional from a first to a second position, and a second sleeve transitional from a first to a second position, when the first and second sleeves are in the first position, the flapper is activated, when the first sleeve is in the second and the second sleeve is in the first position, the flapper is inactivated, when the first and second sleeves are in the second position, the flapper is activated, the application of pressure to the first sleeve via a first member transitions the first sleeve from the first to the second position, and the application of pressure to the second sleeve via a second member transitions the second sleeve from the first to the second position. 1. A wellbore servicing system comprising:a work string; and a housing generally defining an axial flowbore and a contact surface extending circumferentially about the axial flowbore;', 'a first sleeve slidably positioned within the housing and moveable in an axial direction, and relative to the housing, from a first position to a second position;', 'a second sleeve slidably positioned within the first sleeve and moveable in the axial direction, and relative to the first sleeve, from a third position to a fourth position; and', wherein, in the activated state, the flapper valve is free to move between a closed position, in which the flapper valve blocks the axial flowbore, and an open position, in which the flapper valve does not block the axial flowbore, and', 'wherein, in the inactivated state, the flapper valve is retained in the open position by the second sleeve;, 'a flapper valve disposed within the axial flowbore and configurable between an activated state and an inactivated state,'}], 'a pressure control valve tool (PCVT) incorporated within the work string and configurable between first, second ...

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Номер записи: 40
14-01-2016 дата публикации

TOOLS AND METHODS FOR USE IN COMPLETION OF A WELLBORE

Номер: US20160010429A1
Автор: Getzlaf Donald, Nipper Robert, Stromquist Marty, Willems Timothy H.
Принадлежит:

A ported tubular is provided for use in casing a wellbore, to permit selective access to the adjacent formation during completion operations. A system and method for completing a wellbore using the ported tubular are also provided. Ports within the wellbore casing may be opened, isolated, or otherwise accessed to deliver treatment to the formation through the ports, using a tool assembly deployed on tubing or wireline. 1. A method for shifting a sliding sleeve in a wellbore , comprising:providing a wellbore lined with tubing, the tubing comprising a port closure sleeve slidably disposed within a tubular, the tubular having an inner profile for use in locating said sleeve;providing a tool assembly comprising: a locator engageable with said locatable inner profile of the tubular; and a resettable anchor member;deploying the tool assembly within the wellbore on coiled tubing;engaging the inner profile with the locator;setting the anchor within the wellbore to engage the sliding sleeve;applying a downward force to the coiled tubing to slide the port closure sleeve with respect to the tubular.2. The method as in claim 1 , wherein the step of setting the anchor comprises application of a radially outward force with the anchor to the port closure sleeve so as to frictionally engage the sleeve with the anchor.3. The method as in claim 1 , wherein the port closure sleeve comprises an inner surface of uniform diameter along its length claim 1 , free of any engagement profile.4. The method as in claim 1 , wherein the port closure sleeve has an inner diameter consistent with the inner diameter of the tubing.5. The method as in claim 1 , wherein the tool assembly further comprises a sealing member associated with the anchor claim 1 , and wherein the method further comprises the step of setting the sealing member across the port closure sleeve to provide a hydraulic seal across the sleeve.6. The method as in claim 1 , wherein the step of applying the downward force comprises ...

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Номер записи: 41
14-01-2016 дата публикации

EQUIPMENT FOR EXTRACTING AND INCREASING PRODUCTION OF CRUDE OIL AND GAS

Номер: US20160010435A1
Автор: Jeon Se Chang
Принадлежит:

The invention relates to equipment for extracting and increasing production of crude oil and gas comprises: a connector unit connected to a main piston axial, the main piston axial makes up and down movements inside of a main cylinder; a piston unit connected to the connector unit, the piston unit moves in connection with the main piston axial in order to extract the extracting objects additionally; a cylinder unit creating pressure to lift the extracting objects to the ground level as the piston unit makes up and down movements inside of the piston unit; and a supply unit managing the conveying process of the extracting objects by lifting the extracting objects to the ground level when the piston unit moves up and transporting the extracting objects to the storage when the piston unit moves down. 1. An equipment for extracting and increasing production of crude oil and gas comprising:a connector unit connected to a main piston axial, the main piston axial makes up and down movements inside of a main cylinder and the main cylinder is installed below the ground and exposed to outside in order to extract extracting objects;a piston unit connected to the connector unit, the piston unit moves in connection with the main piston axial in order to extract the extracting objects additionally;a cylinder unit creating pressure to lift the extracting objects to the ground level as the piston unit makes up and down movements inside of the piston unit; anda supply unit managing the conveying process of the extracting objects by lifting the extracting objects to the ground level when the piston unit moves up and transporting the extracting objects to the storage when the piston unit moves down.2. The equipment for extracting and increasing production of crude oil and gas of claim 1 , the piston unit comprising:a piston axial connected to the connector unit but separated from the main piston axial, the piston axial makes up and down movements inside of the cylinder unit while ...

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Номер записи: 42
11-01-2018 дата публикации

Rotating superhard cutting element

Номер: US20180010396A1
Автор: Bradley David DUNBAR, Roddy HARWELL, William Brian Atkins
Принадлежит: Halliburton Energy Services Inc

Systems and methods are disclosed for a rotating superhard cutting element. The rotating cutting element includes a substrate comprising a rotating portion and a stable portion. The stable portion has a cavity and is configured to be fixed to a blade of a drill bit. The rotating cutting element further includes a retainer that rotatably secures the rotating portion of the substrate in the cavity of the stable portion of the substrate, and a cutting layer on the rotating portion of the substrate. The cutting layer has a plurality of cutting surfaces. One of the plurality of cutting surfaces has a property different from another one of the plurality of cutting surfaces. The cutting layer is configured to rotate with respect to the stable portion of the substrate and use one of the plurality of cutting surfaces based on a characteristic of a formation to be cut.

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Номер записи: 43
11-01-2018 дата публикации

MULTISTAGE HIGH PRESSURE FRACTURING SYSTEM WITH COUNTING SYSTEM

Номер: US20180010412A1
Автор: GRAF ROBERT JAMES, SMOLKA ROBERT STEVE
Принадлежит: COMPLETIONS RESEARCH AG

The invention relates to a multistage high pressure fracturing system and tubular hydraulic valve (THV) system for connection to a completion string to enable isolation of a zone of interest within a well. In particular, the system enables access to a downhole formation for fracturing the zone of interest and for hydrocarbon production. The system generally includes a plug counting system, a plug capture system and a valve system wherein dropping a series of plugs down the completion string enables successive capture of individual plugs within individual THVs for subsequent fracturing operations. 1. A tubular hydraulic valve (THV) system for connection to a tubing string to enable isolation of a zone of interest within a well , to enable access to a downhole formation for fracturing the zone of interest and for hydrocarbon production , the THV having an internal bore enabling a plug to pass through the THV , the THV comprising:a plug counting system having an uphole end for connection to a tubing string and a plug engagement system for engagement with a plug passing through the internal bore, the plug engagement system for counting successive plugs passing through the plug counting system and for triggering a first hydraulic event when a pre-set number of plugs passing through the internal bore is reached;a plug capture system operatively connected to the plug counting system, the plug counting system responsive to the first hydraulic event to effect plug capture within the THV when the first hydraulic event is triggered;a valve system operatively connected to the plug counting system and plug capture system, the valve system including a valve responsive to plug capture to open the valve to enable fluid flow from the internal bore to the exterior of the THV.2. The system as in wherein the plug engagement system includes at least one pin connected to a tooth ratchet and a plug piston wherein engagement of a plug passing through the internal bore with the at least one ...

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Номер записи: 44
11-01-2018 дата публикации

DOWNHOLE TOOL AND METHOD OF USE

Номер: US20180010417A1
Автор: VanLue Duke
Принадлежит:

A method of using a downhole tool that includes the step of operating a workstring to run the downhole tool into a wellbore to a desired position. The downhole tool includes a mandrel having a proximate end with a first outer diameter; a distal end having a first set of threads and a second outer diameter; a flowbore extending from the proximate end to the distal end; and an inner set of shear threads disposed in the flowbore at the proximate end. 1. A method of using a downhole tool , the method comprising:operating a workstring to run the downhole tool into a wellbore to a desired position, the downhole tool comprising: a proximate end having a first outer diameter;', 'a distal end comprising a first set of threads and a second outer diameter;', 'a flowbore extending from the proximate end to the distal end; and', 'an inner set of shear threads disposed in the flowbore at the proximate end;', 'a first slip disposed around the mandrel;', 'a second slip disposed around the mandrel;', 'a seal element disposed around the mandrel, and between the first slip and the second slip; and', 'a lower sleeve disposed around the mandrel at the distal end, and threadingly engaged with the first set of threads;, 'a mandrel made of composite material, the mandrel further comprisingplacing the mandrel under a tensile load that causes the seal element to begin to buckle axially and expand outwardly, and that causes at least partial fracture of the first slip and the second slip;{'b': 5', '000, 'increasing the tensile load to a point whereby the downhole tool is set and is able to withstand an upstream pressure of at least , psi; and'}disconnecting the downhole tool from a setting device coupled therewith when the tensile load is of sufficient amount to cause shearing of the set of shear threads.2. The method of claim 1 , wherein the downhole tool further comprises:a composite member disposed about the mandrel and in engagement with the seal element, wherein the composite member is ...

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Номер записи: 45
11-01-2018 дата публикации

DOWNHOLE TOOL AND METHOD OF USE

Номер: US20180010418A1
Автор: VanLue Duke
Принадлежит:

A method of using a downhole tool that includes the step of operating a workstring to run the downhole tool into a wellbore to a desired position. The downhole tool includes a mandrel having a proximate end with a first outer diameter; a distal end with a second outer diameter; a flowbore; and an inner set of shear threads disposed in the flowbore at the proximate end. 1. A method of using a downhole tool , the method comprising:at a surface facility proximate to a wellbore, connecting the downhole tool with a workstring; [ a proximate end having a first outer diameter;', 'a distal end having a second outer diameter;', 'a flowbore extending from the proximate end to the distal end; and', 'an inner set of shear threads disposed in the flowbore at the proximate end;, 'a mandrel made of composite material, the mandrel further comprising, 'a first slip disposed around the mandrel;', 'a second slip disposed around the mandrel;', 'a seal element disposed around the mandrel, and between the first slip and the second slip; and', 'a lower sleeve disposed around and coupled with the mandrel at the distal end;, 'operating the workstring to run the downhole tool into the wellbore to a desired position, the downhole tool comprisingsetting the downhole tool; anddisconnecting the downhole tool from the workstring.2. The method of claim 1 , wherein the workstring further comprises a setting device with an external threaded adapter claim 1 , and wherein the connecting step comprises threadingly engaging the external threaded adapter with the inner set of shear threads claim 1 , and wherein the disconnecting step further comprises shearing the inner set of shear threads.3. The method of claim 1 , wherein the downhole tool further comprises:a composite member disposed about the mandrel and in engagement with a seal element, wherein the composite member is made of a first material and comprises a resilient portion and a deformable portion; anda bearing plate disposed around the mandrel ...

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Номер записи: 46
11-01-2018 дата публикации

Tubing Retrievable Injection Valve Assembly

Номер: US20180010423A1
Автор: Henschel Robert C., Hill Thomas G., Hodge Rory L., Pfaff Shane W.
Принадлежит: Tejas Research & Engineering, LLC

A method and apparatus for controlling the flow of fluid in an injection well includes a main valve assembly having a valve and a retrievable nozzle selective lock assembly (RNSLA). The RNSLA is operable when positioned within the valve body to open the valve when fluid is pumped into the well and closes the valve when fluid flow is terminated. The RNSLA includes a replaceable orifice nozzle so that orifices of different dimensions may be used in conjunction with the valve assembly. In an alternate embodiment, the RNSLA includes a variable output nozzle assembly to maintain the valve in a protected open position without chattering over a wide range of flow rates. 1. A valve assembly for controlling the flow of fluid within an injection well comprising:a valve body,an upper flow tube within the body;an axially shiftable lower flow tube positioned within the valve body axially movable with respect to the upper flow tube;a flapper valve located at a downhole end of the valve body, anda variable restrictor positioned within the valve body and operable to open the valve when fluid flow is initiated through the valve body and operable to close the valve when fluid flow is terminated, said variable restrictor being in a closed condition at a first flow rate to open the flapper valve and being open at a second higher flow rate to allow fluid flow through the valve assembly.2. The valve assembly of wherein said variable restrictor may be retrieved from the injection well while leaving said flapper valve in the well in a closed position.3. The valve assembly of wherein said axially shiftable lower flow tube is adapted to be shifted to a first position to lock the valve assembly in an open position.4. The valve assembly of wherein claim 2 , said upper flow tube is adapted to return the valve assembly to a closed position.5. A valve assembly as claimed in wherein the variable restrictor includes a variable orifice.6. A valve assembly as claimed in wherein the variable orifice ...

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Номер записи: 47
11-01-2018 дата публикации

PILOT AND STOPPER INSIDE A BALL SUITABLE FOR WELLBORE DRILLING OPERATIONS

Номер: US20180010424A1
Автор: Hawkins, III Samuel P.
Принадлежит:

An apparatus, system, and method of use that enables control of fluid flow in a wellbore drill string with a pilot. The apparatus comprises a pusher rod with a bore for fluid flow contacting a rotatable ball with an internal bore comprising at least one pilot, wherein the seat between the pusher rod and the interior of the tubular prevents fluid flow. Pressure changes on the pusher rod rotate the bore of the ball in and out of contact with the bore of the pusher rod, to enable or prevent fluid flow, respectively. A method of use opens the ball by exerting pressure and/or force on the pusher rod to enable fluid through the ball by aligning the internal bores. Fluid flow is stopped by pressure exerted on the bottom of the ball causing the ball to rotate whereby the internal bore of the pusher rod is connected to the exterior surface of the ball. An accumulator can control the operations of the valve by selectively exerting pressure and/or fluid flow on the pusher rod. 1. A system for use in subterranean drilling comprising:a tubular housing comprising an inner surface, a longitudinal axis, and a bore therethrough for fluid flow inside the tubular housing;a first valve within the bore, the first valve comprising a ball having an internal bore and sized to rotate within the tubular housing, at least one pilot located inside the internal bore of the ball and biased to permit fluid flow in a first direction, and a seat located along the bore of the tubular housing preventing fluid flow between the ball and the tubular housing;a second valve downhole from the first valve within the bore, the second valve comprising a ball having an internal bore and sized to rotate within the tubular housing, at least one pilot located inside the internal bore of the ball and biased to permit fluid flow in a first direction, and a seat located along the bore of the tubular housing preventing fluid flow between the ball and the tubular housing; andan isolation rod of sufficient length to ...

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Номер записи: 48
11-01-2018 дата публикации

Direct Drive Motor-based Walking Beam Pumping Unit

Номер: US20180010431A1
Автор: Liu Kunming
Принадлежит:

The invention discloses a direct drive motor-based walking beam pumping unit, comprising a base; a support is arranged at the upper end of the base; a walking beam is arranged at the upper end of the support; a horsehead is arranged at a first of the walking beam; a lifting rope is arranged on the horsehead and a beam hanger is arranged on the lifting rope; a balance weight is arranged at a second end of the walking beam away from the horsehead; a barrel is arranged at the upper end of the base; a direct drive motor is arranged at the upper end of the barrel. The invention cancels the combination of belt, belt pulley and reducer conventionally used in the pumping unit, greatly lowering the failure rate of the pumping unit, decreasing the frequency of maintenance and service, reducing the cost in use and improving the production efficiency. 1114110141310111312112115101342453536765879874. A direct drive motor-based walking beam pumping unit , comprising a base (); a support () is arranged at the upper end of the base (); a walking beam () is arranged at the upper end of the support (); a horsehead () is arranged at a first end of the walking beam (); a lifting rope () is arranged on the horsehead () and a beam hanger () is arranged on the lifting rope (); a barrel () is arranged at the upper end of the base () , wherein , a balance weight () is arranged at a second end of the walking beam () away from the horsehead (); a direct drive motor () is arranged at the upper end of the barrel (); the direct drive motor () is connected to a crank () through a dual-output motor shaft (); a second rotating shaft is arranged on a first end of the crank () away from the dual-output motor shaft (); a connecting rod () is arranged on the second rotating shaft; a beam () is arranged at a first of the connecting rod () away from the crank (); a beam shaft () is arranged on the beam (); a first rotating shaft () is arranged on the beam shaft () and connected to the beam () through a ...

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Номер записи: 49
14-01-2016 дата публикации

DEVICE AND METHOD FOR PARALLEL MICROFLUIDIC PRESSURE-VOLUME-TEMPERATURE ANALYSIS

Номер: US20160011328A1
Автор: Atkinson, Chen Songhua, Jones Christopher M., JR. Robert S., Pelletier Michael T.
Принадлежит:

A microfluidic device and method is described to parallelize a pressure-volume-temperature (“PVT”) analysis such that a portion of the pressure, temperature and volume analysis is performed separately from others. The resulting PVT data is then recombined statistically for a complete PVT analysis. The microfluidic device may also obtain compositional data of the fluid to perform an equation of state analysis or reservoir simulations. 1. A method to perform a pressure-volume-temperature (“PVT”) analysis of wellbore fluid using a microfluidic device , the method comprising:receiving a wellbore fluid sample into an inlet port of a microfluidic device;communicating a volume of the wellbore fluid sample to a plurality of microfluidic channels;applying pressure and temperature to each fluid sample volume;applying a magnetic field across the microfluidic channels using a nuclear magnetic resonance (“NMR”) apparatus;generating first signals corresponding to phase characteristics of each fluid sample volume within the microfluidic channels using the NMR apparatus, the phase characteristics of each fluid sample volume being dependent upon the pressure or temperature applied to the fluid sample volume; andperforming a PVT analysis based upon the first signals using the processing circuitry.2. A method as defined in claim 1 , wherein performing the PVT analysis further comprises performing a statistical analysis of the first signals.3. A method as defined in claim 1 , wherein generating the first signals further comprises utilizing a one-dimensional NMR profile to determine the fluid sample volumes.4. A method as defined in claim 1 , wherein generating the first signals further comprises determining a diffusion of the fluid sample volumes.5. A method as defined in claim 1 , wherein performing the PVT analysis further comprises determining at least one of a phase behavior claim 1 , transport property or bulk property of the fluid sample volumes.6. A method as defined in claim 1 ...

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Номер записи: 50
14-01-2021 дата публикации

HYBRID PDC BIT

Номер: US20210010330A1
Автор: Chrest Ben, Rothe Mitchell
Принадлежит: ULTERRA DRILLING TECHNOLOGIES, L.P.

A bladeless polycrystalline diamond compact (PDC) drill bit includes a head having a plurality of knots protruding from a drilling face of the head. Each of the plurality of knots includes a single cutter. Each of the cutters is arranged about a central axis of the head such that each cutter has a unique radial position and angular position relative to the central axis. The head defines at least one fluid port extending through the drilling surface. 1. A polycrystalline diamond compact (PDC) drill bit , comprising: a first plurality of cutters arranged on a plurality of blades arranged proximate a center of the head; and', each of the second plurality of cutters is arranged about a central axis of the head such that each of the second plurality of cutters has a unique radial position and at least a substantial number of the second plurality of cutters have unique angular positions relative to the central axis; and', 'the head defines at least one fluid nozzle extending through the drilling surface., 'a second plurality of cutters arranged on a plurality of knots that protrude from a drilling face of the head, wherein], 'a head comprising2. The polycrystalline diamond compact (PDC) drill bit of claim 1 , wherein:the angular position of each successive one of the second plurality of cutters is incremented by between about 131 and 143 degrees starting from an innermost cutter of the second plurality of cutters relative to the central axis.3. The polycrystalline diamond compact (PDC) drill bit of claim 1 , wherein:the at least one fluid nozzle extends through the drilling surface between bases of at least two of the plurality of blades.4. The polycrystalline diamond compact (PDC) drill bit of claim 1 , wherein:a diameter of an opening of each of the at least one fluid nozzle is adjustable.5. The polycrystalline diamond compact (PDC) drill bit of claim 1 , wherein:the angular position of each of the first plurality of cutters and the second plurality of cutters are ...

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Номер записи: 51
14-01-2021 дата публикации

Hybrid Coiled Tubing System

Номер: US20210010346A1
Автор: Greig Scott Robert, Savenkova Anna, Shepherd Iain James
Принадлежит: Halliburton Energy Services, Inc.

A hybrid coiled tubing system. The hybrid coiled tubing system may include composite coiled tubing, metallic coiled tubing, and a composite coiled tubing connector coupled to and joining the composite coiled tubing and the metallic coiled tubing.

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Номер записи: 52
14-01-2021 дата публикации

CHOKE SYSTEM FOR A DOWNHOLE VALVE

Номер: US20210010347A1
Автор: Brown Donavan Holland
Принадлежит: Baker Hughes Oilfield Operations LLC

A choke system for a downhole valve including a first tubular having an outer surface, an inner surface, and a first flow port extending through the outer surface and the inner surface. A second tubular is shiftably arranged relative to the first tubular radially inwardly of the inner surface. The second tubular includes a second flow port that is selectively aligned with the first flow port. A choke member including a choke opening is positioned between the first tubular and the second tubular. The choke member is selectively shiftable and rotatable relative to the first tubular and the second tubular. A choke actuator is axially aligned with the choke member and positioned between the first tubular and the second tubular. The choke actuator being selectively shiftable to unseat the choke member and rotate the choke opening relative to the first and second flow ports. 1. A choke system for a downhole valve comprising:a first tubular including an outer surface, an inner surface, and a first flow port extending through the outer surface and the inner surface;a second tubular shiftably arranged relative to the first tubular radially inwardly of the inner surface, the second tubular including a second flow port that is selectively aligned with the first flow port;a choke member including a choke opening positioned between the first tubular and the second tubular, the choke member being selectively shiftable and rotatable relative to the first tubular and the second tubular;a choke actuator axially aligned with the choke member and positioned between the first tubular and the second tubular, the choke actuator being selectively shiftable to unseat the choke member and rotate the choke opening relative to the first and second flow ports; anda return spring positioned to bias the choke member toward the choke actuator.2. (canceled)3. The choke system according to claim 1 , wherein the return spring extends about the second tubular.4. A choke system for a downhole valve ...

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Номер записи: 53
10-01-2019 дата публикации

Cementing Stage Collar with Dissolvable elements

Номер: US20190010784A1
Автор: Buryakovsky Vadim, Rozenblit Vlad
Принадлежит:

A cementing stage collar and a method. The cementing stage collar may include dissolvable parts. 1. A cementing stage collar , comprising:a body that comprises a flow port;a group of sleeves that comprises at least one sleeve; wherein the group of sleeves comprises exit ports; wherein the group of sleeves is configured to move within the body thereby selectively blocking the flow port and selectively exposing the flow port to an interior of the cementing stage collar; wherein at least one sleeve is dissolvable; anda first closing element that is configured to receive a sealing element and to seal the cementing stage collar; wherein the first closing element is dissolvable.2. The cementing stage collar according to wherein the first closing element is a closing seat.3. The cementing stage collar according to claim 2 , wherein the closing seat comprises a removable and non-solvable cover that covers a dissolvable portion of the closing seat.4. The cementing stage collar according to wherein at least a part of the group of sleeves are dissolvable.5. The cementing stage collar according to claim 1 , comprising a stopper that is configured to seal a through port of the group of sleeves thereby preventing fluid to exit downstream of the cementing stage collar when the flow port is exposed to the interior of the cementing stage collar.6. The cementing stage collar according to claim 5 , wherein the stopper is dissolvable.7. The cementing stage collar according to claim 1 , wherein the group of sleeves comprises an opening sleeve and a closing sleeve.8. The cementing stage collar according to claim 7 , wherein the opening sleeve comprises a removable non-solvable cover that covers a dissolvable portion of the opening sleeve.9. The cementing stage collar according to wherein the closing sleeve is configured to selectively block the flow port; and wherein the opening sleeve is configured to electively expose the flow port to an interior of the opening sleeve.10. A method for ...

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Номер записи: 54
10-01-2019 дата публикации

Method and apparatus for wellbore fluid treatment

Номер: US20190010785A1
Автор: Daniel Jon Themig, Jim Fehr
Принадлежит: Packers Plus Energy Services Inc

A tubing string assembly for fluid treatment of a wellbore includes substantially pressure holding closures spaced along the tubing string, which each close at least one port through the tubing string wall. The closures are openable by a sleeve drivable through the tubing string inner bore.

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Номер записи: 55
10-01-2019 дата публикации

Positionable and Removable Isolation Device in a Wellbore

Номер: US20190010787A1
Автор: Durst Douglas G.
Принадлежит: Halliburton Energy Services, Inc.

An assembly for installation into a wellbore that includes a main wellbore and a lateral wellbore branching off the main wellbore is described. The assembly includes a tubular positionable in the main wellbore, where the tubular includes a profile. The assembly further includes an isolation device securably landable in and sealable against the profile device to isolate a region of the main wellbore from a region of the lateral wellbore. 1. An assembly for installation into a wellbore comprising a main wellbore and a lateral wellbore branching off the main wellbore , the assembly comprising:a tubular positionable in the main wellbore and comprising a profile device; andan isolation device securably landable in and sealable against the profile device to isolate a region of the main wellbore from a region of the lateral wellbore.2. The assembly of claim 1 , wherein the isolation device is extendable into the lateral wellbore to isolate the lateral wellbore from a portion of the main wellbore.3. The assembly of wherein the isolation device is installable or removable from the tubular without a rig or a pulling unit device.4. The assembly of claim 1 , wherein the isolation device is landable in the main wellbore to isolate the lateral wellbore from the main wellbore.5. The assembly of claim 1 , wherein the profile device is locatable in the main wellbore and positionable above a junction region claim 1 , below the junction region claim 1 , or above and below the junction region joining the main wellbore and the lateral wellbore.6. The assembly of claim 1 , wherein the isolation device is installable or removable from the wellbore using a downhole install device claim 1 , wherein the downhole install device is configured for attachment and re-attachment to the isolation device.7. The assembly of claim 1 , wherein a sealing device is locatable in the main wellbore.8. The assembly of claim 7 , wherein the sealing device is usable with the profile device to secure the ...

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Номер записи: 56
09-01-2020 дата публикации

BI-MILL FOR MILLING AN OPENING THROUGH A WELLBORE CASING AND IN A PREPLANNED LATERAL DRILLING PATH IN DEPARTURE FROM THE WELLBORE AXIS

Номер: US20200011134A1
Автор: CRABB JOHN LLOYD, Dewey Charles, Garza Antonio, NEVLUD KENNETH
Принадлежит:

A bi-mill mills an opening through a wellbore casing in a preplanned lateral drilling path in departure from the wellbore axis and through the wellbore casing or rock formation and in the direction of the drilling path. The bi-mill provides increase debris removal and cutting surfaces and includes an assembly having a lead mill and a follow mill and attaches to the wellbore whipstock. The lead mill further includes fluid passageways leading from the lead mill and exiting the nose of the lead mill. Debris removal channels channel milled debris away from the lead mill and in the direction of the follow mill form in a helical configuration for guiding debris milled by lead mill inserts along the debris removal channels. The lead mill and follow mill continue milling through the wellbore casing and into the underground rock formation a distance sufficient to initiate the preplanned drilling path. 1. A bi-mill for milling an opening through a wellbore casing in initiating a preplanned lateral drilling path in departure from the wellbore axis and through the wellbore casing or wellbore rock formation , and further continuing into underground rock formation outside the wellbore and in the direction of the preplanned lateral drilling path and as guided by a wellbore whipstock , comprising:an assembly comprising a lead mill and a follow mill, said lead mill threadably attached to said follow mill, said lead mill comprising;a body forming a structural base for said lead mill, and further comprising:a smooth bore in the lead mill for receiving a circumferentially-grooved shear bolt, said shear bolt comprising a threaded end threadably attached to the wellbore whipstock and with the unthreaded end inserted into said smooth bore, said lead mill comprising a plurality of fluid passageways wherein said smooth bore comprises a sufficiently shallow depth so as to not intersect with internal fluid passageways and so as to not exit the distal side of said lead mill, said lead mill ...

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Номер записи: 57
09-01-2020 дата публикации

FIXED CUTTER STABILIZING DRILL BIT

Номер: US20200011137A1
Автор: MAURSTAD CARY ANDREW
Принадлежит:

A bit for drilling a wellbore includes: a body; and a cutting face including: a blade protruding from the body; and a row of cutters, each cutter including: a substrate mounted in a pocket formed adjacent to a leading edge of the blade; and a cutting table made from a superhard material, mounted to the substrate, and having a working face. A first subset of the row of cutters is oriented at a negative side rake angle. A second subset of the row of cutters is oriented at a zero or slightly positive side rake angle. The first and the second subsets are alternating. An innermost cutter of the first subset has a maximum absolute value of the negative side rake angle. The absolute value negative side rake angles of the rest of the cutters decrease as their distance from a center of the cutting face increases. 1. A bit for drilling a wellbore , comprising:a body; and a blade protruding from the body; and', a substrate mounted in a pocket formed adjacent to a leading edge of the blade; and', 'a cutting table made from a superhard material, mounted to the substrate, and having a working face,, 'a row of cutters, each cutter comprising], 'a cutting face comprising a first subset of the row of cutters is oriented at a negative side rake angle,', 'a second subset of the row of cutters is oriented at a zero side rake angle,', 'the first and the second subsets are alternating,', 'an innermost cutter of the first subset has a maximum absolute value of the negative side rake angle,', 'an absolute value of each of the negative side rake angles of the rest of the cutters decreases as their distance from a center of the cutting face increases,', 'the maximum absolute value of the negative side rake angle ranges between 10 and 30 degrees, and', 'the innermost cutter is located in a cone section of the cutting face., 'wherein2. (canceled)3. (canceled)4. (canceled)5. (canceled)6. The bit of claim 1 , wherein:the blade is a primary blade extending from the center of the cutting face, ...

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Номер записи: 58
09-01-2020 дата публикации

IDENTIFICATION OF WEAK ZONES IN ROTARY DRILL BITS DURING OFF-CENTER ROTATION

Номер: US20200011138A1
Автор: Chen Shilin
Принадлежит:

A method of designing a drill bit is disclosed. The method includes determining a location of a bit coordinate system in a wellbore coordinate system and generating a bit profile based on an angular coordinate around a wellbore axis of a wellbore and the location of the bit coordinate system. The bit profile is based on a cutting edge of a first cutting element on an exterior portion of a first blade. The method also includes determining a cutting layer volume based on the bit profile and identifying a weak zone based on the cutting layer volume being less than a predefined minimum cutting layer volume. The method includes determining a location for a second cutting element on the exterior portion of a second blade based on the weak zone. 1. A method of designing a drill bit , the method comprising:determining a location of a bit coordinate system in a wellbore coordinate system;generating a bit profile for a drill bit based on an angular coordinate around a wellbore axis of a wellbore and the location of the bit coordinate system, the bit profile based on a cutting edge of a first cutting element on an exterior portion of a first blade on the drill bit;determining a cutting layer volume based on the bit profile;identifying a weak zone based on the cutting layer volume being less than a predefined minimum cutting layer volume; anddetermining a location for a second cutting element on the exterior portion of a second blade based on the weak zone.2. The method of claim 1 , further comprising obtaining a radial coordinate based on the wellbore axis for the weak zone.3. The method of claim 2 , further comprising adjusting the radial coordinate based on a bit axis of the drill bit.4. The method of claim 3 , wherein locating the second cutting element is based on the adjusted radial coordinate.5. The method of claim 1 , wherein the location of the weak zone is in a cone zone of the first blade.6. The method of claim 1 , wherein the second cutting element is track set with ...

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Номер записи: 59
09-01-2020 дата публикации

Subterranean Valve Testing, Lubricating, and Sealing Device

Номер: US20200011152A1
Автор: Kravitch Nick C.
Принадлежит:

A sealant gun is inserted into a limited space work area to engage a buttonhead fitting supported by a fitting assembly perpendicular to a valve stem extending from a tapered plug valve. The fitting assembly orients the buttonhead fitting on the valve stem for movement of the sealant gun in a single vertical direction to engage the buttonhead fitting. The sealant gun injects a sealant under pressure through the buttonhead fitting and the valve stem into a tapered bore of the valve body. The tapered bore receives a tapered plug on the end of the valve stem for movement into and out of a closed valve position with the tapered bore. The sealant is injected between the tapered plug and the tapered bore to provide a seal therebetween that prevents the escape of the fluid flowing through the valve from the valve through the valve stem to the atmosphere. 1. A fitting assembly for sealing a stem of a tapered plug valve having a body with a tapered bore for receiving between open and closed positions a tapered plug extending from the end of the stem comprising:a base having a lower surface with a first opening positioned therein and an upper surface having a vertical member projecting therefrom,the first opening having a preselected dimension for receiving a tubular threaded member extending from the valve stem,said vertical member having a second opening with a preselected dimension, said second opening extending perpendicular to the valve stem,a buttonhead fitting extending from said second opening on said vertical member, the buttonhead fitting including a check valve,the buttonhead fitting extending from the second opening on the vertical member in perpendicular alignment with the tubular threaded member extending from the valve stem, andthe base having an internal passageway connecting the first opening to the second opening to transmit a sealant under pressure from the buttonhead fitting into the valve body between opposing surfaces of the tapered plug and the tapered ...

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Номер записи: 60
09-01-2020 дата публикации

Streamlined Valve Assembly for Downhole Pump of Reciprocating Pump System

Номер: US20200011154A1
Автор: John E. Stachowiak, Jr.
Принадлежит: Weatherford Technology Holdings LLC

A downhole pump used for a reciprocating pump system includes a barrel coupling to a tubing string and having a standing valve and includes a plunger coupling to a rod string and having a traveling valve. One or both of the valves can include an assembly comprising a housing, an insert, a ball, and a seat. The insert allowing for flow therethrough defines a ball stop at one end has a ball passage at the other end. The insert positions in flow passage of the housing, and one of the ends engages a shoulder in the passage. The insert includes sidewalls and a conical body to reduce turbulence, flow velocity, gas breakout, ball chatter, and the like.

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Номер записи: 61
10-01-2019 дата публикации

DEVICE AND METHOD FOR PARALLEL PRESSURE-VOLUME-TEMPERATURE ANALYSIS USING GAS CHROMATOGRAPHY AND MASS SPECTROMETRY

Номер: US20190011594A1
Автор: Atkinson Robert S., Chen Songhua, Jones Christopher M., T.Pelletier Michael
Принадлежит:

A device and method is described to parallelize a pressure-volume-temperature (“PVT”) analysis using gas chromatography and mass spectrometry techniques such that a portion of the pressure, temperature and volume analysis is performed separately from others. The resulting PVT data is then recombined statistically for a complete PVT analysis. The device may also obtain compositional data of the fluid to perform an equation of state analysis or reservoir simulations. 1. A method to perform a pressure-volume-temperature (“PVT”) analysis of wellbore fluid , the method comprising:receiving a wellbore fluid sample into an inlet port of a PVT device;communicating a volume of the fluid sample to one or more channels within the PVT device, wherein an analysis apparatus is positioned adjacent the channels;interacting the analysis apparatus with the fluid sample volume in the channels to perform a gas chromatography technique and mass spectrometry technique on the fluid sample volume;in response to the interaction, using the analysis apparatus to generate one or more signals corresponding to characteristics of the fluid sample volume; andusing processing circuitry, performing a PVT analysis based upon the signals.2. The method as defined in claim 1 , wherein the PVT device controls or alters a temperature or pressure of the fluid sample prior to interaction with the analysis apparatus.3. The method as defined in claim 2 , wherein the PVT device at least partially changes a phase of the fluid sample.4. The method as defined in claim 3 , wherein:PVT device changes the sample fluid to a gas state; orthe change includes a precipitation of asphaltenes.5. The method as defined in claim 4 , wherein a semi-permeable membrane or gas membrane extracts the gas state of the sample fluid.6. The method as defined in claim 1 , wherein the analysis apparatus measures at least one of an inorganic gas claim 1 , CO claim 1 , HS claim 1 , organic gas claim 1 , methane (C1) claim 1 , ethane (C2) ...

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Номер записи: 62
15-01-2015 дата публикации

DOWNHOLE TOOL HAVING A SHOCK-ABSORBING SLEEVE

Номер: US20150013991A1
Автор: ANDREYCHUK Mark, ANGMAN Per, BAUDISTEL Chris, GRAF Kevin
Принадлежит:

An apparatus having a shock-absorbing sleeve is disclosed. The apparatus comprises a housing, an axially moveable sleeve received in the housing and a sealed annular space having a fixed volume axially between the housing and the sleeve. A barrier axially moveable with the sleeve divides the annular space into a first and a second chambers. The first and second chambers are filled with uncompressible dampening fluid. One or more metering passages across the barrier fluidly connect the first and chambers. During the axial movement of the sleeve, the volume of the first chamber is reduced and that of the second chamber is increased, forcing the fluid in the first chamber to flow into the second chamber in a controlled manner to dampen the movement of the sleeve. 1. A downhole apparatus comprising:a tubular housing along a tubing string;a sleeve located within the housing and axially moveable therein from a first position to a second position; anda first annular chamber radially intermediate the housing and the sleeve, said first annular chamber containing a first dampening fluid and being capable of controllably releasing the first dampening fluid under pressure; whereinwhen the sleeve moves from the first position to the second position, the first dampening fluid is pressurized and controllably released for controlling the speed of the sleeve movement.2. The apparatus of wherein the first dampening fluid is a substantially incompressible fluid.3. The apparatus of wherein the first dampened fluid is grease.4. The apparatus of wherein the first dampened fluid has a viscosity index in the range between 80 and 110.5. The apparatus of wherein the first dampened fluid has a viscosity index of 90.6. The downhole apparatus of further comprising:a second annular chamber radially intermediate the housing and the sleeve, and axially immediately adjacent the first annular chamber; wherein the second annular chamber is in fluid communication with the first chamber for receiving ...

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Номер записи: 63
15-01-2015 дата публикации

DOWNHOLE TOOL AND METHOD

Номер: US20150013997A1
Автор: Simpson Neil Andrew Abercrombie
Принадлежит:

A method of manufacture and installation of a resizable, plastically deformable or crimpable elastomeric bearing collar or stabilizer sleeve which can be installed over upset sections of rotary drilling and wellbore completion tubulars such as but not limited to subs, drill collars, drill pipe, wellbore casing, production liners and other drilling and production related tubulars that are nm down-hole. In order to enable the reduction of rotational torque generated when directionally drilling and completing extended reach development (ERD) wells. 1. A downhole tool comprising a collar for location on a tubular body , the collar reconfigurable from a first diameter configuration to a second , smaller , diameter configuration.2. (canceled)3. (canceled)4. (canceled)5. (canceled)6. (canceled)7. (canceled)8. The tool of claim 1 , wherein the collar is rotatably mounted on the tubular body.9. (canceled)10. (canceled)11. The tool of claim 1 , wherein the collar comprises or forms part of a bearing claim 1 , optionally a fluid lubricated bearing.12. (canceled)13. (canceled)14. (canceled)15. The tool of claim 1 , wherein the collar comprises a deformable portion claim 1 , wherein the deformable portion permits reconfiguration of the collar from the first diameter configuration to the second diameter configuration.16. (canceled)17. The tool of claim 15 , wherein the deformable portion comprises a ductile material claim 15 , optionally a ductile metal.18. (canceled)19. (canceled)20. (canceled)21. (canceled)22. The tool of claim 1 , wherein the collar comprises a core.23. The tool of claim 22 , wherein the core comprises a cylindrical tubular body claim 22 , or ring.24. (canceled)25. The tool of claim 22 , wherein the core comprises or forms part of a deformable portion of the collar.26. The tool of claim 1 , wherein the collar comprises at least one outer layer.27. (canceled)28. (canceled)29. (canceled)30. (canceled)31. (canceled)32. (canceled)33. (canceled)34. The tool of ...

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Номер записи: 64
15-01-2015 дата публикации

Methods for Assaying Polymers Using an Integrated Computational Element

Номер: US20150015884A1
Автор: Freese Robert P., Haggstrom Johanna, Russell Aaron Gene
Принадлежит:

Various molecular characteristics of a polymer may be determined using an integrated computational element to assay the polymer. Methods for assaying a polymer can comprise optically interacting electromagnetic radiation with a polymer and an integrated computational element; and determining a molecular characteristic of the polymer, using the integrated computational element. The molecular characteristic of the polymer may be used to determine a bulk characteristic of a fluid phase in which the polymer may be disposed. 1. A method comprising:optically interacting electromagnetic radiation with a polymer and an integrated computational element; anddetermining a molecular characteristic of the polymer, using the integrated computational element.2. The method of claim 1 , wherein the molecular characteristic of the polymer comprises a polymer property selected from the group consisting of molecular weight claim 1 , molecular weight distribution claim 1 , degree of crosslinking claim 1 , degree of branching claim 1 , degree of substitution claim 1 , uniformity of substitution claim 1 , crystallinity claim 1 , crystalline melting temperature claim 1 , glass transition temperature claim 1 , and any combination thereof.3. The method of claim 1 , wherein the polymer is optically interacted as a solid phase with the electromagnetic radiation.4. The method of claim 1 , wherein the polymer is present in a fluid phase while optically interacting with the electromagnetic radiation.5. The method of claim 4 , further comprising:determining a bulk characteristic of the fluid phase from the molecular characteristic of the polymer.6. The method of claim 5 , wherein the bulk characteristic comprises a viscosity of the fluid phase.7. The method of claim 4 , wherein the fluid phase comprises a treatment fluid.8. The method of claim 1 , further comprising:detecting the electromagnetic radiation that has optically interacted with the polymer and the integrated computational element; ...

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Номер записи: 65
19-01-2017 дата публикации

Laser Propelled Tractor with Laser Operated Logging Tools

Номер: US20170016291A1
Автор: Al Dabbous Mohammed Saeed, Lewis David Rucker
Принадлежит: Saudi Arabian Oil Company

A method for maneuvering and operating a tool within a wellbore of a subterranean well includes providing a tractor assembly having a fluid chamber with a port extending through a sidewall of the fluid chamber. The port is moved to the open position to allow a well fluid of the subterranean well to flow into the fluid chamber. The port is moved to the closed position to prevent the well fluid from flowing between the interior of the fluid chamber and the exterior of the fluid chamber. A heating laser beam is generated with a laser and directed towards the fluid chamber to increase the temperature of the well fluid within the fluid chamber. The port is moved to the open position to allow the high heat well fluid to flow out of the fluid chamber to accelerate the tractor assembly within the wellbore. 1. A method for maneuvering and operating a tool within a wellbore of a subterranean well , the method comprising:(a) providing a tractor assembly having a fluid chamber with a port extending through a sidewall of the fluid chamber, the port moveable between an open position and a closed position(b) moving the port to the open position to allow a well fluid of the subterranean well to flow into the fluid chamber;(c) moving the port to the closed position to prevent the well fluid from flowing between the interior of the fluid chamber and the exterior of the fluid chamber;(d) generating a heating laser beam with a laser mounted adjacent to the fluid chamber and directing the heating laser beam towards the fluid chamber to increase a temperature of the well fluid within the fluid chamber to generate a high heat well fluid; and(e) moving the port to the open position to allow the high heat well fluid to flow out of the fluid chamber to accelerate the tractor assembly within the wellbore.2. The method according to claim 1 , wherein the steps of moving the port to the open position and moving the port to the closed position includes signaling the port with an opening control ...

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Номер записи: 66
19-01-2017 дата публикации

Multi-Run Retrievable Battery Pack for Electronic Slickline Tools

Номер: US20170016293A1
Автор: Jack Gammill Clemens, Matthew Craig Mlcak, Sean Gregory THOMAS
Принадлежит: Halliburton Energy Services Inc

A downhole tool assembly includes a downhole tool and an anchor. The anchor is positionable at a downhole work site and includes a wet-connect port for engaging a battery pack. The tool operates until the battery runs low on power, when a low battery power alert is activated. The tool may be anchored at the work site while the battery is disconnected and retrieved to the surface for replacement. One or more charged batteries are then deployed and connected to the tool without having to remove the tool from the worksite or reposition the tool. The tool may be coupled to a wireline cable or a slickline cable or coiled tubing having a conductive wire for delivering low-voltage power to the tool. While the low-voltage power may not be adequate to operate the tool at full load, the power may be used to charge the tool during downtime.

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Номер записи: 67
19-01-2017 дата публикации

Tar Mat Formation Prediction in Late-Charge Reservoirs

Номер: US20170016321A1
Автор: Kang Wang, Oliver C. Mullins, Shu PAN, Yi Chen, Youxiang Zuo
Принадлежит: Schlumberger Technology Corp

A downhole tool, surface equipment, and/or remote equipment are utilized to obtain data associated with a subterranean hydrocarbon reservoir, fluid contained therein, and/or fluid obtained therefrom. At least one condition indicating that a density inversion exists in the fluid contained in the reservoir is identified from the data. Molecular sizes of fluid components contained within the reservoir are estimated from the data. A model of the density inversion is generated based on the data and molecular sizes. The density inversion model is utilized to estimate the density inversion amount and depth and time elapsed since the density inversion began to form within the reservoir. A model of a gravity-induced current of the density inversion is generated based on the data and the density inversion amount, depth, and elapsed time.

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Номер записи: 68
21-01-2016 дата публикации

HOLE OPENER AND METHOD FOR DRILLING

Номер: US20160017666A1
Автор: Beauchamp Sonny
Принадлежит:

The present document describes a drill-bit which achieves both the rigidity and a fast rate of penetration. The drill-bit comprises a cone shaped central portion comprising a plurality of ribs protruding from the central portion and defining a plurality of blades. The blades are curved along a direction of a longitudinal axis of the cone to facilitate insertion into a hole when rotating in a first direction, and exit from the hole when rotating in a second direction opposite the first direction. The drill-bit comprises a plurality of polycrystalline diamond cutters (PDC) on the blades provided in a first position for cutting the hard structure as the drilling-bit rotates in the first direction, and a plurality of up-drill PDC cutters provided in a second position for cleaning the hole as the drill-bit rotate in the second direction to exit the hole. 1. A drill-bit for drilling holes in a hard structure , the drill-bit comprising:a cone shaped central portion defining an upper end and a lower end;a plurality of ribs protruding from the central portion and defining a plurality of blades, the blades being curved along a direction of a longitudinal axis of the cone to facilitate insertion into a hole when rotating in a first direction, and exit from the hole when rotating in a second direction opposite the first direction;a first set of polycrystalline diamond cutters PDC provided on the blades for cutting the hard structure as the drilling-bit rotates in the first direction.2. The drill-bit of claim 1 , wherein the blades comprise:an upper portion comprising the first set of PDC cutters along an edge thereof for cutting the hard structure as the drilling-bit rotates in the first direction;a middle portion which is substantially parallel to the longitudinal axis for stabilizing the drill-bit when rotating within the hole and for refining an inner surface of the hole; anda lower portion defining a slope starting from the middle portion and ending at the lower end.3. The ...

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Номер записи: 69
21-01-2016 дата публикации

Pressure Activated Cyclical Valve Apparatus and Method

Номер: US20160017690A1
Автор: Baudoin Toby Scott
Принадлежит:

A bypass tool has a piston movable within the bore of a central housing. A control slot on an exterior wall of the piston engages a slot pin in the housing. Longitudinal movement of the piston is downward, in response to fluid pressure exerted on a ball seated on a ball seat on the piston; and spring biased upward. The control slot and slot pin rotate the piston as it moves longitudinally between a first, upper position in which bypass ports in the housing are closed, and a second, lower position in which the bypass ports are open. An intermediate longitudinal position has the ports closed, and permits pressuring up on a ball to force it through the ball seat and reset the tool in the flow through position. The ball and/or ball seat may be of resilient material to permit passage of the ball through the seat.

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Номер записи: 70
18-01-2018 дата публикации

Anti-Balling Drill Bit and Method of Making Same

Номер: US20180016848A1
Автор: Anil Kumar, Rajagopala Pillai, Walter R. Rothrock, Jr.
Принадлежит: National Oilwell DHT LP

A drill bit for drilling a wellbore penetrating a subterranean formation is disclosed. The drill bit includes a bit body having a surface about a working end thereof, ribs extending from the surface of the bit body with channels defined therebetween, cutting elements positionable on the ribs to cuttingly engage the subterranean formation and release cuttings therefrom, and an anti-balling composition. The anti-balling composition includes a hardphase having a chemical potential that is more electronegative than the surface. The anti-balling composition is disposed on a surface of the bit body whereby the cuttings from the wellbore are prevented from collecting on the bit body.

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Номер записи: 71
18-01-2018 дата публикации

NESTED FLAPPER SPRING

Номер: US20180016866A1
Автор: Caminari Richard T., Coss Frank Edward
Принадлежит:

A device in accordance to an embodiment includes a tubular housing having an inside diameter defining an axial bore, a top surface and an outer surface, a groove formed along the outer surface below the top surface, a flapper pivotally connected with the housing and pivotal between an open position to allow flow through the bore and a closed position to block flow through the bore and a torsion spring having a spring diameter and disposed in the groove and in connection with the flapper to bias the flapper to one of the open and the closed position. The torsion spring may be nested in a C-shaped groove. 1. A device , comprising:a tubular housing having an inside diameter defining an axial bore, a top surface and an outer surface;a groove formed along the outer surface below the top surface;a flapper connected with the housing and pivotal between an open position to allow flow through the bore and a closed position to block flow through the bore; anda torsion spring having a spring diameter and disposed in the groove and in connection with the flapper to bias the flapper to one of the open and the closed position.2. The device of claim 1 , wherein the groove is substantially C-shaped having a slot along the outer surface with a diameter less than the spring diameter.3. The device of claim 1 , wherein the torsion spring has a first tab in contact with the flapper and a second tab in contact with the housing.4. The device of claim 1 , wherein the torsion spring has a first tab in contact with the flapper and a second tab positioned in a recess on the outer surface of the housing.5. The device of claim 1 , wherein the groove is substantially C-shaped having a slot along the outer surface with a diameter less than the spring diameter; andthe torsion spring comprises a first tab in contact with the flapper and a second tab in contact with the housing.6. The device of claim 1 , wherein the groove is substantially C-shaped having a slot along the outer surface with a ...

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Номер записи: 72
18-01-2018 дата публикации

SOFT SEAT RETENTION

Номер: US20180016867A1
Автор: Caminari Richard T., Coss Frank Edward
Принадлежит:

A device, such as a valve, having a soft seat disposed in a groove formed in and circumferentially along a hard seating surface of a hard seat and one or more retaining elements disposed in the groove in contact with the soft seat and the hard seat. 1. A device , comprising:a hard seat comprising a hard sealing surface extending circumferentially about an axial bore and having an inner circumferential edge and an outer circumferential edge; anda soft seat disposed circumferentially along the hard sealing surface between the inner and the outer circumferential edges.2. The device of claim 1 , wherein the hard sealing surface is curved.3. The device of claim 1 , wherein the soft seat is a circular member formed of a pliable material.4. The device of claim 1 , wherein the soft seat is positioned in a groove formed in the hard sealing surface.5. The device of claim 1 , further comprising:a groove formed in and circumferentially along the hard sealing surface between the inner and outer edges, the soft seat positioned in the groove and having a soft sealing surface positioned above the hard sealing surface; anda retainer element disposed in the groove and in contact with the soft seat and the hard seat.6. The device of claim 5 , wherein the retainer element is disposed between the soft seat and the outer circumferential edge.7. The device of claim 5 , wherein the retainer element is an elongated member.8. The device of claim 5 , wherein the retainer element is an elongated member extending circumferentially or substantially circumferentially along the length of the soft seat.9. The device of claim 5 , wherein the retainer element comprises two or more elements spaced circumferentially apart.10. The device of claim 1 , further comprising:a groove formed in and circumferentially along the hard sealing surface between the inner and outer edges, the soft seat positioned in the groove and having a soft sealing surface positioned above the hard sealing surface;an undercut ...

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Номер записи: 73
18-01-2018 дата публикации

REVOLVED SEAT LINE FOR A CURVED FLAPPER

Номер: US20180016868A1
Автор: Caminari Richard T.
Принадлежит:

A device, such as a valve, includes a hard seat having an axial bore extending along a central axis. A flapper pivotally connected with the hard seat at a hinge axis and pivotal between an open position to allow flow through the bore and a closed position to block flow through the bore, the flapper having a flapper sealing surface that slopes inward toward the central axis along a full circumference of the flapper sealing surface and the hard seat having a hard sealing surface that slopes inward toward the central axis conforming to the flapper sealing surface and on which the flapper sealing surface bears when in the closed position. 1. A device , comprising:a hard seat having an axial bore extending along a central axis;a flapper pivotally connected with the hard seat at a hinge axis and pivotal between an open position to allow flow through the bore and a closed position to block flow through the bore, the flapper having a flapper sealing surface that slopes inward toward the central axis along a full circumference of the flapper sealing surface; andthe hard seat having a hard sealing surface that slopes inward toward the central axis conforming to the flapper sealing surface and on which the flapper sealing surface bears when in the closed position.2. The device of claim 1 , wherein the flapper is a curved flapper having an undulating flapper sealing surface.3. The device of claim 1 , wherein the inward sloping flapper sealing surface provides a rotational axis of freedom to lap the flapper sealing surface with the hard sealing surface.4. The device of claim 3 , wherein the flapper is a curved flapper having an undulating flapper sealing surface.5. The device of claim 1 , wherein the inward sloping flapper sealing surface provides a rotational axis of freedom about an axis normal to the hinge axis to lap the flapper sealing surface with the hard sealing surface.6. The device of claim 5 , wherein the flapper is a curved flapper having an undulating flapper ...

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Номер записи: 74
18-01-2018 дата публикации

BACKFLOW PREVENTION ASSEMBLY FOR DOWNHOLE OPERATIONS

Номер: US20180016869A1
Автор: Gatzen Matthias, Hartmann Jannik Paul, Regener Thorsten
Принадлежит: BAKER HUGHES INCORPORATED

Backflow prevention assemblies and methods for downhole systems having outer strings and inner strings include a housing defining a cavity and being part of the outer string, a flow tube disposed between the inner string and the outer string movable axially within the outer string, and a backflow prevention structure having a flapper and a seal seat, the flapper biased toward a closed position and maintained in an open position by the flow tube. The flapper is housed within the cavity when in the open position and the flapper and seal seat form a fluid seal to prevent fluid flow into or through the flow tube when in the closed position. When the flow tube is moved from a first position that maintains the flapper in the open position to a second position, the backflow prevention structure operates to close the flapper and seal the backflow prevention structure. 1. A backflow prevention assembly of a downhole system including an outer string and an inner string movable within the outer string , the backflow prevention assembly comprising:a housing defining a cavity, the housing being part of the outer string;a movable flow tube located within the housing and disposed between the inner string and the outer string, the movable flow tube movable axially within the outer string; anda backflow prevention structure having a flapper and a seal seat, the flapper biased toward a closed position and maintained in an open position by the movable flow tube, wherein the flapper is housed within the cavity of the housing when in the open position, and wherein the flapper and seal seat form a fluid seal to prevent fluid flow into or through the movable flow tube when in the closed position,wherein when the movable flow tube is moved from a first position that maintains the flapper in the open position to a second position, the backflow prevention structure operates to close the flapper to the seal seat and seal the backflow prevention structure.2. The backflow prevention assembly of ...

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Номер записи: 75
18-01-2018 дата публикации

DOWNHOLE TOOL WITH AN ISOLATED ACTUATOR

Номер: US20180016870A1
Автор: Buchheit Megan Laura, Hill Steven Nicholas, Pinard Geoffrey
Принадлежит:

A downhole tool in accordance to aspects of the disclosure includes a housing forming a bore to convey a wellbore fluid, an actuating piston moveably disposed in a cylinder located in the housing adjacent to the bore and a barrier fluid isolating the actuating piston from the bore. The downhole tool may include a compensator piston in communication with the barrier fluid and the bore that is moveable to balance the pressure between the barrier fluid and the bore. 1. A downhole tool , the downhole tool comprising:a housing forming a bore to convey a wellbore fluid;an actuating piston moveably disposed in a cylinder located in the housing adjacent to the bore; anda barrier fluid isolating the actuating piston from the bore.2. The downhole tool of claim 1 , further comprising a compensator piston in communication with the barrier fluid and the bore claim 1 , the compensator piston moveable to balance the pressure between the barrier fluid and the bore.3. The downhole tool of claim 1 , further comprising a compensator piston in communication with the barrier fluid and the bore claim 1 , the compensator piston moveable to balance the pressure between the barrier fluid and the bore; anda check valve device adapted to selectively allow fluid to flow across the compensator piston between the bore and the barrier fluid.4. The downhole tool of claim 3 , wherein the compensator piston comprises the check valve device.5. The downhole tool of claim 1 , wherein the actuating piston comprises piston seals claim 1 , the piston seals isolated from the bore by the barrier fluid; andthe compensator piston is moveably disposed in a second cylinder located in the housing.6. The downhole tool of claim 1 , further comprising a tool actuator operationally coupled with the actuating piston to move in unison with the actuating piston in a first direction; andseals on the tool actuator isolating the actuating piston from the bore, wherein the barrier fluid is contained by the seals.7. The ...

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Номер записи: 76
18-01-2018 дата публикации

SYSTEMS AND METHODS FOR MANAGING DEBRIS IN A WELL

Номер: US20180016872A1
Автор: RANDLE Bryce Elliott
Принадлежит:

Various systems, methods, and devices are disclosed for handling contaminants in a wellbore or riser. A washpipe debris trap (WPDT) traps contaminants traveling up a wellbore from a downhole location, and the WPDT may serve as an indicator for a breached screen in a downhole location. A marine riser reversing tool (MRRT) may reverse the flow of fluid between a workstring conduit and an annulus between the workstring and the wellbore such that fluid rises to the wellhead with greater velocity. A bi-directional chamber trap (BDCT) may be utilized in a wellbore operation to remove contaminants from a fluid. 1. A device for trapping debris , comprising:a lower assembly having a lower screen and a check valve, wherein the lower screen is a thru-tubing screen;an upper assembly having an upper screen and a check valve, wherein the upper screen is a thru-tubing screen, and wherein the check valve of the upper assembly is a ball check valve having a ball with a first density that is buoyant when submerged in fluid having a second density, wherein the second density is larger than the first density;an assembly bridge formed between the lower assembly and the upper assembly; andwherein the check valve of the lower assembly is a ball check valve that is closed when the fluid flows in a forward direction, allowing only the fluid and debris smaller than a gauge of the thru-tubing screen of the lower assembly to leave the assembly bridge, and open when the fluid flows in a reverse direction, allowing the fluid and debris to enter the assembly bridge.2. The device of claim 1 , wherein the ball check valve of the upper assembly is open when the fluid flows in a forward direction claim 1 , allowing the fluid and debris to enter the assembly bridge claim 1 , and closed when the fluid flows in a reverse direction claim 1 , allowing only the fluid and debris smaller than a gauge of the thru-tubing screen of the upper assembly to leave the assembly bridge.3. The device of claim 1 , ...

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Номер записи: 77
18-01-2018 дата публикации

Pressurized Chamber Management

Номер: US20180017201A1
Автор: Cygan Adam Zygmunt, Del Campo Christopher, Dupont Hugues, Irvine Christopher, Parks Stephen Dennis, Ugalde Alien
Принадлежит:

Apparatus and methods for filling a pressure compensated fluid container with a liquid. An example method includes restraining movement of a piston slidably disposed within the fluid container in a first piston position, wherein the piston divides the fluid container into first and second portions. The method further includes pumping the liquid into the first portion to compress gas located within the first portion, stopping the pumping of the liquid into the first portion, and stopping the restraining of movement of the piston to permit the piston to move to a second piston position due to expansion of the gas compressed within the first portion. 1. An apparatus comprising: a chamber comprising a port; and', maintain the piston in a first piston position within the chamber while the first portion receives a liquid via the port to compress gas located within the first portion; and', 'permit the piston to move to a second piston position due to expansion of the gas compressed within the first portion., 'a piston slidably disposed within the chamber and dividing the chamber into first and second portions, wherein the first portion is fluidly connected with the port and the second portion is in fluid communication with a space external to the apparatus, and wherein during liquid filling operations the apparatus is operable to], 'a pressure compensated fluid containment system comprising2. The apparatus of wherein the port is a first port claim 1 , wherein the chamber further comprises a second port fluidly connected with the first portion claim 1 , and wherein during the liquid filling operations the apparatus is further operable introduce the liquid into the first portion via the first port and discharge the liquid from the first portion via the second port to flush out the gas located within the first portion.3. The apparatus of wherein the first piston position within the chamber is selectable based at least partially on a coefficient of compression of the liquid ...

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Номер записи: 78
18-01-2018 дата публикации

Multipurpose Permanent Electromagnetic Sensing System for Monitoring Wellbore Fluids and Formation Fluids

Номер: US20180017697A1
Автор: Donderici Burkay, FOUDA Ahmed E., Mandviwala Tasneem, Samson Etienne
Принадлежит:

Methods and systems of electromagnetic sensing in a wellbore are presented in this disclosure for monitoring annulus fluids and water floods. An array of transmitters and one or more receivers are located along a casing in the wellbore. A transmitter in the array and one of the receivers can be mounted on a same collar on the casing forming a transmitter-receiver pair. The receiver can receive a signal originating from the transmitter and at least one other signal originating from at least one other transmitter in the array, wherein the signal is indicative of a fluid in the wellbore in a vicinity of the transmitter-receiver pair and the at least one other signal is indicative of another fluid in a formation around the wellbore. The receiver can further communicate, via a waveguide, the signal and the at least one other signal to a processor for signal interpretation. 1. A dual-purpose electromagnetic sensing system for monitoring wellbore fluids and formation fluids , the system comprising:an array of transmitters and one or more receivers located along a casing in a wellbore, whereina transmitter in the array of transmitters and a receiver of the one or more receivers are mounted on a same collar on the casing forming a transmitter-receiver pair,the receiver receives a signal originating from the transmitter and at least one other signal originating from at least one other transmitter in the array of transmitters, the signal being indicative of a fluid in the wellbore in a vicinity of the transmitter-receiver pair and the at least one other signal being indicative of another fluid in a formation around the wellbore, andthe receiver communicates, via a waveguide, the signal and the at least one other signal to a processor.2. The system of claim 1 , wherein another transmitter of the array of transmitters and another receiver of the one or more receivers forming another transmitter-receiver pair are mounted on a different collar on the casing.3. The system of claim ...

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Номер записи: 79
18-01-2018 дата публикации

OIL VISCOSITY PREDICTION

Номер: US20180017699A1
Автор: Chen Songhua, Chen Yuesheng, Sandor Magadelna Traico
Принадлежит:

Various embodiments include a method for determining a viscosity for heavy oil in a formation by obtaining viscosity data and nuclear magnetic resonance (NMR) relaxation time distribution data for a plurality of oil samples. A correlation is determined between a set of viscosity data for the plurality of oil samples and an NMR relaxation time geometric mean for the plurality of oil samples. An NMR relaxation time geometric mean intrinsic value is determined based on the correlation, apparent hydrogen index, and T. Electromagnetic energy may then be transmitted into a formation and NMR relaxation time distributions determined for oil in the formation based on secondary electromagnetic field responses associated with the electromagnetic energy. A viscosity of the oil in the formation may then be determined based a correlation between the set of viscosity data and the NMR relaxation time geometric mean intrinsic value of the distribution data. 1. A method , comprising:transmitting electromagnetic energy into a formation;measuring NMR relaxation time distribution data for oil in the formation based on secondary electromagnetic field responses associated with the electromagnetic energy; and{'sub': 'E', 'determining a viscosity of the oil in the formation based on a correlation between a set of viscosity data and an NMR relaxation time geometric mean intrinsic value of distribution data derived from an echo spacing time (T) and/or a hydrogen index (HI).'}2. The method of claim 1 , further comprising:obtaining the set of viscosity data and nuclear magnetic resonance (NMR) relaxation time distribution data for a plurality of oil samples;determining the NMR relaxation time geometric mean intrinsic value for the distribution data; anddetermining the correlation between the set of viscosity and the NMR relaxation time geometric mean for the NMR relaxation time distribution data.3. The method of claim 2 , further comprising:obtaining hydrogen indexes for the plurality of oil ...

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Номер записи: 80
17-01-2019 дата публикации

SUPER HARD CONSTRUCTIONS & METHODS OF MAKING SAME

Номер: US20190017330A1
Автор: Bowes David Christian
Принадлежит: ELEMENT SIX (UK) LIMITED

A super hard construction comprises a substrate comprising a peripheral surface, an interface surface and a longitudinal axis extending in a plane and a super hard material layer formed over the substrate and having an exposed outer surface, a peripheral surface extending therefrom and an interface surface. One of the interface surface of the substrate or the interface surface of the super hard material layer comprises one or more projections arranged to project from the interface surface, the one or more projections being spaced from the peripheral surface of the substrate and a peripheral flange extending between the peripheral side edge and the interface surface. The peripheral flange is inclined at an angle of between around 5 degrees to around 30 degrees to a plane substantially perpendicular to the plane through which the longitudinal axis extends. 1. A super hard construction comprising:a substrate comprising a peripheral surface, an interface surface and a longitudinal axis extending in a plane; anda super hard material layer formed over the substrate and having an exposed outer surface, a peripheral surface extending therefrom and an interface surface;wherein one of the interface surface of the substrate or the interface surface of the super hard material layer comprises:one or more projections arranged to project from the interface surface; the one or more projections being spaced from the peripheral surface of the substrate; anda peripheral flange extending between the peripheral side edge and the interface surface, the peripheral flange being inclined at an angle of between around 5 degrees to around 30 degrees to a plane substantially perpendicular to the plane through which the longitudinal axis extends.2. The super hard construction of claim 1 , wherein the peripheral flange is substantially concentric with the substrate.3. The super hard construction of claim 1 , wherein the flange extends to the peripheral side edge.4. The super hard construction of ...

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Номер записи: 81
17-01-2019 дата публикации

SURFACE CONTROLLED REVERSIBLE COILED TUBING VALVE ASSEMBLY

Номер: US20190017333A1
Автор: Bolze Victor M., Burgos Rex, Kharrat Wassim, Shampine Rod
Принадлежит:

A valve assembly for reversibly governing fluid flow through coiled tubing equipment. Valves of the assembly may be directed by a telemetric line running from an oilfield surface. In this manner, valve adjustment and/or reversibility need not require removal of the assembly from the well in order to attain manual accessibility. Similarly, operation of the valves is not reliant on any particular flow rate or other application limiting means. As such, multiple fluid treatments at a variety of different downhole locations may take place with a reduced number of trips into the well and without compromise to flow rate parameters of the treatments. 1. A coiled tubing valve assembly for deployment from an oilfield surface , the assembly comprising:a valve disposed within a channel of the assembly for adjustably regulating flow therethrough; anda telemetric mechanism coupled to said valve for governing the regulating of the flow as directed by equipment disposed at the oilfield surface.2. The assembly of wherein said telemetric mechanism is of a fiber optic configuration.3. The assembly of further comprising:an actuating element coupled to said valve to drive the regulating; andan electronics housing to interface said element and said fiber optic telemetric mechanism to provide the coupling thereof to said valve.4. The assembly of wherein said actuating element comprises one of a downhole pump claim 3 , a downhole motor claim 3 , a piezo-electric stack claim 3 , a magnetostrictive material claim 3 , a shape memory material claim 3 , and a solenoid.5. The assembly of wherein said valve is configured to perform one of a check valve function and a backpressure valve function.6. The assembly of wherein said valve comprises a first valve governing a first passage claim 1 , the assembly further comprising a second valve governing a second passage claim 1 , the passages configured to be independently opened as directed by communications over said telemetric mechanism.7. The ...

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Номер записи: 82
17-01-2019 дата публикации

APPARATUS, SYSTEMS, AND METHODS FOR FRACTURING A GEOLOGICAL FORMATION

Номер: US20190017363A1
Автор: Anders Edward O.
Принадлежит:

The present disclosure relates, according to some embodiments, to apparatus, systems, and methods of fracturing a geological structure including the application of kinetic energy (e.g., from high velocity frack fluid) to a subterranean structure. In some embodiments, the present disclosure relates to apparatus, systems, and methods for delivery of high velocity fluid to a well using a down hole valve and/or throttling system. The present disclosure relates to apparatus, systems, and methods of generating pressure using accumulators (e.g., high pressure accumulators) at the surface of a well. 110.-. (canceled)11. A system for kinetically fracking a subterranean structure , the system comprising:(a) a well in fluid communication with the subterranean structure;(b) a well liner inside the well;(c) a fracking string inside the well liner, the fracking string comprising a central channel; and(d) a fluid velocity activated annular valve configured to abruptly decelerate the fracking fluid.12. A system for kinetically fracking a subterranean structure according to further comprising from one to about twenty additional high pressure gas pumps claim 11 , each independently configured to deliver 1500 to 2000 horsepower.13. A downhole fluid velocity activated annular valve configured for operation in a wellbore with an inserted production liner claim 11 , the valve comprising:(a) an annular body having a longitudinal axis, an interior surface configured to slide along and seal a fracking string, and an exterior surface comprising a taper, the taper extending circumferentially around the exterior surface and extending along at least a portion of the length of the body;(b) an annular packing element contacting and surrounding the taper and configured to translate radially outwardly upon axial movement of the ramp; and(c) at least one aperture configured to align with a corresponding hole in the fracking string and support fluid communication between the inner channel of the ...

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Номер записи: 83
17-01-2019 дата публикации

Fluid Characterization and Phase Envelope Prediction from Downhole Fluid Sampling Tool

Номер: US20190017377A1
Автор: Du Di, Gascooke Darren, GU Ming, He Tian, Jones Christopher Michael, Kallenhbasti Mehdi Alipour, Pelletier Michael T.
Принадлежит: Halliburton Energy Services, Inc.

Disclosed herein are methods and systems for fluid characterization of fluid samples from a downhole fluid sampling tool. A fluid characterization method may include obtaining a fluid sample of a reservoir fluid; analyzing the fluid sample to derive input parameters, wherein the input parameters comprise fluid properties obtained from measurement of the fluid sample; determining component mole fractions of the fluid sample using a mole fraction distribution function; and determining calculated fluid properties using equation of state flash calculating. 1. A fluid characterization method comprising:obtaining a fluid sample of a reservoir fluid;analyzing the fluid sample to derive input parameters, wherein the input parameters comprise fluid properties obtained from measurement of the fluid sample;determining component mole fractions of the fluid sample using a mole fraction distribution function; anddetermining calculated fluid properties using equation of state flash calculating.2. The method of claim 1 , wherein obtaining the fluid sample comprising operating a downhole fluid sampling tool in a wellbore to obtain the fluid sample.3. The method of claim 1 , wherein the fluid properties of the input parameters comprise a component concentration claim 1 , a live oil density claim 1 , and a gas-to-oil ratio.4. The method of claim 3 , wherein the component concentration is a lumped component concentration.5. The method of claim 1 , further comprising obtaining initial values for molecular weight of C6+ components and density of C36+ components of the fluid sample.6. The method of claim 5 , wherein the initial values are used in the mole fraction distribution function to determine component mole fractions.7. The method of claim 1 , wherein the component mole fractions determined using the mole fraction distribution function are delumped component mole fractions of a lumped component concentration obtained in the step of analyzing the fluid sample.9. The method of claim 1 ...

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Номер записи: 84
21-01-2021 дата публикации

COMPOSITE EXPANDABLE METAL ELEMENTS WITH REINFORCEMENT

Номер: US20210017835A1
Автор: Greci Stephen Michael, PELTO Christopher Michael
Принадлежит:

Methods for forming a seal in a wellbore. An example method includes positioning an expandable metal sealing element in the wellbore; wherein the expandable metal sealing element comprises a composite material of expandable metal and a reinforcement material. The expandable metal forms a matrix and the reinforcement material is distributed within the matrix. The method further includes contacting the expandable metal sealing element with a fluid that reacts with the expandable metal to produce a reaction product having a volume greater than the expandable metal. 1. A method for forming a seal in a wellbore comprising: 'a composite material comprising an expandable metal and a reinforcement material; wherein the expandable metal forms a matrix and the reinforcement material is distributed within the matrix;', 'positioning an expandable metal sealing element in the wellbore; wherein the expandable metal sealing element comprisescontacting the expandable metal sealing element with a fluid that reacts with the expandable metal to produce a reaction product having a volume greater than the expandable metal.2. The method of claim 1 , wherein the expandable metal comprises a metal selected from the group consisting of magnesium claim 1 , calcium claim 1 , aluminum claim 1 , and any combination thereof.3. The method of claim 1 , wherein the expandable metal comprises a metal alloy selected from the group consisting of magnesium-zinc claim 1 , magnesium-aluminum claim 1 , calcium-magnesium claim 1 , aluminum-copper claim 1 , and any combination thereof.4. The method of claim 1 , wherein the reinforcement material comprises a material selected from the group consisting of metals claim 1 , ceramics claim 1 , glass claim 1 , plastics claim 1 , and any combination thereof.5. The method of claim 1 , wherein the reinforcement material comprises a shape selected from the group consisting of a rod claim 1 , a ball claim 1 , a mesh claim 1 , and any combination thereof.6. The method ...

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Номер записи: 85
16-01-2020 дата публикации

SLIDING SLEEVE INCLUDING A SELF-HOLDING CONNECTION

Номер: US20200018137A1
Автор: "OBrien Robert", De La Cruz Carlos, Gaudette Sean
Принадлежит: Baker Hughes, a GE company, LLC

A tubular includes an outer surface, an inner surface defining a passage, and a plurality of openings extending through the outer surface and the inner surface. A sleeve is positioned within the passage. The sleeve includes an outer surface portion having at least one recess. At least one release member extends from the inner surface into the at least one recess. The at least one release member maintains the sleeve in a first configuration relative to the plurality of openings. At least one of the inner surface and the outer surface portion includes a self-holding connection that establishes one of a reduced diameter portion of the passage and an increased diameter portion of the sleeve. The self-holding connection is configured to maintain the sleeve in a second configuration axially shifted relative to the first configuration. 1. A tubular comprising:an outer surface, an inner surface defining a passage, and a plurality of openings extending through the outer surface and the inner surface;a sleeve positioned within the passage, the sleeve including an outer surface portion having at least one recess; andat least one release member extending from the inner surface into the at least one recess, the at least one release member maintaining the sleeve in a first configuration relative to the plurality of openings,wherein at least one of the inner surface and the outer surface portion includes a self-holding connection that establishes one of a reduced diameter portion of the passage and an increased diameter portion of the sleeve, the self-holding connection being configured to maintain the sleeve in a second configuration axially shifted relative to the first configuration.2. The tubular according to claim 1 , wherein the self-holding connection comprises a projection formed on the outer surface portion of the sleeve.3. The tubular according to claim 2 , wherein the projection defines an annular rib.4. The tubular according to claim 1 , wherein the sleeve includes a ...

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Номер записи: 86
16-01-2020 дата публикации

Using the specific heat capacity of a drilling fluid to determine other properties thereof

Номер: US20200018147A1
Автор: Brice Aaron JACKSON, Kevin Gregory KLEINGUETL
Принадлежит: Halliburton Energy Services Inc

A method of monitoring and controlling one or more properties of a drilling fluid used in drilling a well is provided. The method comprises circulating the drilling fluid through the wellbore, measuring the specific heat capacity of the drilling fluid, and determining the value of an additional property of the drilling fluid based at least in part on the measured specific heat capacity of the drilling fluid. For example, the additional property of the drilling fluid can be the oil-to-water ratio of the drilling fluid. As another example, the additional property of the drilling fluid can be average specific gravity of the solids in the drilling fluid.

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Номер записи: 87
16-01-2020 дата публикации

Rolling annular seal

Номер: US20200018397A1
Автор: Nicolas Arteaga
Принадлежит: Cameron International Corp

Sealing assemblies with rolling annular seals are provided. In one embodiment, an apparatus includes a stuffing box having a rolling seal positioned in a body for sealing against a tubing or wireline cable received in a bore of the body. The rolling seal can rotate within the body to roll along the tubing or wireline cable in response to movement of the tubing or wireline cable through the body and friction between the rolling seal and the tubing or wireline cable. Additional systems, devices, and methods are also disclosed.

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Номер записи: 88
22-01-2015 дата публикации

ATMOSPHERE TO PRESSURE BALL DROP APPARATUS

Номер: US20150021024A1
Автор: Artherholt Danny, Artherholt Dennis, Gardner Jeremy, McGuire Bob
Принадлежит: OIL STATES ENERGY SERVICES, L.L.C.

An improved ball drop apparatus including an atmosphere-to-pressure frac ball injection chamber. A ball is first inserted into the atmosphere-to-pressure ball injection chamber from a ball feeding apparatus. The ball is then pushed into a pressure equalization section through a first seal pack. In a preferred embodiment, the pressure equalization section is connected to a pressure equalization apparatus and also to the wellbore through a second seal pack. Once the ball is injected into the pressure equalization section, the pressure equalization apparatus applies pressure, thereby causing the pressure of the pressure equalization section to increase until it reaches close to wellbore pressure. Once the pressures of the pressure equalization section and the wellbore are close, the atmosphere-to-pressure frac ball injection chamber and the frac ball are pushed through the second seal pack and into the wellbore, where the frac ball can be pumped downhole. The atmosphere-to-pressure ball injection chamber is then retracted into the pressure equalization section. The pressure equalization section can then be returned to atmospheric or close to atmospheric pressure by the pressure equalization apparatus. The ball injection chamber is then returned to a ball loading position where it may again be loaded by a ball feeding apparatus. 1. A ball drop apparatus , the ball drop apparatus comprising:one or more ball drop receiver sections connected to one or more atmosphere-to-pressure frac ball injection chambers, the ball drop receiver sections configured to feed one or more frac balls into the atmosphere-to-pressure frac ball injection chamber in an initial loading position,one or more first seal packs situated between the initial loading position of the one or more atmosphere-to-pressure frac ball injection chambers and one or more pressure equalization sections,one or more second seal packs situated between the one or more pressure equalization sections and an axial ...

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Номер записи: 89
22-01-2015 дата публикации

TEMPERATURE COMPENSATED ELEMENT

Номер: US20150021030A1
Автор: FRISBY Ray, Greenan Iain, LOGINOV Arthur
Принадлежит:

A time actuated element includes a mandrel, a housing coupled to the mandrel, the housing defining a fluid expansion chamber. A piston is positioned within the fluid expansion chamber. A thermally expanding fluid is positioned within the fluid expansion chamber. An end ring coupled to the piston slides along the mandrel in response to a sliding of the piston. A packer having a first end and a second end, the first end adapted to slide along the mandrel in response to a sliding of the end ring, and the second end fixedly coupled to the mandrel, so that a sliding of the first end of the packer toward the second end causes the packer element to decrease in length and increase in radius. 1. A temperature compensated element comprising:a mandrel, the mandrel being generally tubular and having a central axis and an exterior cylindrical surface;a housing coupled to the mandrel, the housing defining a fluid expansion chamber between an inner wall of the housing and the exterior cylindrical surface of the mandrel;a piston positioned about the mandrel, the piston having a piston head positioned within the fluid expansion chamber and adapted to slide along the mandrel, the piston head forming a seal against the housing and the mandrel to enclose the fluid expansion chamber;a thermally expanding fluid positioned within the fluid expansion chamber;an end ring positioned about the mandrel, the end ring coupled to the piston, the end ring adapted to slide along the mandrel in response to a sliding of the piston; anda packer including a packer element coupled to the exterior cylindrical surface of the mandrel, the packer having a first end and a second end, the first end adapted to slide along the mandrel in response to a sliding of the end ring, and the second end fixedly coupled to the mandrel, so that a sliding of the first end of the packer toward the second end causes the packer element to decrease in length and increase in radius.2. The temperature compensated element of ...

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Номер записи: 90
22-01-2015 дата публикации

GROOVED SWELLABLE PACKER

Номер: US20150021044A1
Автор: DAVIS Tim, FRISBY Ray, GREENAN Iain M., Kutac Andrew
Принадлежит:

A swellable packer which includes a generally tubular mandrel having a central axis and an exterior cylindrical surface. The swellable packer further includes a swellable elastomeric body fixed to the exterior cylindrical surface of the mandrel, wherein the swellable elastomeric body includes a plurality of grooves and wherein the generally tubular elastomeric sleeve has a circumference and a thickness. 1. A swellable packer comprising:a generally tubular mandrel having a central axis and an exterior cylindrical surface; anda swellable elastomeric body coupled to the exterior cylindrical surface of the mandrel, the swellable elastomeric body comprising a plurality of grooves, the swellable elastomeric body having a circumference and a thickness.2. The swellable packer of claim 1 , wherein the grooves are arranged longitudinally along the swellable elastomeric body and parallel to the central axis.3. The swellable packer of claim 1 , wherein the grooves are arranged in a helical pattern about the swellable elastomeric body.4. The swellable packer of claim 1 , wherein the grooves are arranged circumferentially about the swellable elastomeric body.5. The swellable packer of claim 4 , wherein the distance between each groove of the plurality of grooves is between 0.5 and 4 inches.6. The swellable packer of claim 4 , wherein the distance between adjacent grooves in a first location along the swellable elastomeric body is different from the distance between adjacent grooves in a second location along the swellable elastomeric body.7. The swellable packer of claim 1 , wherein the width of each groove of the plurality of grooves is between 0.05 inches and 1 inch.8. The swellable packer of claim 1 , wherein the depth of each groove of the plurality of grooves is between 1% and 50% of the thickness of the swellable elastomeric body.9. The swellable packer of claim 1 , wherein the swellable elastomeric body is formed by wrapped layers.10. The swellable packer of claim 1 , ...

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Номер записи: 91
22-01-2015 дата публикации

Polycrystalline diamond materials having improved abrasion resistance, thermal stability and impact resistance

Номер: US20150021101A1
Автор: Anthony Griffo, Madapusi K. Keshavan, Michael Janssen, Youhe Zhang, Yuelin Shen
Принадлежит: Smith International Inc

PCD materials comprise a diamond body having bonded diamond crystals and interstitial regions disposed among the crystals. The diamond body is formed from diamond grains and a catalyst material at high pressure/high temperature conditions. The diamond grains have an average particle size of about 0.03 mm or greater. At least a portion of the diamond body has a high diamond volume content of greater than about 93 percent by volume. The entire diamond body can comprise high volume content diamond or a region of the diamond body can comprise the high volume content diamond. The diamond body includes a working surface, a first region substantially free of the catalyst material, and a second region that includes the catalyst material. At least a portion of the first region extends from the working surface to depth of from about 0.01 to about 0.1 mm.

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Номер записи: 92
16-01-2020 дата публикации

QUANTIFYING CONTAMINATION OF DOWNHOLE SAMPLES

Номер: US20200018739A1
Автор: Alipour Kallehbasti Mehdi, Jones Christopher Michael, KHAN Waqar Ahmad
Принадлежит:

Systems, devices, and techniques for determining downhole fluid contamination are disclosed. In one or more embodiments, phase-related properties are measured for a reservoir fluid having a determined composition. An equation-of-state (EOS) is tuned based, at least in part, on the measured phase-related properties and the tuned EOS is applied to estimate fluid property values for a reference fluid over specified ranges of at least two thermodynamic properties. Contaminant reference data are generated that correlate the estimated fluid property values for the reference fluid with respective contaminant levels. Within a wellbore, a fluid sample is analyzed to determining a fluid property values. A contaminant level is identified that corresponds within the contaminant reference data to the determined fluid property value of the fluid sample. 1. A method for determining downhole fluid contamination , said method comprising:measuring phase-related properties for a reservoir fluid having a determined composition;tuning an equation-of-state (EOS) based, at least in part, on the phase-related properties;applying the tuned EOS to estimate fluid property values for a reference fluid over specified ranges of at least two thermodynamic properties;generating contaminant reference data that correlate the estimated fluid property values for the reference fluid with respective contaminant levels; collecting a fluid sample; and', 'determining a fluid property value for the fluid sample; and, 'within a wellbore,'}identifying a contaminant level that corresponds within the contaminant reference data to the determined fluid property value of the fluid sample.2. The method of claim 1 , wherein the reference fluid comprises the reservoir fluid having a specified contaminant level claim 1 , said method further comprising:applying the tuned EOS to estimate fluid property values for the reservoir fluid over the specified ranges of at least two thermodynamic properties; and in response to ...

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Номер записи: 93
28-01-2016 дата публикации

PREVENTING FLUID LOSS

Номер: US20160024863A1
Автор: BADRI MOHAMMED, Taherian Reza
Принадлежит:

Sealing particles are used to stop or reduce undesired fluid loss. The sealing particles may be swellable or have effective cross-sectional areas greater than five square millimeters or are both swellable and have effective cross-sectional areas greater than five square millimeters. The sealing particles are disposed in one or more locations in which there is undesired fluid flow and, once lodged therein, stop or at least reduce the undesired fluid loss. A tubular having a bypass flow path may be used to deploy the sealing particles. The bypass flow path may use a biased or unbiased sleeve that is selectably movable to expose or block exit ports in the tubular. A retrievable sealing disk may be deployed to move the sleeve. The sealing particles may be made of a bi-stable material with extenders and may be actuated using swellable material. The sealing particles may extend in multiple dimensions. 1. A method , comprising:providing sealing particles that are swellable or have effective cross-sectional areas greater than five square millimeters or are both swellable and have effective cross-sectional areas greater than five square millimeters;disposing the sealing particles in one or more locations in which there is undesired fluid loss; andstopping or reducing the undesired fluid loss using the sealing particles.2. The method of claim 1 , further comprising:providing a bypass flow path for the sealing particles;providing an actuator to open and/or close the bypass flow path; andselectably opening or closing the bypass flow path using the actuator.3. The method of claim 2 , wherein the actuator comprises a weight or a motor.4. The method of claim 2 , wherein selectably opening or closing the bypass flow path using the actuator comprises rotating or translating a sleeve.5. The method of claim 4 , further comprising biasing the sleeve.6. The method of claim 1 , wherein the disposing the sealing particles comprises pumping the sealing particles.7. The method of claim 6 , ...

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Номер записи: 94
28-01-2016 дата публикации

CONDITIONING FERROUS ALLOYS INTO CRACKING SUSCEPTIBLE AND FRAGMENTABLE ELEMENTS FOR USE IN A WELL

Номер: US20160024864A1
Автор: Marya Manuel, Werner Andrew T.
Принадлежит:

A technique includes providing a tool to be deployed in a well to perform a downhole function. The downhole function requires a minimum structural integrity for an element of the tool. The technique includes forming at least part of the element from a ferrous alloy and charging the alloy with hydrogen cause the element to be more prone to cracking than before the hydrogen charging. 1. A method usable with a well , comprising:providing a template to define an etching pattern;establishing contact between the template and a downhole element; andcausing the template to be cathodic and the downhole element to be anodic to etch the downhole element according to the pattern to predispose the downhole element to fracturing.2. The method of claim 1 , wherein the act of causing maintains a structural integrity of the downhole element above a minimum structural integrity required by a downhole function performed by the downhole element.3. The method of claim 1 , wherein the act of causing comprising connecting a power source to the template and the downhole element to produce an active galvanic corrosion cell.4. The method of claim 1 , wherein the act of providing the template comprises:providing the template containing at least one selected from the following: stainless steel, nickel alloy, zinc alloy, copper alloy.5. A method usable with a well claim 1 , comprising:providing a downhole element having a first material; andproviding a second material on the downhole element, such that the first and second materials form active galvanic cells from debris of the downhole element in the well.6. The method of claim 5 , further comprising:forming a coating of the second material on the downhole element.7. The method of claim 5 , further comprising:forming the second material into a template; andusing the template to etch a fracture pattern on the downhole element.8. The method of claim 5 , wherein the act of using the template to etch comprises etching a hydrogen charge material of ...

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Номер записи: 95
28-01-2016 дата публикации

DUAL BARRIER PERFORATING SYSTEM

Номер: US20160024874A1
Автор: Arabie Blake Lyndon, Johnson Michael Richard
Принадлежит:

A system and method for use in used in oil and gas wellbores is provided. More specifically, the disclosure relates to barriers or seals used in downhole operations involving activities such as perforating operations and well abandonment operations. The system and method relate to sealing a borehole such as when a well is being abandoned at the end of its productive life. The embodiments are particularly applicable to boreholes containing casing with an inner wall and an outer wall wherein an annulus is formed between the outer wall of the casing and the borehole wall. 1. A process for sealing a borehole having a borehole wall , said borehole containing a casing with an inner wall and an outer wall wherein an annulus is formed between said outer wall and said borehole wall , the process comprising:a. introducing into said casing a first assembly at a first setting depth, said first assembly having a perforating gun and configured to allow fluid flow through said first assembly only in a direction towards said perforating gun;b. moving said first assembly from an unset position to a set position in which it engages said inner wall of said casing;c. introducing into said casing a second assembly at a second setting depth;d. moving said second assembly from an unset position to a set position in which said second assembly engages said inner wall of said casing;e. applying fluid pressure through said first and second assemblies to said perforating gun so as to initiate said perforating gun to produce perforations in said casing;f. introducing a sealing fluid through said first and second assemblies into said annulus such that a portion of said sealing fluid remains in said first and second assemblies;g. preventing fluid flow through said second assembly; andh. thereafter, introducing additional sealing fluid above said second assembly.2. The process of wherein said first assembly is a first packer assembly comprising:a first mandrel defining a first central flow passage ...

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Номер записи: 96
28-01-2016 дата публикации

Downhole bypass tool

Номер: US20160024885A1
Автор: Andy Ferguson, Roger Schultz
Принадлежит: Thru Tubing Solutions Inc

The present disclosure is directed to a downhole bypass tool that includes an inlet for receiving fluid into a housing of the bypass tool. The bypass tool also includes a flow directing apparatus disposed in the housing for directing fluid to flow into an operational flow path of a vibratory tool. The vibratory tool is at least partially disposed within the hosing of the bypass tool. The flow directing apparatus operates selectively bypass the operational flow path of the vibratory tool such that the fluid bypasses the operational flow path of the vibratory tool and flows out of an outlet of the bypass tool.

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Номер записи: 97
28-01-2016 дата публикации

PRESSURE-OPERATED DIMPLE LOCKOUT TOOL

Номер: US20160024886A1
Автор: Williamson Jimmie Robert
Принадлежит: Halliburton Energy Services, Inc.

The disclosure describes a lockout tool including a cam housing configured to fit within a flow tube of a safety valve that is coupled to production tubing and has a longitudinal up-down axis. The lockout tool further includes a piston disposed within the cam housing and configured to move within the cam housing parallel to the longitudinal up-down axis and form a plurality of dimples in the flow tube upon provision within the production tubing of a pressurized fluid. 1. A method of locking open a safety valve , comprising:forming simultaneously a plurality of dimples in a flow tube of a safety valve using a lockout tool having a cam housing and a piston disposed within the cam housing, the lockout tool being configured to move relative to the cam housing parallel to a longitudinal up-down axis of the safety valve upon provision of a pressurized fluid within production tubing that is coupled to the safety valve.2. The method of claim 1 , wherein at least two of the plurality of dimples are formed at a separation angle about the longitudinal up-down axis of the safety valve of at least 90 degrees.3. The method of claim 2 , wherein two of the plurality of dimples are formed at a separation angle of approximately 180 degrees with respect to each other.4. The method of claim 1 , wherein at least two of the plurality of dimples are formed generally on a common plane perpendicular to the longitudinal up-down axis of the safety valve.5. The method of claim 1 , wherein:the piston comprises a piston body configured to move along the longitudinal up-down axis of the safety valve and a plurality of dimpling cams that each comprise a high point;each dimpling cam being rotatably coupled to the piston body such that the respective high point protrudes through the cam housing during a portion of rotation of the dimpling cam with respect to the piston body; andeach dimpling cam being further configured to synchronously rotate as the piston body moves within the outer shell so that ...

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Номер записи: 98
28-01-2016 дата публикации

ABANDONMENT AND CONTAINMENT SYSTEM FOR GAS WELLS

Номер: US20160024896A1
Автор: Arabie Blake, Johnson Michael
Принадлежит:

The invention presents a method for plugging and abandoning spent wells. An expandable liner hanger having sealing elements positioned thereon, is run-in and expanded, creating at least one seal against fluid migration. A redundant seal is created using a swellable annular sealing device, such as a swell packer. The swell packer and liner hanger are run-in and expanded. A bottom valve is closed and the expansion and running tools released from the liner hanger. After pulling out of the running tool, the wellbore is cemented creating an effective plug. 1. A method for plugging and abandoning a subterranean wellbore having a casing positioned therein , the method comprising the steps of:running a tool string into the wellbore, the tool string having a swellable annular sealing device, and an expandable liner hanger with at least one annular sealing element mounted thereon;radially expanding the swellable annular sealing device;creating a fluid-tight annular seal between the swellable annular sealing device and the casing;radially expanding the expandable liner hanger and contacting the casing with the at least one annular sealing element; andcreating a fluid-tight annular seal between the expandable liner hanger and the casing, wherein the step of radially expanding the swellable annular sealing device further comprises the step of exposing a swellable material positioned on the device to an actuating fluid, an actuating chemical, or to heat.27-. (canceled)8. The method of claim 1 , further comprising the step of flowing an actuating fluid downhole.9. The method of claim 8 , further comprising the step of flowing the actuating fluid through the tool string claim 8 , through a valve attached to the tool string claim 8 , and through valve ports into a wellbore annulus defined between the swellable annular sealing device and the casing.10. The method of claim 9 , wherein the step of running the tool string into the wellbore further comprises the step of running a valve ...

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Номер записи: 99
26-01-2017 дата публикации

DOWNHOLE TOOL FOR REMOVING A CASING PORTION

Номер: US20170022773A1
Автор: "ORourke Timothy M.", Park Jonathan
Принадлежит:

A packoff device is disclosed for sealing an annulus within a wellbore, and for bypassing the sealed annulus. The packoff device may include a mandrel having a bore formed axially therethrough and first and second ports extending radially from the bore. A sealing element that extends radially-outwardly from the mandrel may be positioned axially between the first and second ports, and may create a seal within an annulus between the mandrel and a casing, to isolate a portion of the annulus above the sealing element from a portion below the sealing element. A sleeve within the bore may, with the mandrel, form a channel providing fluid communication between the first and second ports. The sleeve may be movable between open and closed states. The first and second ports may be unobstructed by the sleeve in the open state, one or more may be obstructed in the closed state. 1. A packoff device , comprising:a mandrel having an axial bore and one or more ports extending radially from the axial bore to an exterior surface of the mandrel;a sealing element extending radially-outward from the mandrel; and a first configuration in which flow from an annulus around the mandrel and below the sealing element is permitted to flow axially upwardly through the sealing element into an annulus around the mandrel and above the sealing element; and', 'a second configuration in which flow from the annulus around the mandrel and below the sealing element is blocked from flowing axially upwardly through the sealing element and into the annulus around the mandrel and above the sealing element., 'a sleeve configured to selectively move relative to the mandrel to open and close the one or more ports, the sleeve being movable between at least2. The packoff device of claim 1 , the packoff device comprising one or more swab cups having downward facing lips.3. The packoff device of claim 1 , the sealing element having a fixed outer diameter.4. The packoff device of claim 1 , the sleeve being ...

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Номер записи: 100