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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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Поддерживает ввод нескольких поисковых фраз (по одной на строку). При поиске обеспечивает поддержку морфологии русского и английского языка
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Применить Всего найдено 1595. Отображено 114.
11-10-2016 дата публикации

Expandable tubing run through production tubing and into open hole

Номер: US0009464511B2
Автор: Michael Fripp, John Gano, Peter Besselink, Wilfried Van Moorleghem, FRIPP MICHAEL, GANO JOHN, BESSELINK PETER, VAN MOORLEGHEM WILFRIED, Fripp Michael, Gano John, Besselink Peter, Van Moorleghem Wilfried
Принадлежит: Halliburton Energy Services, Inc., HALLIBURTON ENERGY SERVICES INC

A downhole completion assembly for sealing and supporting an open hole section of a wellbore includes a sealing structure movable between contracted and expanded configurations, a truss structure also movable between contracted and expanded configurations, wherein, when in their respective contracted configurations, the sealing and truss structures are each able to axially traverse production tubing extended within a wellbore, a conveyance device operably coupled to the sealing and truss structures and configured to transport the sealing and truss structures in their respective contracted configurations through the production tubing and to an open hole section of the wellbore, and a deployment device operably connected to the sealing and truss structures and configured to radially expand the sealing and truss structures from their respective contracted configurations to their respective expanded configurations.

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Номер записи: 1
22-09-2016 дата публикации

FLOW DISTRIBUTION ASSEMBLIES FOR DISTRIBUTING FLUID FLOW THROUGH SCREENS

Номер: US20160273320A1
Автор: Stephen Michael Greci, Jean-Marc Lopez, Michael Fripp, John Charles Gano, GRECI STEPHEN MICHAEL, LOPEZ JEAN-MARC, FRIPP MICHAEL, GANO JOHN CHARLES, Greci Stephen Michael, Lopez Jean-Marc, Fripp Michael, Gano John Charles
Принадлежит: Halliburton Energy Services, Inc.

Embodiments herein include an assembly comprising a base pipe having at least one flow port defined therein; a well screen arranged about the base pipe and in fluid communication with the at least one flow port, the well screen having an end disposed at or near the at least one flow port; a shroud arranged about the end of the well screen and extending axially along a length of the well screen; and an annular gap defined between the well screen and the shroud and configured to receive a flow of a fluid, wherein the shroud increases a flow resistance of the fluid by channeling the fluid across the annular gap to distribute a flow energy of the fluid over the length of the well screen.

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Номер записи: 2
01-05-2013 дата публикации

Variable flow restrictor for use in a subterranean well

Номер: CN103080467A
Автор: Holderman Luke W., Dykstra Jason D., Fripp Michael
Принадлежит:

A variable flow resistance system for use in a subterranean well can include a flow chamber through which a fluid composition flows, the chamber having at least one inlet, an outlet, and at least one structure spirally oriented relative to the outlet, whereby the structure induces spiral flow of the fluid composition about the outlet. Another variable flow resistance system for use in a subterranean well can include a flow chamber including an outlet, at least one structure which induces spiral flow of a fluid composition about the outlet, and at least one other structure which impedes a change in direction of flow of the fluid composition radially toward the outlet.

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Номер записи: 3
23-05-2017 дата публикации

Thermal component temperature management system and method

Номер: US0009657551B2
Автор: Joe Marzouk, Michael Fripp, Adan Hernandez Herrera, MARZOUK JOE, FRIPP MICHAEL, HERRERA ADAN HERNANDEZ, Marzouk Joe, Fripp Michael, Herrera Adan Hernandez
Принадлежит: HALLIBURTON ENERGY SERVICES, INC., HALLIBURTON ENERGY SERVICES INC, Halliburton Energy Services, Inc.

A downhole tool includes a temperature sensitive component. The temperature of the temperature sensitive component is at least partially controlled by a temperature management system thermally coupled to the temperature sensitive component. The temperature management system may include a cold plate thermally coupled to the temperature sensitive component, a hot plate thermally coupled to the cold plate, and a thermo-electrical converter system thermally coupled to the hot plate and to the body of the downhole tool, wherein the thermo-electrical converter system comprises two membrane electrode assemblies.

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Номер записи: 4
22-06-2017 дата публикации

DISSOLVABLE PERFORATING DEVICE

Номер: US20170175500A1
Автор: Richard Ellis Robey, Christopher Hoelscher, Michael Fripp, ROBEY RICHARD ELLIS, HOELSCHER CHRISTOPHER, FRIPP MICHAEL, Robey Richard Ellis, Hoelscher Christopher, Fripp Michael
Принадлежит: Halliburton Energy Services, Inc.

In accordance with embodiments of the present disclosure, a perforating system for perforating a subterranean formation includes a carrier gun body having a cylindrical sleeve. The perforating system also includes a charge holder disposed in the cylindrical sleeve and a plurality of charges disposed on the charge holder. The charge holder is dissolvable in at least one wellbore fluid delivered through the carrier gun body after detonation of the charges. The charges may also be dissolvable during or after detonation. In some embodiments, the carrier gun body is dissolvable wellbore fluid delivered through the carrier gun body. By including dissolvable parts, the disclosed perforating gun yields relatively lower amounts of debris in the wellbore after detonation. In addition, the dissolving portions of the perforating gun allow the remaining portions of the gun to be used to perform wellbore operations downhole without pulling the perforating gun.

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Номер записи: 5
11-04-2017 дата публикации

Thermal component temperature management system and method

Номер: US0009617827B2
Автор: Joe Marzouk, Michael Fripp, Adan Hernandez Herrera, MARZOUK JOE, FRIPP MICHAEL, HERRERA ADAN HERNANDEZ, Marzouk Joe, Fripp Michael, Herrera Adan Hernandez
Принадлежит: HALLIBURTON ENERGY SERVICES, INC., HALLIBURTON ENERGY SERVICES INC, Halliburton Energy Services, Inc.

A downhole tool includes a temperature sensitive component. The temperature of the temperature sensitive component is at least partially controlled by a temperature management system thermally coupled to the temperature sensitive component. A metal hydride may be selectively thermally coupled to a cold plate that is thermally coupled to the temperature sensitive component.

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Номер записи: 6
01-09-2016 дата публикации

WELLBORE SYSTEMS WITH ADJUSTABLE FLOW CONTROL AND METHODS FOR USE THEREOF

Номер: US20160251936A1
Автор: Michael Fripp, John Gano, Scott Cunningham, Stephen Michael Greci, FRIPP MICHAEL, GANO JOHN, CUNNINGHAM SCOTT, GRECI STEPHEN MICHAEL, Fripp Michael, Gano John, Cunningham Scott, Greci Stephen Michael
Принадлежит: Halliburton Energy Services, Inc.

It is sometimes desirable to differentially regulate fluid flow in a subterranean formation using autonomous inflow control devices (AICDs), but they are not readily configurable in the field at present. Wellbore systems providing adjustable flow control may comprise: a wellbore pipe having a flow control assembly fixedly coupled thereto, the wellbore pipe having an interior space, an outer surface, and one or more AICDs establishing a fluid connection between the interior space and the outer surface of the wellbore pipe, and the flow control assembly comprising one or more flow chambers defined on the outer surface about the one or more AICDs, one or more inlets being fluidly connected to the one or more flow chambers; wherein the one or more inlets are configured to accept a plug for occluding fluid flow therethrough, so as to limit access of a fluid to an entry location of the AICDs.

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Номер записи: 7
11-05-2017 дата публикации

METHOD AND APPARATUS FOR MAGNETIC PULSE SIGNATURE ACTUATION

Номер: US20170130558A1
Автор: Zachary W. Walton, Michael Fripp, WALTON ZACHARY W, FRIPP MICHAEL, Walton Zachary W., Fripp Michael
Принадлежит:

A wellbore servicing tool comprising a housing comprising one or more ports and generally defining a flow passage, an actuator disposed within the housing, a magnetic signature system (MSS) comprising a magnetic sensor in signal communication with an electronic circuit disposed within the housing and coupled to the actuator, and a sleeve slidably positioned within the housing and transitional from a first position to a second position, wherein, the sleeve is allowed to transition from the first position to the second position upon actuation of the actuator, and wherein the actuator is actuated upon recognition of a predetermined quantity of predetermined magnetic pulse signatures via the MSS.

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Номер записи: 8
11-04-2017 дата публикации

Thermal component temperature management system and method

Номер: US0009617828B2
Автор: Joe Marzouk, Michael Fripp, Adan Hernandez Herrera, MARZOUK JOE, FRIPP MICHAEL, HERRERA ADAN HERNANDEZ, Marzouk Joe, Fripp Michael, Herrera Adan Hernandez
Принадлежит: Halliburton Energy Services, Inc., HALLIBURTON ENERGY SERVICES INC

A downhole tool includes a temperature sensitive component. The temperature of the temperature sensitive component is at least partially controlled by a temperature management system thermally coupled to the temperature sensitive component. The temperature management system may include a cooling mixture chamber thermally coupled to the temperature sensitive component, wherein first and second components of a cooling mixture cause an endothermic reaction when mixed together within the cooling mixture chamber.

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Номер записи: 9
14-11-2017 дата публикации

Tubing pressure operated downhole fluid flow control system

Номер: US0009816352B2
Автор: Brad R. Pickle, Michael Fripp, PICKLE BRAD R, FRIPP MICHAEL, Pickle Brad R., Fripp Michael
Принадлежит: HALLIBURTON ENERGY SERVICES, INC, HALLIBURTON ENERGY SERVICES INC, Halliburton Energy Services, Inc.

A downhole flow control system utilizes a tubing pressure operated valve to selectively open and close fluid flow across the system. The tubing pressure operated valve includes a piston responsive to tubing pressure, and a valve element responsive to piston movement. The valve element can be moved rotationally, longitudinally, or both, in response to the piston movement. The valve is movable between a closed and at least one open position. The piston and valve elements can be releasably attachable, such as by a one-way ratchet. The valve element can be a rotating valve operable by a J-slot mechanism to rotate to multiple positions in response to movement of the piston element.

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Номер записи: 10
08-08-2017 дата публикации

Wellbore systems with adjustable flow control and methods for use thereof

Номер: US0009725984B2
Автор: Michael Fripp, John Gano, Scott Cunningham, Stephen Michael Greci, FRIPP MICHAEL, GANO JOHN, CUNNINGHAM SCOTT, GRECI STEPHEN MICHAEL, Fripp Michael, Gano John, Cunningham Scott, Greci Stephen Michael
Принадлежит: Halliburton Energy Services, Inc., HALLIBURTON ENERGY SERVICES INC

It is sometimes desirable to differentially regulate fluid flow in a subterranean formation using autonomous inflow control devices (AICDs), but they are not readily configurable in the field at present. Wellbore systems providing adjustable flow control may comprise: a wellbore pipe having a flow control assembly fixedly coupled thereto, the wellbore pipe having an interior space, an outer surface, and one or more AICDs establishing a fluid connection between the interior space and the outer surface of the wellbore pipe, and the flow control assembly comprising one or more flow chambers defined on the outer surface about the one or more AICDs, one or more inlets being fluidly connected to the one or more flow chambers; wherein the one or more inlets are configured to accept a plug for occluding fluid flow therethrough, so as to limit access of a fluid to an entry location of the AICDs.

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Номер записи: 11
07-03-2017 дата публикации

Systems and methods for surface detection of wellbore projectiles

Номер: US0009587484B2
Автор: Zachary W. Walton, Michael Fripp, WALTON ZACHARY W, FRIPP MICHAEL, Walton Zachary W., Fripp Michael
Принадлежит: Halliburton Energy Services, Inc., HALLIBURTON ENERGY SERVICES INC

Disclosed are systems and methods for positively identifying wellbore projectiles introduced downhole. One well system includes at least one wellbore projectile configured to be introduced into a flow path associated with a work string arranged within a wellbore and extending from a wellhead installation, at least one optical computing device in optical communication with the flow path and having at least one integrated computational element configured to detect a characteristic of the at least one wellbore projectile and generate a resulting output signal indicative of the characteristic of the at least one wellbore projectile, and a computational system configured to receive the resulting output signal and associate the resulting output signal with a size or configuration of the at least one wellbore projectile.

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Номер записи: 12
02-03-2017 дата публикации

Composite Cables

Номер: US20170058098A1
Автор: Sean Gregory Thomas, Michael Fripp, THOMAS SEAN GREGORY, FRIPP MICHAEL, Thomas Sean Gregory, Fripp Michael
Принадлежит: Halliburton Energy Services, Inc.

Disclosed are composite cables suitable for use in conjunction with wellbore tools. One cable may include a polymer composite that includes dopants dispersed in a polymer matrix and continuous fibers extending along an axial length of the cable through the polymer matrix, wherein the cable is characterized by at least one of the following: (1) at least a portion of the cable having a density greater than about 2 g/cm3, wherein at least some of the dopants have a density of about 6 g/cm3 or greater, (2) at least a portion of the cable having a density less than about 2 g/cm3, wherein at least some of the dopants have a density of about 0.9 g/cm3 or less, (3) at least some of the dopants are ferromagnetic, or (4) at least some of the dopants are hydrogen getters.

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Номер записи: 13
07-03-2017 дата публикации

Method and apparatus for magnetic pulse signature actuation

Номер: US0009587486B2
Автор: Zachary W. Walton, Michael Fripp, WALTON ZACHARY W, FRIPP MICHAEL, Walton Zachary W., Fripp Michael
Принадлежит: Halliburton Energy Services, Inc., HALLIBURTON ENERGY SERVICES INC

A wellbore servicing tool comprising a housing comprising one or more ports and generally defining a flow passage, an actuator disposed within the housing, a magnetic signature system (MSS) comprising a magnetic sensor in signal communication with an electronic circuit disposed within the housing and coupled to the actuator, and a sleeve slidably positioned within the housing and transitional from a first position to a second position, wherein, the sleeve is allowed to transition from the first position to the second position upon actuation of the actuator, and wherein the actuator is actuated upon recognition of a predetermined quantity of predetermined magnetic pulse signatures via the MSS.

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Номер записи: 14
26-01-2012 дата публикации

MAXIMIZING HYDROCARBON PRODUCTION WHILE CONTROLLING PHASE BEHAVIOR OR PRECIPITATION OF RESERVOIR IMPAIRING LIQUIDS OR SOLIDS

Номер: US20120018167A1
Автор: Davis Eric, FRIPP Michael L., Jones Christopher M., JR. John L., Konopczynski Michael R., LEBLANC Michel J., Maida, Pelletier Michael T., Samson Etienne M.
Принадлежит: Halliburton Energy Services, Inc.

A method of flowing fluid from a formation, the method comprising: sensing presence of a reservoir impairing substance in the fluid flowed from the formation; and automatically controlling operation of at least one flow control device in response to the sensing of the presence of the substance. A well system, comprising: at least one sensor which senses whether a reservoir impairing substance is present; and at least one flow control device which regulates flow of a fluid from a formation in response to indications provided by the sensor. 1. A method of flowing fluid from a formation , the method comprising:sensing presence of a reservoir impairing substance in the fluid flowed from the formation; andautomatically controlling operation of at least one flow control device in response to the sensing of the presence of the substance.2. The method of claim 1 , wherein the fluid comprises a hydrocarbon gas.3. The method of claim 1 , wherein multiple flow control devices regulate flow of the fluid from multiple respective zones of the formation claim 1 , and wherein each of the flow control devices is independently operable in response to the sensing of the presence of the substance.4. The method of claim 3 , wherein the sensing of the presence of the substance is performed by multiple sensors claim 3 , and wherein each of the multiple flow control devices is operable in response to the sensing of the presence of the substance by a corresponding one of the sensors.5. The method of claim 1 , wherein the sensing of the presence of the substance is performed by at least one sensor which detects formation of at least one of mist claim 1 , fog and dew in the fluid.6. The method of claim 1 , wherein the sensing of the presence of the substance is performed by at least one sensor which detects an increase in density of the fluid.7. The method of claim 1 , wherein a first densitometer is positioned upstream of a flow restriction claim 1 , and a second densitometer is positioned ...

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Номер записи: 15
02-02-2012 дата публикации

Well screens constructed utilizing pre-formed annular elements

Номер: US20120024520A1
Автор: Donald G. Kyle, Floyd R. Simonds, Jason Dykstra, Jean-Marc Lopez, Michael L. Fripp, Syed Hamid
Принадлежит: Halliburton Energy Services Inc

Construction of well screens utilizing pre-formed annular-shaped elements. A well screen includes a filter layer configured to filter fluid flowing through the well screen and a drainage layer which radially supports the filter layer, the drainage layer including multiple individual annular-shaped elements. Another well screen includes a drainage layer configured to support the filter layer, with the drainage layer including at least one cavity molded therein. Another well screen includes a base pipe and a layer made up of multiple individual annular-shaped elements stacked coaxially on the base pipe. A cavity is formed in at least one of the elements.

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Номер записи: 16
01-03-2012 дата публикации

Thermal Component Temperature Management System and Method

Номер: US20120048531A1
Автор: Fripp Michael, Herrera Adan Hernandez, Marzouk Joe
Принадлежит: Halliburton Energy Services, Inc.

A downhole tool includes a thermally sensitive component. The temperature of the thermally sensitive component is at least partially controlled by a temperature management system thermally coupled to the thermally sensitive component. 1. A downhole tool , comprising:a body;a temperature sensitive component housed within the body;a cold plate thermally coupled to the temperature sensitive component; anda metal hydride selectively thermally coupled to the cold plate and thermally coupled to a body of the downhole tool.2. The downhole tool of claim 1 , wherein the metal hydride is formed as a powder and disposed within a metal hydride container containing hydrogen.3. The downhole tool of claim 2 , wherein the metal hydride container is not thermally coupled to the cold plate when thermally coupled to the body of the downhole tool.4. The downhole tool of claim 3 , further comprising a eutectic material disposed within the metal hydride container.5. The downhole tool of claim 3 , further comprising a piston to move the metal hydride container relative to the cold plate.6. The downhole tool of claim 5 , further comprising a spring biasing the metal hydride container towards the cold plate.7. The downhole tool of claim 1 , wherein the metal hydride is disposed within a sealed container.8. The downhole tool of claim 7 , wherein the metal hydride is selectively thermocoupled to the cold plate by a circulation system comprising a conduit claim 7 , a working fluid claim 7 , and a pump.9. The downhole tool of claim 8 , wherein the circulation system further comprises at least two valves claim 8 , and wherein closing the valves and deactivating the pump thermally decouples the metal hydride from the cold plate.10. The downhole tool of claim 9 , wherein the sealed container comprises a piston disposed therein claim 9 , and wherein actuation of the piston varies the pressure on the metal hydride.11. The downhole tool of claim 10 , wherein the piston increases pressure on the metal ...

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Номер записи: 17
10-05-2012 дата публикации

VARIABLE FLOW RESISTANCE SYSTEM WITH CIRCULATION INDUCING STRUCTURE THEREIN TO VARIABLY RESIST FLOW IN A SUBTERRANEAN WELL

Номер: US20120111577A1
Автор: DYKSTRA Jason D., FRIPP Michael L.
Принадлежит: Halliburton Energy Services, Inc.

A flow control device can include a surface that defines a chamber and includes a side perimeter and opposing end surfaces, a greatest distance between the opposing end surfaces being smaller than a largest dimension of the opposing end surfaces, a first port through one of the end surfaces, and a second port through the surface and apart from the first port, the side perimeter surface being operable to direct flow from the second port to rotate about the first port. Another device can include a cylindroidal chamber for receiving flow through an inlet and directing the flow to an outlet, a greatest axial dimension of the cylindroidal chamber being smaller than a greatest diametric dimension of the cylindroidal chamber, the cylindroidal chamber promoting rotation of the flow based on a characteristic of the inflow through the inlet. The device can have a flow path structure in the cylindroidal chamber. 1. A flow control device for installation in a subterranean wellbore , the flow control device comprising:an interior surface that defines an interior chamber, the interior surface includes a side perimeter surface and opposing end surfaces, a greatest distance between the opposing end surfaces is smaller than a largest dimension of the opposing end surfaces;a first port through one of the end surfaces;a second port through the interior surface and apart from the first port, the side perimeter surface operable to direct flow from the second port to rotate about the first port; anda flow path structure in the interior chamber.2. The flow control device of claim 1 , wherein the flow path structure is operable to direct the flow from the second port to rotate about the first port.3. The flow control device of claim 2 , wherein the flow path structure is operable to allow the flow from the second port to flow directly toward the first port.4. The flow control device of claim 1 , wherein the first port comprises an outlet from the interior chamber and the second port ...

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Номер записи: 18
07-06-2012 дата публикации

DEVICE FOR DIRECTING THE FLOW OF A FLUID USING A PRESSURE SWITCH

Номер: US20120138304A1
Автор: DYKSTRA Jason D., FRIPP Michael L.
Принадлежит: Halliburton Energy Services, Inc.

A device for directing the flow of a fluid comprises: a pressure pocket; a first fluid passageway; a pressure source; and a pressure switch, wherein the first fluid passageway operationally connects at least the pressure pocket and the pressure source, and wherein the pressure switch is positioned adjacent to the pressure source. According to an embodiment, depending on at least one of the properties of the fluid, the fluid that flows into the pressure pocket changes. In one embodiment, the change is the fluid increasingly flows into the pressure pocket. In another embodiment, the change is the fluid decreasingly flows into the pressure pocket. According to another embodiment, a flow rate regulator comprises: the device for directing the flow of a fluid; a second fluid passageway; a third fluid passageway; and a fourth fluid passageway. 1. A device for directing the flow of a fluid comprises:a pressure pocket;a first fluid passageway;a pressure source; anda pressure switch,wherein the first fluid passageway operationally connects at least the pressure pocket and the pressure source, andwherein the pressure switch is positioned adjacent to the pressure source.2. The device according to claim 1 , wherein depending on at least one of the properties of the fluid claim 1 , the fluid that flows into the pressure pocket changes.3. The device according to claim 2 , further comprising a second fluid passageway and wherein the at least one of the properties of the fluid are selected from the group consisting of the flow rate of the fluid in the second fluid passageway claim 2 , the viscosity of the fluid claim 2 , and the density of the fluid.4. The device according to claim 3 , further comprising a third fluid passageway claim 3 , a fourth fluid passageway claim 3 , and a branching point claim 3 , wherein the second fluid passageway branches into the third fluid passageway and the fourth fluid passageway at the branching point.5. The device according to claim 4 , wherein the ...

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Номер записи: 19
14-06-2012 дата публикации

SYSTEMS AND METHODS FOR WELL MONITORING

Номер: US20120146805A1
Автор: Fripp Michael Linley, JR. James Dan, Scott Bruce Edward, VICK
Принадлежит: Halliburton Energy Services, Inc.

Devices capable of being disposed in a wellbore for outputting acoustical signals for monitoring downhole parameters are described. Receiving devices positioned remote from the devices and can receive the acoustical signals and determine the downhole parameters. The devices can output acoustical signals in response to fluid flow or otherwise. 1. A system for use with a bore in a subterranean formation , the system comprising:a device capable of being disposed in the bore and of responding to fluid flow by providing an acoustical signal representing a downhole parameter,wherein the device is capable of outputting the acoustical signal to a medium for receipt by a receiving device, the receiving device being positioned remote from the device.2. The system of claim 1 , wherein at least one property of the acoustical signal is representative of the downhole parameter claim 1 , the at least one property comprises at least one of:a tone;a beat;signal noise;a frequency change; oran amplitude change.3. The system of claim 1 , wherein the acoustical signal comprises at least one property representing the downhole parameter claim 1 , the at least one property comprising a presence of an amplitude signal.4. The system of claim 1 , wherein the device comprises a bell having a clapper capable of cooperating with at least one of a plate or a tubing string in response to fluid flow to provide the acoustical signal representing the downhole parameter.5. The system of claim 1 , wherein the device comprises a whistle capable of providing the acoustical signal representing the downhole parameter in response to fluid flow.6. The system of claim 5 , wherein the whistle comprises at least one of:a Helmholtz resonator;a vortex shedding device;a downhole siren; ora slide device.7. The system of claim 1 , wherein the device comprises:a first device capable of outputting a first acoustical signal at a first frequency; anda second device capable of outputting a second acoustical signal at a ...

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Номер записи: 20
21-06-2012 дата публикации

EXIT ASSEMBLY WITH A FLUID DIRECTOR FOR INDUCING AND IMPEDING ROTATIONAL FLOW OF A FLUID

Номер: US20120152527A1
Автор: DYKSTRA Jason D., FRIPP Michael L.
Принадлежит: Halliburton Energy Services, Inc.

According to an embodiment, an exit assembly comprises: a first fluid inlet; a first fluid outlet; and at least one fluid director, wherein the fluid enters the exit assembly in one direction, in another direction, or combinations thereof, and wherein the at least one fluid director induces flow of the fluid rotationally about the assembly when the fluid enters in the one direction and impedes flow of the fluid rotationally about the assembly when the fluid enters in the another direction. In another embodiment, the exit assembly includes two or more fluid inlets. According to another embodiment, a flow rate restrictor comprises: a fluid switch; and the exit assembly. According to another embodiment, the flow rate restrictor is for use in a subterranean formation. 1. An exit assembly comprising:a first fluid inlet;a first fluid outlet; andat least one fluid director,wherein the fluid enters the exit assembly in one direction, in another direction, or combinations thereof, andwherein the at least one fluid director induces flow of the fluid rotationally about the assembly when the fluid enters in the one direction and impedes flow of the fluid rotationally about the assembly when the fluid enters in the another direction.2. The assembly according to claim 1 , wherein the fluid has a vector component that enters the assembly tangentially relative to a radius of the first fluid outlet.3. The assembly according to claim 1 , wherein the size and shape of the fluid director is selected such that the fluid director induces flow of a fluid rotationally about the assembly when the fluid enters in the one direction and impedes flow of the fluid rotationally about the assembly when the fluid enters in the another direction.4. The assembly according to claim 1 , wherein the fluid director includes at least three boundaries.5. The assembly according to claim 4 , wherein at least one of the boundaries induces flow of a fluid rotationally about the assembly.6. The assembly ...

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Номер записи: 21
12-07-2012 дата публикации

System and method for completion optimization

Номер: US20120179428A1
Автор: Jason D. Dykstra, Kenneth L. Schwendemann, Michael L. Fripp, Orlando Dejesus, Syed Hamid, Tommy F. Grigsby
Принадлежит: Halliburton Energy Services Inc

A system for completing a wellbore ( 38 ) having multiple zones. The system includes a completion ( 42 ) having a plurality of landing points defined therein positioned within the wellbore ( 38 ). A service tool is axially movable within the completion ( 42 ). The service tool is coupled to a pipe string ( 36 ) extending from the surface and selectively supported by a movable block ( 30 ) above the surface. A subsurface model is defined in a computer operably associated with the wellbore ( 38 ). The model is operable to predict the position of the service tool relative to the landing points of the completion ( 42 ) based upon a dynamic lumped mass model of the service tool and a dynamic lumped capacitance thermal model of the wellbore environment.

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Номер записи: 22
23-08-2012 дата публикации

Method and apparatus for autonomous downhole fluid selection with pathway dependent resistance system

Номер: US20120211243A1
Автор: Jason D. Dykstra, John C. Gano, Luke Holderman, Michael Linley Fripp, Orlando Dejesus
Принадлежит: Halliburton Energy Services Inc

Apparatus and methods for controlling the flow of fluid, such as formation fluid, through an oilfield tubular positioned in a wellbore extending through a subterranean formation. Fluid flow is autonomously controlled in response to change in a fluid flow characteristic, such as density or viscosity. In one embodiment, a fluid diverter is movable between an open and closed position in response to fluid density change and operable to restrict fluid flow through a valve assembly inlet. The diverter can be pivotable, rotatable or otherwise movable in response to the fluid density change. In one embodiment, the diverter is operable to control a fluid flow ratio through two valve inlets. The fluid flow ratio is used to operate a valve member to restrict fluid flow through the valve.

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Номер записи: 23
27-09-2012 дата публикации

WELL TOOLS INCORPORATING VALVES OPERABLE BY LOW ELECTRICAL POWER INPUT

Номер: US20120241143A1
Автор: Fink Kevin D., FRIPP Michael L., Kalman Mark D., Perkins Donald, Williamson Jimmie R., Wright Adam D.
Принадлежит: Halliburton Energy Services, Inc.

Well tools including valves operable by low electrical input. One well tool includes a valve which controls fluid communication between pressure regions in a well, the valve including a rotatable member which is biased to rotate, and a brake or clutch which prevents rotation of the member. Another valve includes a barrier which separates reactants, with the valve being operable in response to the barrier being opened and the reactants thereby reacting with each other. Yet another valve includes a barrier which separates the pressure regions, and a control circuit which heats the barrier to a weakened state. Another valve includes a member displaceable between open and closed positions, a restraining device which resists displacement of the member, and a control device which degrades or deactivates the restraining device and thereby permits the member to displace between its open and closed positions, in response to receipt of a predetermined signal. 18-. (canceled)9. A well tool , comprising:a valve which controls fluid communication between pressure regions in a well, the valve including a barrier which separates reactants, and the valve being operable in response to the barrier being opened and the reactants thereby reacting with each other.10. The well tool of claim 9 , wherein the valve further includes a plug isolating the pressure regions from each other claim 9 , and wherein at least a portion of the plug is dissolvable by a product of the reactants.11. The well tool of claim 9 , wherein the valve further includes a plug isolating the pressure regions from each other claim 9 , and wherein a product of the reactants is corrosive to at least a portion of the plug.12. The well tool of claim 9 , wherein an exothermic reaction is produced when the reactants react with each other claim 9 , and wherein at least a portion of the plug is weakened claim 9 , melted or disintegrated by the exothermic reaction.13. The well tool of claim 9 , wherein pressure is produced ...

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Номер записи: 24
11-10-2012 дата публикации

METHOD AND APPARATUS FOR CONTROLLING FLUID FLOW IN AN AUTONOMOUS VALVE USING A STICKY SWITCH

Номер: US20120255740A1
Автор: DYKSTRA Jason D., FRIPP Michael L.
Принадлежит: Halliburton Energy Services, Inc.

Apparatus and methods are described for autonomously controlling fluid flow in a tubular in a wellbore. A fluid is flowed through an inlet passageway into a biasing mechanism. A fluid flow distribution is established across the biasing mechanism. The fluid flow distribution is altered in response to a change in the fluid characteristic over time. In response, fluid flow through a downstream sticky switch assembly is altered, thereby altering fluid flow patterns in a downstream vortex assembly. The method “selects” based on a fluid characteristic, such as viscosity, density, velocity, flow rate, etc. The biasing mechanism can take various forms such as a widening passageway, contour elements along the biasing mechanism, or a curved section of the biasing mechanism passageway. The biasing mechanism can include hollows formed in the passageway wall, obstructions extending from the passageway wall, fluid diodes, Tesla fluid diodes, a chicane, or abrupt changes in passageway cross-section. 1. A method for controlling flow of fluid in a wellbore extending through a subterranean formation , the fluid having a characteristic which changes over time , the fluid flowing through an inlet passageway , a flow biasing mechanism , and a variable flow resistance assembly , the method comprising the following steps:flowing fluid through the inlet passageway;establishing a first fluid flow distribution across an outlet of the flow biasing mechanism; thenaltering the first fluid flow distribution to a second flow distribution across the outlet of the flow biasing mechanism in response to a change in the fluid characteristic; andchanging the fluid flow resistance of the variable flow resistance assembly in response to the altering of the distribution of flow from the outlet of the flow biasing mechanism.2. A method as in claim 1 , further comprising the step of flowing the fluid to the surface or into the formation.3. A method as in claim 1 , further comprising the steps of ...

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Номер записи: 25
08-11-2012 дата публикации

DEVICE FOR DIRECTING THE FLOW OF A FLUID USING A CENTRIFUGAL SWITCH

Номер: US20120279593A1
Автор: DYKSTRA Jason D., FRIPP Michael L.
Принадлежит: Halliburton Energy Services, Inc.

According to an embodiment, a device for directing the flow of a fluid comprises: a fluid chamber; a first outlet; a second outlet; a first outlet fluid passageway, wherein the first outlet fluid passageway is operatively connected to the first outlet; and a second outlet fluid passageway, wherein the second outlet fluid passageway is operatively connected to the second outlet; wherein the fluid rotationally flows about the inside of the chamber, and wherein the fluid flowing through the first outlet fluid passageway conjoins with the fluid flowing through the second outlet fluid passageway at a point downstream of the first and second outlet. According to another embodiment, a device for directing the flow of a fluid comprises: a sensor; a first outlet connected to the sensor; a second outlet connected to the sensor; a first outlet fluid passageway; and a second outlet fluid passageway; wherein as the total number of phases of the fluid increases, the sensor directs at least a first phase of the fluid into the first outlet fluid passageway and directs at least a second phase of the fluid into the second outlet fluid passageway, and wherein the fluid flowing through the first outlet fluid passageway conjoins with the fluid flowing through the second outlet fluid passageway at a point downstream of the first and second outlet. 1. A device for directing the flow of a fluid comprises:a fluid chamber;a first outlet;a second outlet;a first outlet fluid passageway, wherein the first outlet fluid passageway is operatively connected to the first outlet; anda second outlet fluid passageway, wherein the second outlet fluid passageway is operatively connected to the second outlet;wherein the fluid rotationally flows about the inside of the chamber, andwherein the fluid flowing through the first outlet fluid passageway conjoins with the fluid flowing through the second outlet fluid passageway at a point downstream of the first and second outlet.2. The device according to claim ...

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Номер записи: 26
20-12-2012 дата публикации

Managing Treatment of Subterranean Zones

Номер: US20120318526A1
Автор: DYKSTRA Jason D., Fripp Michael Linley
Принадлежит: Halliburton Energy Services, Inc.

A downhole heated fluid generation system includes: a compressor-valve assembly having a compressor and a valve, the assembly operable to compress and regulate a fluid used in generating a heated treatment fluid; a combustor fluidly coupled to the compressor-valve assembly, the combustor operable to provide the heated treatment fluid into a wellbore; and a controller communicably coupled to the compressor-valve assembly, the controller operable to: determine an input indicative of a desired position of the valve; determine a value indicative of an actual position of the valve; determine a desired operating condition of the compressor based, at least in part, on the input indicative of the desired position of the valve and the value indicative of an actual position of the valve; and adjust an operating parameter of the compressor based on the desired operating pressure to compress a fluid flowing through the compressor and the valve. 1. A method for controlling a compressor-valve assembly in a downhole heated fluid generation system , comprising:determining an input indicative of a desired position of a valve in the compressor-valve assembly;determining a value indicative of an actual position of the valve;determining a desired operating condition of a compressor in the compressor-valve assembly based, at least in part, on the input indicative of the desired position of the valve and the value indicative of an actual position of the valve; andadjusting an operating parameter of the compressor based on the desired operating condition to compress a fluid flowing through the compressor and the valve of the compressor-valve assembly.2. The method of claim 1 , further comprising:scaling the value indicative of the actual position of the valve through a filter; anddetermining a difference between the input indicative of the desired position of the valve and the scaled value indicative of the actual position of the valve.3. The method of claim 2 , wherein the filter ...

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Номер записи: 27
20-12-2012 дата публикации

Managing Treatment of Subterranean Zones

Номер: US20120323378A1
Автор: DYKSTRA Jason D., Fripp Michael Linley
Принадлежит: Halliburton Energy Services, Inc.

A downhole heated fluid generation system includes: a plurality of subsystems, including an air subsystem having an air compressor or an air flow control valve, a fuel subsystem having a fuel compressor or a fuel flow control valve, a treatment fluid subsystem having a fluid pump; a combustor coupled to at least one of the plurality of subsystems to provide a heated fluid into at least one of a wellbore or a subterranean zone; and a controller operable to: receiving an input indicative of a desired flow rate of the heated fluid; receiving an input indicative of a desired quality of the heated fluid; determining a virtual flow rate of the heated fluid based, at least in part, on the input indicative of the desired flow rate; and controlling the plurality of subsystems with the virtual flow rate of the heated fluid. 1. A method for controlling a downhole heated fluid generation system , comprising:receiving an input indicative of a desired flow rate of a heated fluid, the heated fluid generated by the downhole heated fluid generation system to inject into at least one of a wellbore or a subterranean zone;receiving an input indicative of a desired quality of the heated fluid;determining a virtual flow rate of the heated fluid based, at least in part, on the input indicative of the desired flow rate; andcontrolling a plurality of subsystems of the downhole heated fluid generation system with the virtual flow rate of the heated fluid.2. The method of claim 1 , wherein determining a virtual flow rate of the heated fluid based claim 1 , at least in part claim 1 , on the input indicative of the desired flow rate comprises determining the virtual flow rate of the heated fluid independent of the input indicative of the desired quality of the heated fluid.3. The method of claim 1 , wherein controlling a plurality of subsystems of the downhole heated fluid generation system with the virtual flow rate of the heated fluid comprises:determining an expected airflow rate through an ...

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Номер записи: 28
03-01-2013 дата публикации

WELL TOOL ACTUATOR AND ISOLATION VALVE FOR USE IN DRILLING OPERATIONS

Номер: US20130000922A1
Автор: FRIPP Michael L., Skinner Neal G.
Принадлежит: Halliburton Energy Services, Inc.

A well tool actuator can include a series of chambers which, when opened in succession, cause the well tool to be alternately actuated. A method of operating a well tool actuator can include manipulating an object in a wellbore; 1. A well tool actuator , comprising:a series of chambers which, when opened in succession, cause the well tool to be alternately actuated.2. The well tool actuator of claim 1 , further comprising a control valve which alternately exposes a piston to well pressure and isolates the piston from well pressure in response to the chambers being opened in succession.3. The well tool actuator of claim 2 , wherein the control valve comprises a sleeve which displaces incrementally in response to the chambers being opened in succession.4. The well tool actuator of claim 1 , further comprising a sensor.5. The well tool actuator of claim 4 , wherein the chambers are opened in succession in response to detection of predetermined acoustic signals by the sensor.6. The well tool actuator of claim 4 , wherein the chambers are opened in succession in response to detection of drill string movement by the sensor.7. The well tool actuator of claim 4 , wherein the sensor comprises an acoustic sensor.89-. (canceled)10. A method of operating a well tool actuator claim 4 , the method comprising:manipulating an object in a wellbore, wherein the manipulating comprises rotating the object;a sensor of the actuator detecting the object manipulation; andthe actuator actuating in response to the sensor detecting the object manipulation.11. A method of operating a well tool actuator claim 4 , the method comprising:manipulating an object in a wellbore;a sensor of the actuator detecting the object manipulation; andthe actuator actuating in response to the sensor detecting the object manipulation, wherein a series of chambers of the actuator are opened in succession in response to the sensor detecting respective predetermined patterns of the object manipulation.12. The method ...

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Номер записи: 29
17-01-2013 дата публикации

Estimating a Wellbore Parameter

Номер: US20130014940A1
Автор: DYKSTRA Jason D., Fripp Michael Linley
Принадлежит: Halliburton Energy Services, Inc.

A system for estimating a wellbore parameter includes a first component located at or near a terranean surface; a second component at least partially disposed within a wellbore at or near a subterranean zone, the second component associated with a sensor; and a controller communicably coupled to the first and second components operable to: adjust a characteristic of an input fluid to the wellbore through a range of input values; receive, from the sensor, a plurality of output values of the input fluid that vary in response to the input values, the output values representative of a downhole condition; and estimate a wellbore parameter distinct from the downhole condition based on the measured output values.

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Номер записи: 30
17-01-2013 дата публикации

Remotely Activated Downhole Apparatus and Methods

Номер: US20130014941A1
Автор: Acosta Frank, Budler Nicholas, Covington Ricky Layne, Fripp Michael, Helms Lonnie, Key John, Longbottom James R., Tips Timothy Rather
Принадлежит:

An apparatus includes an impervious body, a sealing element; an energy source, and a trigger. The impervious body is configured to prevent passage of fluid therethrough. The sealing element is disposed about the impervious body. The energy source is operationally connected to the sealing element. The trigger is configured to transfer energy from the energy source to the sealing element. The trigger is activated, at least in part, by receiving a signal from a pump tool passing through an interior of the impervious body. 1. An apparatus comprising:an impervious body configured to prevent passage of fluid therethrough;a sealing element disposed about the impervious body;an energy source operationally connected to the sealing element; anda trigger configured to transfer energy from the energy source to the sealing element;wherein the trigger is activated, at least in part, by receiving a signal from a pump tool passing through an interior of the impervious body.2. The apparatus of claim 1 , wherein the signal from the pump tool comprises a modification or transmission of a magnetic signal.3. The apparatus of claim 1 , wherein the signal from the pump tool comprises a modification of a magnetic signal caused by the pump tool moving a shifting sleeve disposed within the interior of the impervious body.4. The apparatus of claim 1 , wherein the pump tool comprises a plug claim 1 , wiper claim 1 , dart claim 1 , or ball.5. The apparatus of claim 1 , wherein the pump tool comprises a section of magnetic fluid.6. An apparatus comprising:an impervious body configured to prevent passage of fluid therethrough;a sealing element disposed about the impervious body;a hydraulic fluid reservoir operationally connected to the sealing element;a compartment hydraulically connected to the hydraulic fluid reservoir;a port coupled with a shifting sleeve providing selective hydraulic communication between the hydraulic fluid reservoir and the compartment; anda trigger configured to receive a ...

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Номер записи: 31
17-01-2013 дата публикации

METHODS OF LIMITING OR REDUCING THE AMOUNT OF OIL IN A SEA USING A FLUID DIRECTOR

Номер: US20130014955A1
Автор: DYKSTRA Jason D., FRIPP Michael L.
Принадлежит: Halliburton Energy Services, Inc.

According to an embodiment, a method of limiting the amount of oil in a sea comprises: positioning a device for directing the flow of a fluid adjacent to a wellhead, wherein the device comprises: a first fluid passageway; a second fluid passageway; a third fluid passageway, wherein the first fluid passageway is operatively connected to the second and third fluid passageways; and a fluid director, wherein the fluid director is operatively connected to the first, second, and third fluid passageways, and wherein depending on at least one of the properties of a fluid, the fluid director directs the fluid to increasingly flow into the second or third fluid passageways. This embodiment is useful in limiting the amount of oil when a blowout has occurred. According to another embodiment, a method of reducing the amount of oil in a sea comprises: inserting at least one component of the device for directing the flow of a fluid into a portion of a sea, wherein the portion of the sea comprises the oil, and wherein depending on at least one of the properties of a fluid, the fluid director directs the fluid to increasingly flow into the second or third fluid passageways. This embodiment is useful for reducing the amount of oil in a sea when an oil slick has occurred. 1. A method of limiting the amount of oil in a sea comprising: a first fluid passageway;', 'a second fluid passageway;', 'a third fluid passageway, wherein the first fluid passageway is operatively connected to the second and third fluid passageways; and', wherein the fluid director is operatively connected to the first, second, and third fluid passageways, and', 'wherein depending on at least one of the properties of a fluid, the fluid director directs the fluid to increasingly flow into the second or third fluid passageways., 'a fluid director,'}], 'positioning a device for directing the flow of a fluid adjacent to a wellhead, wherein the device comprises2. The method according to claim 1 , wherein the first fluid ...

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Номер записи: 32
17-01-2013 дата публикации

Remotely Activated Downhole Apparatus and Methods

Номер: US20130014959A1
Автор: Acosta Frank, Budler Nicholas, Covington Ricky Layne, Fripp Michael, Helms Lonnie, Key John, Longbottom James R., Tips Timothy Rather
Принадлежит:

An apparatus includes an impervious body, a sealing element, an energy source, and a trigger. The impervious body is configured to prevent passage of fluid therethrough. The sealing element is disposed about the impervious body. The energy source is operationally connected to the sealing element. The trigger is configured to transfer energy from the energy source to the sealing element. The trigger is activated, at least in part, by receiving a signal transmitted through the impervious body. 1. An apparatus comprising:an impervious body configured to prevent passage of fluid therethrough;a sealing element disposed about the impervious body;an energy source operationally connected to the sealing element; anda trigger configured to transfer energy from the energy source to the sealing element;wherein the trigger is activated, at least in part, by receiving a signal transmitted through the impervious body.2. An apparatus comprising:an impervious body configured to prevent passage of fluid therethrough;a sealing element disposed about the impervious body;a hydraulic fluid reservoir operationally connected to the sealing element;an electronics compartment hydraulically connected to the hydraulic fluid reservoir;a pressure barrier between the hydraulic fluid reservoir and the electronics compartment; anda trigger configured to receive a signal from within an interior of the impervious body and open the pressure barrier;wherein opening of the pressure barrier permits movement of hydraulic fluid out of the hydraulic fluid reservoir and into the electronics compartment, allowing the sealing element to set.3. The apparatus of claim 2 , comprising a hydrostatic piston forming at least one boundary of the hydraulic fluid reservoir and configured to move when the pressure barrier is opened in the presence of a predetermined hydrostatic pressure;wherein movement by the hydrostatic piston causes the sealing element to set.4. The apparatus of claim 2 , wherein the trigger is ...

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Номер записи: 33
24-01-2013 дата публикации

Three dimensional fluidic jet control

Номер: US20130020090A1
Автор: Jason D. Dykstra, Michael L. Fripp
Принадлежит: Halliburton Energy Services Inc

A method of controlling a fluid jet can include discharging fluid through an outlet of a jetting device, thereby causing the fluid jet to be flowed in multiple non-coplanar directions, and the fluid jet being directed in the non-coplanar directions by a fluidic circuit of the jetting device. A jetting device can include a body having at least one outlet, and a fluidic circuit which directs a fluid jet to flow from the outlet in multiple non-coplanar directions without rotation of the outlet. A method of drilling a wellbore can include flowing fluid through a fluidic switch of a jetting device, thereby causing a fluid jet to be discharged in multiple non-coplanar directions from the jetting device, and the fluid jet cutting into an earth formation.

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Номер записи: 34
28-02-2013 дата публикации

INJECTION OF FLUID INTO SELECTED ONES OF MULTIPLE ZONES WITH WELL TOOLS SELECTIVELY RESPONSIVE TO MAGNETIC PATTERNS

Номер: US20130048290A1
Автор: Fripp Michael Linley, FRISBIE Eric Russell, Howell Matthew Todd, Kyle Donald, TIPS Timothy
Принадлежит: Halliburton Energy Services, Inc.

A method of actuating a well tool can include displacing a magnetic device pattern in the well, thereby transmitting a corresponding magnetic signal to the well tool, and the well tool actuating in response to detection of the magnetic signal. A method of injecting fluid into selected ones of multiple zones penetrated by a wellbore can include displacing at least one magnetic device into at least one valve in the wellbore, the valve actuating in response to the displacing step, and injecting the fluid through the valve and into at least one of the zones associated with the valve. An injection valve for use in a subterranean well can include a sensor which detects a magnetic field, and an actuator which opens the injection valve in response to detection of at least one predetermined magnetic signal by the sensor. 1. A method of actuating at least one well tool in a well , the method comprising:producing a first magnetic device pattern in the well, thereby transmitting a corresponding first magnetic signal to the well tool; andthe well tool actuating in response to detection of the first magnetic signal.2. The method of claim 1 , wherein the first pattern comprises a predetermined number of the magnetic devices.3. The method of claim 1 , wherein the first pattern comprises a predetermined spacing in time of the magnetic devices.4. The method of claim 1 , wherein the first pattern comprises a predetermined spacing in time between predetermined numbers of the magnetic devices.5. The method of claim 1 , wherein the at least one well tool comprises multiple well tools claim 1 , and wherein a first set of the well tools actuates in response to detection of the first magnetic signal.6. The method of claim 5 , wherein a second set of the well tools actuates in response to detection of a second magnetic signal.7. The method of claim 6 , wherein the second magnetic signal corresponds to a second magnetic device pattern produced in the well.8. The method of claim 1 , wherein ...

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Номер записи: 35
28-02-2013 дата публикации

Downhole Fluid Flow Control System Having a Fluidic Module with a Bridge Network and Method for Use of Same

Номер: US20130048299A1
Автор: DYKSTRA Jason D., Fripp Michael Linley, Gano John Charles, Holderman Luke William
Принадлежит: Halliburton Energy Services, Inc.

A downhole fluid flow control system includes a fluidic module () having a main fluid pathway (), a valve () and a bridge network. The valve () has a first position wherein fluid flow through the main fluid pathway () is allowed and a second position wherein fluid flow through the main fluid pathway () is restricted. The bridge network has first and second branch fluid pathways () each having a common fluid inlet () and a common fluid outlet () with the main fluid pathway () and each including two fluid flow resistors () with a pressure output terminal () positioned therebetween. In operation, the pressure difference between the pressure output terminals () of the first and second branch fluid pathways () shifts the valve () between the first and second positions. 1. A downhole fluid flow control system comprising:a fluidic module having a bridge network with first and second branch fluid pathways each including at least one fluid flow resistor and a pressure output terminal;wherein a pressure difference between the pressure output terminals of the first and second branch fluid pathways is operable to control fluid flow through the fluidic module.2. The flow control system as recited in wherein the first and second branch fluid pathways each include at least two fluid flow resistors.3. The flow control system as recited in wherein the pressure output terminal of each branch fluid pathway is positioned between the two fluid flow resistors.4. The flow control system as recited in wherein the two fluid flow resistors of each branch fluid pathway have different responses to fluid viscosity.5. The flow control system as recited in wherein the two fluid flow resistors of each branch fluid pathway have different responses to fluid density.6. The flow control system as recited in wherein the first and second branch fluid pathways each have a common fluid inlet and a common fluid outlet with a main fluid pathway.7. The flow control system as recited in wherein a fluid ...

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Номер записи: 36
28-02-2013 дата публикации

Downhole Fluid Flow Control System and Method having Dynamic Response to Local Well Conditions

Номер: US20130048301A1
Автор: DYKSTRA Jason D., Fripp Michael Linley, Gano John Charles, Holderman Luke William
Принадлежит: Halliburton Energy Services, Inc.

A downhole fluid flow control system having dynamic response to local well conditions. The system includes a tubing string operably positionable in a wellbore. Annular barriers are positioned between the tubing string and the wellbore to isolate first and second zones. A fluid flow control device is positioned within each zone. A flow tube that is operably associated with the fluid flow control device of the first zone is operable to establish communication between the second zone and the fluid flow control device in the first zone such that a differential pressure between the first zone and the second zone is operable to actuate the fluid flow control device of the first zone from a first operating configuration to a second operating configuration. 1. A downhole fluid flow control method comprising:isolating first and second zones in a wellbore, each zone having a fluid flow control device positioned therein;establishing communication between the first zone and the fluid flow control device in the second zone;establishing communication between the second zone and the fluid flow control device in the first zone;flowing fluid through the fluid flow control device of the first zone;generating a differential pressure between the first zone and the second zone; andactuating the fluid flow control device of the second zone from a first operating configuration to a second operating configuration responsive to the differential pressure.2. The downhole fluid flow control method as recited in wherein isolating first and second zones in the wellbore further comprises installing annular barriers between a tubing string and the wellbore.3. The downhole fluid flow control method as recited in wherein establishing communication between the first zone and the fluid flow control device in the second zone further comprises extending a flow tube through at least one of the annular barriers.4. The downhole fluid flow control method as recited in wherein flowing fluid through the fluid ...

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Номер записи: 37
07-03-2013 дата публикации

Flow path control based on fluid characteristics to thereby variably resist flow in a subterranean well

Номер: US20130056217A1
Автор: Jason D. Dykstra, Michael L. Fripp, Syed Hamid
Принадлежит: Halliburton Energy Services Inc

A system for variably resisting flow of a fluid composition can include a flow passage and a set of one or more branch passages which intersect the flow passage, whereby a proportion of the composition diverted from the passage to the set of branch passages varies based on at least one of a) viscosity of the fluid composition, and b) velocity of the fluid composition in the flow passage. Another variable flow resistance system can include a flow path selection device that selects which of multiple flow paths a majority of fluid flows through from the device, based on a ratio of desired fluid to undesired fluid in the composition. Yet another variable flow resistance system can include a flow chamber, with a majority of the composition entering the chamber in a direction which changes based on a ratio of desired fluid to undesired fluid in the composition.

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Номер записи: 38
28-03-2013 дата публикации

METHOD AND APPARATUS FOR AUTONOMOUS DOWNHOLE FLUID SELECTION WITH PATHWAY DEPENDENT RESISTANCE SYSTEM

Номер: US20130075107A1
Автор: DeJesus Orlando, DYKSTRA Jason D., Fripp Michael Linley, GANO John C., Holderman Luke
Принадлежит: Halliburton Energy Services, Inc.

An apparatus is described for controlling flow of fluid in a subterranean formation based on a selected characteristic of fluid flow, such as viscosity, velocity or density, as that characteristic varies over time. A pathway-dependent resistance assembly, such as a vortex chamber having two inlets and an outlet, provides varying resistance to fluid flow based on the ratio of flow from the inlets, the direction of flow as directed by the inlets, and the characteristic of the fluid. The incoming flow ratio is preferably determined by flowing fluid through a plurality of passageways having differing flow rate responses to fluid having differing characteristics. Fluid of a selected characteristic will encounter lesser resistance to flow across the system, while fluid of an un-favored characteristic will encounter greater resistance to flow. Thus, flow of well fluids can be autonomously restricted as the fluid characteristics change over time. 1. A well device for installation in a wellbore in a subterranean zone , comprising:a fluid diode in fluid communication between an interior and an exterior of the well device.2. The well device of claim 1 , wherein the fluid diode is in fluid communication between the interior and the exterior to communicate production fluid from the exterior of the well device to the interior of the well device.3. The well device of claim 2 , wherein the well device comprises a section of a completion string.4. The well device of claim 1 , wherein the fluid diode is in fluid communication between the interior and the exterior to communicate injection fluid from the interior of the well device to the exterior of the well device.5. The well device of claim 4 , wherein the well device comprises a section of a working string.6. The well device of claim 1 , wherein the fluid diode comprises:an interior surface that defines an interior chamber, the interior surface includes a side perimeter surface and opposing end surfaces;a first port through one of ...

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Номер записи: 39
18-04-2013 дата публикации

METHOD AND APPARATUS FOR CONTROLLING FLUID FLOW USING MOVABLE FLOW DIVERTER ASSEMBLY

Номер: US20130092381A1
Автор: DeJesus Orlando, DYKSTRA Jason D., FRIPP Michael L.
Принадлежит: Halliburton Energy Services, Inc.

Apparatus and methods for controlling the flow of fluid, such as formation fluid, through an oilfield tubular positioned in a wellbore extending through a subterranean formation. Fluid flow is autonomously controlled in response to change in a fluid flow characteristic, such as density or viscosity. In one embodiment, a fluid diverter is movable between an open and closed position in response to fluid density change and operable to restrict fluid flow through a valve assembly inlet. The diverter can be pivotable, rotatable or otherwise movable in response to the fluid density change. In one embodiment, the diverter is operable to control a fluid flow ratio through two valve inlets. The fluid flow ratio is used to operate a valve member to restrict fluid flow through the valve. 1. A fluid flow control apparatus for use in an oilfield tubular positioned in a wellbore extending through a subterranean formation , the oilfield tubular for flowing fluid therethrough , the fluid having a density which changes over time , the apparatus comprising:a tool housing;a valve assembly positioned in the housing and having an inlet, an outlet, and a valve member, the valve member movable between a closed position wherein fluid flow through the valve assembly is restricted and an open position in which fluid flow through the valve assembly is relatively unrestricted;a movable fluid diverter positioned in the tool housing, the fluid diverter movable in response to change in the fluid density, the fluid diverter movable between a first position and a second position, the fluid diverter for changing the fluid flow pattern within the housing, and wherein the valve member moves between the closed and open positions in response to movement of the fluid diverter between the first and second positions and change in the fluid flow pattern through the housing.2. An apparatus as in wherein the fluid diverter is of a preselected density and is buoyant in a fluid of a preselected density.3. An ...

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Номер записи: 40
18-04-2013 дата публикации

Method and apparatus for controlling fluid flow using movable flow diverter assembly

Номер: US20130092382A1
Автор: Jason D. Dykstra, Michael L. Fripp, Orlando Dejesus
Принадлежит: Halliburton Energy Services Inc

Apparatus and methods for controlling the flow of fluid, such as formation fluid, through an oilfield tubular positioned in a wellbore extending through a subterranean formation. Fluid flow is autonomously controlled in response to change in a fluid flow characteristic, such as density or viscosity. In one embodiment, a fluid diverter is movable between an open and closed position in response to fluid density change and operable to restrict fluid flow through a valve assembly inlet. The diverter can be pivotable, rotatable or otherwise movable in response to the fluid density change. In one embodiment, the diverter is operable to control a fluid flow ratio through two valve inlets. The fluid flow ratio is used to operate a valve member to restrict fluid flow through the valve.

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Номер записи: 41
18-04-2013 дата публикации

METHOD AND APPARATUS FOR CONTROLLING FLUID FLOW USING MOVABLE FLOW DIVERTER ASSEMBLY

Номер: US20130092392A1
Автор: DeJesus Orlando, DYKSTRA Jason D., FRIPP Michael L.
Принадлежит: Halliburton Energy Services, Inc.

Apparatus and methods for controlling the flow of fluid, such as formation fluid, through an oilfield tubular positioned in a wellbore extending through a subterranean formation. Fluid flow is autonomously controlled in response to change in a fluid flow characteristic, such as density or viscosity. In one embodiment, a fluid diverter is movable between an open and closed position in response to fluid density change and operable to restrict fluid flow through a valve assembly inlet. The diverter can be pivotable, rotatable or otherwise movable in response to the fluid density change. In one embodiment, the diverter is operable to control a fluid flow ratio through two valve inlets. The fluid flow ratio is used to operate a valve member to restrict fluid flow through the valve. 1. A method of fluid flow control for use in an oilfield tubular positioned in a wellbore extending through a subterranean formation , the oilfield tubular for flowing fluid therethrough , the fluid having a characteristic which changes over time , the apparatus comprising:flowing fluid through a fluid ratio assembly positioned in a housing, the fluid ratio assembly having a first and second passageways through which fluid flows, the flow defining a flow ratio;flowing fluid through an outlet positioned in the housing;varying resistance to fluid flow through at least one of the first and second passageways, the resistance variation dependent on change in the fluid characteristic;changing the flow ratio defined by flow through the first and second passageways in response to varying the resistance through at least one of the first and second passageways;moving a valve element positioned in the housing in response to changing the flow ratio; andrestricting fluid flow through the outlet in response to moving the valve element.2. A method as in wherein the fluid characteristic is one of viscosity claim 1 , density claim 1 , or flow rate.3. A method as in wherein the valve element biased towards a ...

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Номер записи: 42
18-04-2013 дата публикации

METHOD AND APPARATUS FOR CONTROLLING FLUID FLOW USING MOVABLE FLOW DIVERTER ASSEMBLY

Номер: US20130092393A1
Автор: DeJesus Orlando, DYKSTRA Jason D., FRIPP Michael L.
Принадлежит: Halliburton Energy Services, Inc.

Apparatus and methods for controlling the flow of fluid, such as formation fluid, through an oilfield tubular positioned in a wellbore extending through a subterranean formation. Fluid flow is autonomously controlled in response to change in a fluid flow characteristic, such as density or viscosity. In one embodiment, a fluid diverter is movable between an open and closed position in response to fluid density change and operable to restrict fluid flow through a valve assembly inlet. The diverter can be pivotable, rotatable or otherwise movable in response to the fluid density change. In one embodiment, the diverter is operable to control a fluid flow ratio through two valve inlets. The fluid flow ratio is used to operate a valve member to restrict fluid flow through the valve. 1. A method of fluid flow control for use in an oilfield tubular positioned in a wellbore extending through a subterranean formation , the oilfield tubular for flowing fluid therethrough , the fluid having a characteristic which changes over time , the apparatus comprising:flowing fluid through a fluid ratio assembly positioned in a housing, the fluid ratio assembly having a first and second passageways through which fluid flows, the flow defining a flow ratio;flowing fluid through an outlet positioned in the housing;varying resistance to fluid flow through at least one of the first and second passageways, the resistance variation dependent on change in the fluid characteristic;changing the flow ratio defined by flow through the first and second passageways in response to varying the resistance through at least one of the first and second passageways;moving a valve element positioned in the housing in response to changing the flow ratio; andrestricting fluid flow through the outlet in response to moving the valve element.2. A method as in wherein the fluid characteristic is one of viscosity claim 1 , density claim 1 , or flow rate.3. A method as in wherein the valve element biased towards a ...

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Номер записи: 43
25-04-2013 дата публикации

VARYING PORE SIZE IN A WELL SCREEN

Номер: US20130098614A1
Автор: DAGENAIS Peter, FRIPP Michael L.
Принадлежит: Halliburton Energy Services, Inc.

A method can include applying a magnetic field to a well screen, thereby varying sizes of pores via which fluid flows through the well screen. A well screen can include a magnetic shape memory material having a dimension which changes in response to application of a magnetic field. Restriction to flow through the well screen can vary in response to the change in dimension of the magnetic shape memory material. 1. A method , comprising:applying a magnetic field to a well screen, thereby varying sizes of pores via which fluid flows through the well screen.2. The method of claim 1 , wherein the pores are formed in a magnetic shape memory material of the well screen.3. The method of claim 1 , wherein the magnetic field is applied to the well screen in a well.4. The method of claim 1 , wherein the magnetic field is applied to the well screen prior to installation of the well screen in a well.5. The method of claim 1 , wherein a substance is released from the pores in response to applying the magnetic field.6. The method of claim 5 , wherein the substance comprises a well treatment.7. The method of claim 5 , wherein the substance blocks flow through the pores prior to being released.8. The method of claim 5 , wherein the substance is released by being dissolved.9. The method of claim 5 , wherein the substance is released by being dispersed.10. The method of claim 1 , wherein applying the magnetic field to the well screen increases the sizes of the pores claim 1 , after the well screen is installed in a wellbore.11. The method of claim 1 , wherein applying the magnetic field to the well screen decreases the sizes of the pores claim 1 , after the well screen is installed in a wellbore.12. The method of claim 1 , wherein applying the magnetic field to the well screen comprises alternately increasing and decreasing the sizes of the pores.13. The method of claim 12 , wherein the fluid flows in one direction through the well screen when the sizes of the pores are increased ...

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Номер записи: 44
02-05-2013 дата публикации

CONSTRUCTION AND OPERATION OF AN OILFIELD MOLTEN SALT BATTERY

Номер: US20130106366A1
Автор: CAJA Josip, CAJA Mario, FRIPP Michael L., HAMID Syed
Принадлежит: Halliburton Energy Services, Inc.

Construction and operation of an oilfield molten salt battery. A battery includes an outer case, an elongated mandrel positioned within the outer case, and the mandrel being an electrical component of the battery. Another battery includes an electrical pickup, and a polymer insulator providing insulation between the outer case and the pickup. A method of charging a battery for use in a subterranean well includes the steps of: providing the battery including an electrolyte, and anode and cathode electrodes, the electrolyte being a molten salt comprising lithium salt, and at least one of the electrodes comprising lithium atoms; positioning the battery within a wellbore; and then charging the battery. Another method includes the steps of: heating the lithium ion molten salt battery; then charging the battery; and then positioning the battery within a wellbore. 110-. (canceled)11. A method of charging a battery for use in a subterranean well , the method comprising the steps of:providing the battery including an electrolyte, and anode and cathode electrodes, the electrolyte being a molten salt with a dissolved lithium salt, and at least one of the electrodes comprising lithium atoms;positioning the battery within a wellbore of the well; andthen charging the battery.12. The method of claim 11 , wherein the charging step further comprises controlling a voltage across the battery while the battery is being charged.13. The method of claim 11 , wherein the positioning step further comprises enclosing the battery within an outer housing claim 11 , and then exposing the outer housing to well fluids within the wellbore.14. The method of claim 11 , wherein the charging step further comprises at least one of: maintaining a constant current through the battery claim 11 , maintaining a constant voltage across the battery claim 11 , varying voltage across the battery claim 11 , varying current through the battery claim 11 , varying electrical energy applied to the battery in ...

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Номер записи: 45
09-05-2013 дата публикации

VARIABLE FLOW RESISTANCE FOR USE WITH A SUBTERRANEAN WELL

Номер: US20130112423A1
Автор: DYKSTRA Jason D., Felten Frederic, FRIPP Michael L., Zhao Liang
Принадлежит: Halliburton Energy Services, Inc.

A variable flow resistance system for use with a subterranean well can include a structure which displaces in response to a flow of a fluid composition, whereby a resistance to the flow of the fluid composition changes in response to a change in a ratio of desired to undesired fluid in the fluid composition. Another system can include a structure which rotates in response to flow of a fluid composition, and a fluid switch which deflects the fluid composition relative to at least two flow paths. A method of variably resisting flow in a subterranean well can include a structure displacing in response to a flow of a fluid composition, and a resistance to the flow of the fluid composition changing in response to a ratio of desired to undesired fluid in the fluid composition changing. Swellable materials and airfoils may be used in variable flow resistance systems. 17-. (canceled)8. A variable flow resistance system for use with a subterranean well , the system comprising:a fluid switch which directs a flow of a fluid composition to at least first and second flow paths; anda structure which displaces in response to the flow of the fluid composition, whereby a resistance to the flow of the fluid composition changes in response to a change in a ratio of desired to undesired fluid in the fluid composition, and wherein the structure pivots, and thereby varies the resistance to flow, in response to a change in a proportion of the fluid composition which flows through the first and second flow paths.9. A variable flow resistance system for use with a subterranean well , the system comprising:a fluid switch which directs a flow of a fluid composition to at least first and second flow paths; anda structure which displaces in response to the flow of the fluid composition, whereby a resistance to the flow of the fluid composition changes in response to a change in a ratio of desired to undesired fluid in the fluid composition, and wherein the structure rotates, and thereby varies ...

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Номер записи: 46
09-05-2013 дата публикации

FLUID DISCRIMINATION FOR USE WITH A SUBTERRANEAN WELL

Номер: US20130112424A1
Автор: DYKSTRA Jason D., FRIPP Michael L.
Принадлежит: Halliburton Energy Services, Inc.

A fluid discrimination system can include a fluid discriminator which selects through which of multiple outlet flow paths a fluid composition flows, the selection being based on a direction of flow of the fluid composition through the discriminator, and the direction being dependent on a fluid type in the fluid composition. Another fluid discriminator can include a structure which displaces in response to a fluid composition flow, whereby an outlet flow path of the fluid composition changes in response to a change in a ratio of fluids in the fluid composition. A method of discriminating between fluids can include providing a fluid discriminator which selects through which of multiple outlet flow paths a fluid composition flows in the well, the selection being based on a direction of flow of the fluid composition through the discriminator, and the direction being dependent on a ratio of the fluids in the fluid composition. 15-. (canceled)6. A fluid discrimination system for use with a subterranean well , the system comprising:a fluid discriminator which selects through which of multiple outlet flow paths a fluid composition flows, the selection being based on at least one direction of flow of the fluid composition through the fluid discriminator, and the direction being dependent on at least one fluid type in the fluid composition, wherein the at least one direction comprises first and second directions, wherein the fluid discriminator selects a first outlet flow path in response to flow of the fluid composition more in the first direction, wherein the fluid discriminator selects a second outlet flow path in response to flow of the fluid composition more in the second direction, and wherein the flow of the fluid composition in the first direction impinges on a structure, whereby the structure displaces and the first outlet flow path is selected.7. The system of claim 6 , wherein the flow of the fluid composition in the second direction impinges on the structure claim ...

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Номер записи: 47
09-05-2013 дата публикации

FLUID DISCRIMINATION FOR USE WITH A SUBTERRANEAN WELL

Номер: US20130112425A1
Автор: DYKSTRA Jason D., FRIPP Michael L.
Принадлежит: Halliburton Energy Services, Inc.

A fluid discrimination system can include a fluid discriminator which selects through which of multiple outlet flow paths a fluid composition flows, the selection being based on a direction of flow of the fluid composition through the discriminator, and the direction being dependent on a fluid type in the fluid composition. Another fluid discriminator can include a structure which displaces in response to a fluid composition flow, whereby an outlet flow path of the fluid composition changes in response to a change in a ratio of fluids in the fluid composition. A method of discriminating between fluids can include providing a fluid discriminator which selects through which of multiple outlet flow paths a fluid composition flows in the well, the selection being based on a direction of flow of the fluid composition through the discriminator, and the direction being dependent on a ratio of the fluids in the fluid composition. 1. A fluid discrimination system for use with a subterranean well , the system comprising:a fluid discriminator which selects through which of multiple outlet flow paths a fluid composition flows, the selection being based on at least one direction of flow of the fluid composition through the fluid discriminator, and the direction being dependent on at least one fluid type in the fluid composition.2. The system of claim 1 , wherein the fluid discriminator selects a first outlet flow path in response an increase in a ratio of desired to undesired fluid in the fluid composition claim 1 , and wherein the fluid discriminator selects a second outlet flow path in response to a decrease in the ratio of desired to undesired fluid.3. The system of claim 1 , wherein the fluid discriminator selects a first outlet flow path in response to the direction of flow being more radial claim 1 , and wherein the fluid discriminator selects a second outlet flow path in response to the direction of flow being more rotational.4. The system of claim 1 , wherein the at ...

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Номер записи: 48
16-05-2013 дата публикации

Downhole Cables for Well Operations

Номер: US20130122296A1
Автор: Clemens Jack G., Foster Jerry C., FRIPP Michael L., Miller Todd B., Mineo Richard, Rose Lawrence C.
Принадлежит: Halliburton Energy Services, Inc.

A slickline cable comprises an axially extending strength member having a first diameter proximate an upper end and at least one smaller second diameter distal from the upper end. A coating material is adhered to at least a portion of the length of the strength member to form a substantially uniform outer diameter along the slickline cable. A method for making a slickline comprises forming an axially extending strength member having a first diameter proximate an upper end and at least one smaller second diameter distal from the upper end. A coating material is adhered to at least a portion of the length of the strength member to form a substantially uniform outer diameter along the slickline cable. 1. A slickline cable comprising:an axially extending strength member having a first diameter proximate an upper end and at least one smaller second diameter distal from the upper end; anda coating material adhered to at least a portion of the length of the strength member to form a substantially uniform outer diameter along the slickline cable.2. The slickline cable of wherein the substantially uniform outer diameter of the slickline cable is chosen from the group consisting of: the first diameter; and a predetermined diameter larger than the first diameter.3. The slickline cable of wherein the coating comprises a thermoplastic material.4. The slickline cable of wherein the coating has a specific gravity less than a specific gravity of a fluid in a wellbore.5. The slickline cable of wherein the coating material swells when exposed to a slickline fluid.6. The slickline cable of wherein the coating comprises at least on of: a plurality of reinforcing fibers and a plurality of hollow glass beads.7. The slickline cable of wherein the strength member continuously tapers from the first diameter to the at least one second diameter.8. The slickline cable of wherein the at least one second diameter comprises a plurality of monotonically decreasing diameters from the upper end to a ...

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Номер записи: 49
06-06-2013 дата публикации

Bidirectional Downhole Fluid Flow Control System and Method

Номер: US20130140038A1
Автор: DeJesus Orlando, DYKSTRA Jason D., Fripp Michael Linley
Принадлежит: Halliburton Energy Services, Inc.

A bidirectional downhole fluid flow control system is operable to control the inflow of formation fluids and the outflow of injection fluids. The system includes at least one injection flow control component and at least one production flow control component in parallel with the at least one injection flow control component. The at least one injection flow control component and the at least one production flow control component each have direction dependent flow resistance, such that injection fluid flow experiences a greater flow resistance through the at least one production flow control component than through the at least one injection flow control component and such that production fluid flow experiences a greater flow resistance through the at least one injection flow control component than through the at least one production flow control component. 1. A bidirectional downhole fluid flow control system comprising:at least one injection flow control component having direction dependent flow resistance;a fluid selector valve in series with the at least one injection flow control component; andat least one production flow control component in parallel with the at least one injection flow control component and having direction dependent flow resistance,wherein, injection fluid flow experiences a greater flow resistance through the at least one production flow control component than through the at least one injection flow control component; andwherein, production fluid flow experiences a greater flow resistance through the at least one injection flow control component than through the at least one production flow control component.2. The flow control system as recited in wherein the at least one injection flow control component further comprises a fluidic diode providing greater resistance to flow in the production direction than in the injection direction.3. The flow control system as recited in wherein the at least one production flow control component further ...

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Номер записи: 50
20-06-2013 дата публикации

FLUID FLOW CONTROL

Номер: US20130153238A1
Автор: DYKSTRA Jason D., Fripp Michael Linley, Lopez Jean-Marc, Zhao Liang
Принадлежит: Halliburton Energy Services, Inc.

Fluid flow influencer devices capable of affecting fluid flow for fluid selection are described. Fluid flow influencer devices may affect fluid flowing into a turbulence, such as a vortex, having a structure that is usable to restrict fluid flow in a flow path of a chamber by different amounts based on at least one property of the fluid. The fluid flow control device may be in an autonomous fluid selector, such as a diverter, a vortex-causing device, or a whisker. Fluid properties based on which the flow influencer device can select fluid can include fluid density, fluid velocity, fluid viscosity, and Reynolds number of the fluid flow. 1. A flow control device configured for being disposed between a subterranean formation and a tubular in a wellbore , the flow control device comprising:a chamber having (i) an exit opening and (ii) a flow path; anda flow influencer device in the chamber, the flow influencer device being configured to affect fluid flowing into a turbulence having a structure that is based on at least one property of the fluid and the flow influencer device, wherein the chamber is configured for restricting fluid flow in the flow path by different amounts based on the structure of the turbulence.2. The flow control device of claim 1 , wherein the at least one property of the fluid comprises at least two of:Reynolds number of the fluid flow;fluid density;fluid velocity; orfluid viscosity.3. The flow control device of claim 1 , wherein the chamber comprises:an inlet at a first end of the chamber; anda second exit opening located between the exit opening and a second end of the chamber,wherein the flow influencer device is a diverter positioned between the inlet and the exit opening and configured to influence flow of fluid based on the at least one property (i) toward the exit opening and (ii) toward the second exit opening, by causing the fluid to flow into the turbulence that is a vortex and creating an area of low pressure between the diverter and the ...

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Номер записи: 51
27-06-2013 дата публикации

FLOW-AFFECTING DEVICE

Номер: US20130160990A1
Автор: DYKSTRA Jason D., Fripp Michael Linley
Принадлежит: Haliburton Energy Services, Inc.

Fluid flow influencer devices in chambers subsequent to vortex assemblies are described. A flow-affecting device can move from a first position to a second position based on a flow path of fluid flowing from the vortex assembly to the chamber. The flow path may depend on an amount of rotation of the fluid from the vortex assembly. The flow-affecting device in the first position can substantially allow fluid to flow through a chamber exit opening. The flow-affecting device in the second position can substantially restrict fluid from flowing through the chamber exit opening. 1. An assembly capable of being disposed in a wellbore , the assembly comprising:a chamber that is adapted to be positioned subsequent to an exit opening of a vortex assembly; anda flow-affecting device in the chamber, the flow-affecting device being adapted to move between a first position and a second position based on an amount of rotation of fluid entering the chamber from the vortex assembly.2. The assembly of claim 1 , wherein the chamber comprises a chamber exit opening claim 1 ,wherein the flow-affecting device in the first position is adapted to substantially allow fluid to exit through the chamber exit opening,wherein the flow-affecting device in the second position is adapted to substantially restrict fluid from exiting through the chamber exit opening.3. The assembly of claim 2 , wherein the flow-affecting device is adapted to be in the second position in response to the amount of rotation of fluid entering the chamber exceeding a first threshold amount of rotation claim 2 ,wherein the flow-affecting device is adapted to be in the first position in response to the amount of rotation of fluid entering the chamber being below a second threshold amount of rotation.4. The assembly of claim 2 , wherein the chamber comprises a second chamber opening claim 2 , wherein the flow-affecting device in the first position is adapted to substantially restrict fluid from exiting through the second ...

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Номер записи: 52
27-06-2013 дата публикации

Functionalized Surface for Flow Control Device

Номер: US20130161018A1
Автор: DYKSTRA Jason D., Fripp Michael Linley, Pelletier Michael T.
Принадлежит: Halliburton Energy Services, Inc.

Flow control devices can include functionalized surfaces on inner regions of walls. A functionalized surface can include a hydrophilic and/or a hydrophobic material that can affect fluid flowing in a flow path of a wall to facilitate fluid selection by the flow control device. Fluids may be switched in a flow control device using a functionalized surface even when a density and viscosity of different oil and water mixtures of the fluids are the same. 1. (canceled)2. The assembly of claim 10 , wherein the wall is adapted to be positioned antecedent in a flow path to a switching mechanism for a flow control device.3. The assembly of claim 2 , wherein at least one of the hydrophobic material or the hydrophilic material is adapted to increase surface roughness of part of the inner region of the wall based on at least one property of fluid flowing through the flow path.4. The assembly of claim 2 , wherein at least one of the hydrophobic material or the hydrophilic material is adapted to cause fluid flowing through the flow path to oscillate claim 2 , resulting in an increase differential pressure for the fluid during flow through the flow path to the switching mechanism.5. The assembly of claim 4 , wherein at least one of the hydrophobic material or the hydrophilic material is adapted to cause fluid flowing through the flow path to oscillate by changing a velocity profile of the fluid flowing through the flow path.6. The assembly of claim 2 , wherein the switching mechanism is adapted to be positioned between a vortex assembly and the first portion and the second portion of the inner region of the wall claim 2 , the switching mechanism comprising a plurality of passageways that provide separate flow paths to the vortex assembly.7. The assembly of claim 10 , wherein at least one of:first material on the first portion of the inner region of the wall is configured to change to the hydrophobic material in response to stimuli applied to the first material in the wellbore; ...

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Номер записи: 53
18-07-2013 дата публикации

Method and apparatus for autonomous downhole fluid selection with pathway dependent resistance system

Номер: US20130180727A1
Автор: Jason D. Dykstra, John C. Gano, Luke Holderman, Michael Linley Fripp, Orlando Dejesus
Принадлежит: Halliburton Energy Services Inc

Apparatus and methods for controlling the flow of fluid, such as formation fluid, through an oilfield tubular positioned in a wellbore extending through a subterranean formation. Fluid flow is autonomously controlled in response to change in a fluid flow characteristic, such as density or viscosity. In one embodiment, a fluid diverter is movable between an open and closed position in response to fluid density change and operable to restrict fluid flow through a valve assembly inlet. The diverter can be pivotable, rotatable or otherwise movable in response to the fluid density change. In one embodiment, the diverter is operable to control a fluid flow ratio through two valve inlets. The fluid flow ratio is used to operate a valve member to restrict fluid flow through the valve.

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Номер записи: 54
25-07-2013 дата публикации

Downhole Fluid Flow Control System Having a Fluidic Module with a Bridge Network and Method for Use of Same

Номер: US20130186634A1
Автор: Jason D. Dykstra, John Charles Gano, Luke William Holderman, Michael Linley Fripp
Принадлежит: Halliburton Energy Services Inc

A downhole fluid flow control system includes a fluidic module ( 150 ) having a bridge network. The bridge network has first and second branch fluid pathways ( 163, 164 ) each including at least one fluid flow resistors ( 174, 180 ) and a pressure output terminal ( 178, 184 ). In operation, the pressure difference between the pressure output terminals ( 178, 184 ) of the first and second branch fluid pathways ( 163, 164 ) is operable to control fluid flow through the fluidic module ( 150 ).

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Номер записи: 55
01-08-2013 дата публикации

METHOD AND APPARATUS FOR EXPENDABLE TUBING-CONVEYED PERFORATING GUN

Номер: US20130192829A1
Автор: Crowdis Dennis, Fadul Javier, Fripp Michael, Hales John, Herman Paul, Moore Randy, Powell Bryan, Ringgenberg Paul
Принадлежит: Halliburton Energy Services, Inc.

Methods and apparatus are presented for a “disappearing” perforator gun assembly. In a preferred method of perforating a well casing, inserted into the well casing is a tubing conveyed perforator having an outer tubular made from a metallic glass alloy having high strength and low impact resistance. An inner structure is positioned within the outer tubular and holds one or more explosive charges. Upon detonating the explosive charges, the outer tubular is fragmented. The inner structure is preferably also substantially destroyed upon detonation of the one or more explosive charges. For example, the inner structure can be made from a combustible material, corrodible, dissolvable, etc., material. A disintegration-enhancing material is optionally positioned between the outer tubular and the inner structure. Additional embodiments are presented having gun housings which dematerialize upon detonation of the charges. 1. A method of perforating a well casing , comprising the steps of:inserting into the well casing a tubing conveyed perforator having an outer tubular made from a metallic glass alloy having high strength and low impact resistance, and an inner structure positioned within the outer tubular and holding one or more explosive charges;detonating the one or more explosive charges; andfragmenting the outer tubular upon detonation of the one or more explosive charges.2. A method as in claim 1 , further comprising the step of substantially destroying the inner structure upon detonation of the one or more explosive charges.3. A method as in claim 2 , wherein the inner structure is made from a combustible material claim 2 , a corrodible material claim 2 , or a dissolvable material.4. The method of claim 1 , wherein the metallic glass alloy is selected from the group consisting of ZrTiNiCuBeMgCuTbFeCrMoCB.5. The method as in claim 1 , wherein the tubing conveyed perforator further comprises a disintegration-enhancing material positioned between the outer tubular and the ...

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Номер записи: 56
01-08-2013 дата публикации

OPENING OR CLOSING A FLUID FLOW PATH USING A MATERIAL THAT EXPANDS OR CONTRACTS VIA A CHANGE IN TEMPERATURE

Номер: US20130192833A1
Автор: FRIPP Michael L., GANO John C., WARREN Caleb T.
Принадлежит: Halliburton Energy Services, Inc.

A device for opening or closing a fluid flow path comprises: a fluid inlet, wherein the fluid inlet comprises one end of the fluid flow path; an inlet covering, wherein the inlet covering is adjacent to the fluid inlet; and a material, wherein the material is capable of expanding or contracting via a change in temperature; wherein the expansion or contraction of the material causes movement to the inlet covering, and wherein the movement of the inlet covering either opens or closes the fluid flow path. A method for opening or closing a fluid flow path using the device comprises: allowing or causing a change in temperature to the material. 1. A device for opening or closing a fluid flow path comprising:a fluid inlet, wherein the fluid inlet comprises one end of the fluid flow path;an inlet covering, wherein the inlet covering is adjacent to the fluid inlet; anda material, wherein the material is capable of expanding or contracting via a change in temperature;wherein the expansion or contraction of the material causes movement to the inlet covering, andwherein the movement of the inlet covering either opens or closes the fluid flow path.2. The device according to claim 1 , wherein the fluid flow path comprises a fluid outlet.3. The device according to claim 2 , wherein an inflow control device is located between the fluid inlet and the fluid outlet.4. The device according to claim 1 , wherein the material is selected from the group consisting of liquid forms of: water claim 1 , silicon claim 1 , germanium claim 1 , bismuth claim 1 , antimony claim 1 , gallium claim 1 , and metal alloys containing any of the aforementioned metals; shape-memory metals; and shape-memory plastics.5. The device according to claim 4 , wherein the material is capable of expanding with a decrease in temperature and contracting with an increase in temperature.6. The device according to claim 1 , wherein the material is selected from the group consisting of: shape-memory alloys claim 1 , shape- ...

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Номер записи: 57
15-08-2013 дата публикации

ECONOMICAL CONSTRUCTION OF WELL SCREENS

Номер: US20130206393A1
Автор: BONNER Aaron J., CUNNINGHAM Gregory S., FRANKLIN Matthew E., FRIPP Michael L., GRECI Stephen M., KUO Nicholas A., LEAST Brandon T., WARREN Caleb T.
Принадлежит: Halliburton Energy Services, Inc.

A well screen for use in a subterranean well can include a loose filter media, a sandstone, a square weave mesh material, a foam, and/or a nonmetal mesh material. A method of installing a well screen in a subterranean well can include dispersing a material in a filter media of the well screen, after the well screen has been installed in the well, thereby permitting a fluid to flow through the filter media. A method of constructing a well screen can include positioning a loose filter media in an annular space between a base pipe and a shroud, so that the filter media filters fluid which flows through a wall of the base pipe. 139-. (canceled)40. A well screen for use in a subterranean well , the well screen comprising:a generally tubular base pipe; anda filter media comprising a foam which filters fluid that flows between an interior and an exterior of the base pipe, wherein a dispersible material fills pores in the foam.41. The well screen of claim 40 , wherein the dispersible material comprises polylactic acid.42. The well screen of claim 40 , wherein the dispersible material comprises a wax.43. The well screen of claim 40 , wherein the dispersible material comprises a dissolvable material.44. The well screen of claim 40 , wherein the dispersible material comprises a salt.45. The well screen of claim 40 , wherein the dispersible material comprises a sugar.4693-. (canceled) This application claims the benefit under 35 USC §119 of the filing date of International Application Serial No. PCT/US12/24897, filed 13 Feb. 2012. The entire disclosure of this prior application is incorporated herein by this reference.This disclosure relates generally to equipment utilized and operations performed in conjunction with a subterranean well and, in one example described below, more particularly provides for economical construction of well screens.Well screens are used to filter fluid produced from earth formations. Well screens remove sand, fines, debris, etc., from the fluid. It ...

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Номер записи: 58
15-08-2013 дата публикации

ECONOMICAL CONSTRUCTION OF WELL SCREENS

Номер: US20130206406A1
Автор: BONNER Aaron J., CUNNINGHAM Gregory S., FRANKLIN Matthew E., FRIPP Michael L., GRECI Stephen M., KUO Nicholas A., LEAST Brandon T., WARREN Caleb T.
Принадлежит: Halliburton Energy Services, Inc.

A well screen for use in a subterranean well can include a loose filter media, a sandstone, a square weave mesh material, a foam, and/or a nonmetal mesh material. A method of installing a well screen in a subterranean well can include dispersing a material in a filter media of the well screen, after the well screen has been installed in the well, thereby permitting a fluid to flow through the filter media. A method of constructing a well screen can include positioning a loose filter media in an annular space between a base pipe and a shroud, so that the filter media filters fluid which flows through a wall of the base pipe. 1. A well screen for use in a subterranean well , the well screen comprising:a generally tubular base pipe; anda loose filter media proximate the base pipe, wherein the loose filter media is in contact with the base pipe.2. The well screen of claim 1 , wherein the loose filter media is retained in an annular space radially between the base pipe and a shroud.3. The well screen of claim 1 , wherein the loose filter media comprises sand.4. The well screen of claim 1 , wherein the loose filter media comprises proppant.5. The well screen of claim 1 , wherein the loose filter media comprises pieces of metal.6. The well screen of claim 1 , wherein the loose filter media comprises stone.7. The well screen of claim 1 , wherein the loose filter media comprises rubber.8. The well screen of claim 1 , wherein the loose filter media comprises a granular material.9. The well screen of claim 1 , wherein the loose filter media comprises interlocking shapes.10. The well screen of claim 1 , wherein the loose filter media comprises an aggregate material.11. The well screen of claim 1 , wherein the loose filter media comprises a composite material.12. The well screen of claim 1 , wherein the base pipe has a wall which separates an interior from an exterior of the base pipe claim 1 , and wherein the loose filter media filters fluid which flows through the base pipe ...

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Номер записи: 59
29-08-2013 дата публикации

Flow Control Devices on Expandable Tubing Run Through Production Tubing and Into Open Hole

Номер: US20130220640A1
Автор: Besselink Peter, Fripp Michael, Gano John, Van Moorleghem Wilfried
Принадлежит: Halliburton Energy Services, Inc.

Disclosed is a downhole completion assembly for sealing and supporting an open hole section of a wellbore and providing flow control through the downhole completion assembly. One downhole completion system includes a first sealing structure arranged within an open hole section of a wellbore and being movable between a contracted configuration and an expanded configuration, a second sealing structure arranged axially adjacent the first sealing structure and also being movable between a contracted configuration and an expanded configuration, and a flow control device arranged between the first and second sealing structures and configured to provide a flow path for fluids to communicate between a surrounding subterranean formation and an interior of the downhole completion system. 1. A downhole completion system , comprising:a first sealing structure configured to be expanded from a contracted configuration to an expanded configuration when arranged within an open hole section of a wellbore;a second sealing structure configured to be expanded from a contracted configuration to an expanded configuration when arranged proximally from the first sealing structure within the open hole section; anda flow control device arranged between the first and second sealing structures and configured to provide a flow path for fluids.2. The system of claim 1 , wherein claim 1 , the flow control device is configured to span a gap between the first and second sealing structures when in their respective expanded configurations and axially offset from each other.3. The system of claim 2 , wherein the flow control device axially overlaps a proximal connection section of the first sealing structure and a distal connection section of the second sealing structure.4. The system of claim 1 , wherein claim 1 , when in their respective expanded configurations claim 1 , the flow control device radially interposes the first and second sealing structures within the open hole section.5. The system of ...

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Номер записи: 60
29-08-2013 дата публикации

Expandable Conical Tubing Run Through Production Tubing and Into Open Hole

Номер: US20130220641A1
Автор: Besselink Peter, Fripp Michael, Gano John, Van Moorleghem Wilfried
Принадлежит: Halliburton Energy Services, Inc.

Disclosed is a downhole completion assembly for sealing and supporting an open hole section of a wellbore. One downhole completion system includes a first sealing structure having opposing first and second ends and being arranged within an open hole section of a wellbore, the first sealing structure being movable between a contracted configuration and an expanded configuration, and a second sealing structure having opposing first and second ends and being arranged proximate the first sealing structure within the wellbore, the second sealing structure also being movable between a contracted configuration and an expanded configuration, wherein, when in their respective expanded configurations, the first and second sealing structures are frustoconical in shape and the first end of the second sealing structure is at least partially nested within the second end of the first sealing structure. 1. A downhole completion system , comprising:a first sealing structure having opposing first and second ends, the first sealing structure being movable between a contracted configuration and an expanded configuration; anda second sealing structure having opposing first and second ends and being arranged proximate the first sealing structure, the second sealing structure also being movable between a contracted configuration and an expanded configuration,wherein, when in their respective expanded configurations, the first and second sealing structures are frustoconical in shape and the first end of the second sealing structure is at least partially nested within the second end of the first sealing structure.2. The system of claim 1 , further comprising a sealing element arranged about an outer radial surface of the second end of one or both of the first and second sealing structures claim 1 , the sealing element being configured to sealingly engage a section of a wellbore.3. The system of claim 1 , further comprising:a first sealing element arranged about an outer radial surface of ...

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Номер записи: 61
29-08-2013 дата публикации

Expandable Tubing Run Through Production Tubing and Into Open Hole

Номер: US20130220642A1
Автор: Besselink Peter, Fripp Michael, Gano John, Van Moorleghem Wilfried
Принадлежит: Halliburton Energy Services, Inc.

Disclosed is a downhole completion assembly for sealing and supporting an open hole section of a wellbore. One downhole completion system includes a sealing structure movable between a contracted configuration and an expanded configuration, wherein, when in the contracted configuration, the sealing structure is able to axially traverse production tubing extended within a wellbore, a conveyance device coupled to the sealing structure and configured to transport the sealing structure through the production tubing and to an open hole section of the wellbore, and a deployment device operably connected to the sealing structure and configured to radially expand the sealing structure from the contracted configuration to the expanded configuration when the sealing structure is arranged in the open hole section. 1. A downhole completion system , comprising:a sealing structure movable between a contracted configuration and an expanded configuration, wherein, when in the contracted configuration, the sealing structure is able to axially traverse production tubing extended within a wellbore;a conveyance device configured to couple to and transport the sealing structure through the production tubing; anda deployment device configured to radially expand the sealing structure from the contracted configuration to the expanded configuration.2. The system of claim 1 , wherein claim 1 , when in the expanded configuration claim 1 , the sealing structure engages an inner radial surface of an open hole section of the wellbore.3. The system of claim 1 , further comprising one or more sealing elements disposed about an outer radial surface of the sealing structure claim 1 , at least one of the one or more sealing elements being configured to seal against an inner radial surface of an open hole section of the wellbore when the sealing structure is in the expanded configuration.4. The system of claim 1 , wherein the deployment device comprises a hydraulic setting tool.5. The system of claim ...

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Номер записи: 62
29-08-2013 дата публикации

Expandable Tubing Run Through Production Tubing and Into Open Hole

Номер: US20130220643A1
Автор: Besselink Peter, Fripp Michael, Gano John, Van Moorleghem Wilfried
Принадлежит: Halliburton Energy Services, Inc.

Disclosed is a downhole completion assembly for sealing and supporting an open hole section of a wellbore. The system may include a sealing structure movable between contracted and expanded configurations, a truss structure also movable between contracted and expanded configurations, wherein, when in their respective contracted configurations, the sealing and truss structures are each able to axially traverse production tubing extended within a wellbore, a conveyance device operably coupled to the sealing and truss structures and configured to transport the sealing and truss structures in their respective contracted configurations through the production tubing and to an open hole section of the wellbore, and a deployment device operably connected to the sealing and truss structures and configured to radially expand the sealing and truss structures from their respective contracted configurations to their respective expanded configurations. 1. A downhole completion system , comprising:a sealing structure movable between a contracted configuration and an expanded configuration;a truss structure also movable between a contracted configuration and an expanded configuration, wherein, when in their respective contracted configurations, the sealing and truss structures are each able to axially traverse production tubing extended within a wellbore;a conveyance device configured to transport the sealing and truss structures in their respective contracted configurations through the production tubing and to an open hole section of the wellbore; anda deployment device configured to radially expand the sealing and truss structures from their respective contracted configurations to their respective expanded configurations, the truss structure being expanded while arranged at least partially within the sealing structure.2. The system of claim 1 , wherein claim 1 , when in the expanded configuration claim 1 , the sealing structure engages an inner radial surface of the open hole ...

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Номер записи: 63
29-08-2013 дата публикации

Enhanced Expandable Tubing Run Through Production Tubing and Into Open Hole

Номер: US20130220644A1
Автор: Besselink Peter, Fripp Michael, Gano John, Van Moorleghem Wilfried
Принадлежит: Halliburton Energy Services, Inc.

Disclosed is a downhole completion assembly for sealing and supporting an open hole section of a wellbore and filtering fluids passing therethrough. One system includes a sealing structure arranged within the open hole section and being movable between a contracted configuration and an expanded configuration, the sealing structure having one or more perforations defined therein, and a filter device arranged about the sealing structure so as to radially overlap the one or more perforations, the filter device being configured to screen fluids passing through the one or more perforations. 1. A downhole completion system , comprising:a sealing structure configured to be expanded from a contracted configuration to an expanded configuration, the sealing structure having one or more perforations defined therein; anda filter device arranged about the sealing structure so as to overlap at least one of the one or more perforations when the sealing structure is in the expanded configuration, the filter device being configured to screen fluids passing through the at least one of the one or more perforations.2. The system of claim 1 , wherein the filter device is expandable with the sealing structure.3. The system of claim 1 , further comprising a shroud coupled to the filter device.4. The system of claim 3 , wherein the shroud is impermeable and directs the fluids passing through the at least one of the one or more perforations to pass through at least one of an end and a side of the filter device.5. The system of claim 1 , further comprising one or more flow control devices coupled to at least one of the one or more perforations and configured to regulate fluid flow through the at least one of the one or more perforations.6. The system of claim 5 , wherein the one or more flow control devices are selected from the group consisting of an inflow control device claim 5 , an autonomous inflow control device claim 5 , a valve claim 5 , a sleeve claim 5 , a sleeve valve claim 5 , a ...

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Номер записи: 64
29-08-2013 дата публикации

METHOD AND APPARATUS FOR REMOTELY CONTROLLING DOWNHOLE TOOLS USING UNTETHERED MOBILE DEVICES

Номер: US20130222148A1
Автор: Fripp Michael, GANO John C., Holderman Luke W., Lopez Jean Marc, Simonds Floyd R.
Принадлежит: Halliburton Energy Services, Inc.

Remote operation of downhole tools in a subterranean wellbore is performed by inserting untethered, mobile devices sequentially into the wellbore. The mobile devices can include motive means, power supply, communication and data storage means, etc. In one embodiment, the method comprises maneuvering a first mobile device into proximity with a downhole tool, the device powering the tool. The first device is then removed, such as by flowing up or dissolving. The now-powered tool is used to perform a test or other operation. A second mobile device is maneuvered into proximity with the downhole tool and data is transferred. The second device is retrieved with the data or, using on-board logic devices, provides “if-then” commands to the downhole tool. Alternately, a third mobile device can be used to power and transfer commands to the tool. The method can be used for various tasks, such as opening bypass ports on ICD valves. 1. A method for remote operation of a downhole tool positioned in a subterranean wellbore extending from the surface and through at least one hydrocarbon-bearing zone , the method comprising the steps of:maneuvering an untethered, first mobile device from the surface into proximity with a downhole tool positioned in the wellbore; thentransferring an electrical signal between the maneuvered first mobile device and the downhole tool; thenremoving the first mobile device from proximity with the downhole tool; thenmaneuvering an untethered, second mobile device from the surface into proximity with the downhole tool; and thentransferring data between the downhole tool and the second mobile device; andrunning a production test in the wellbore after the step of powering the downhole tool by utilizing the maneuvered first mobile device.27-. (canceled)8. A method for remote operation of a downhole tool positioned in a subterranean wellbore extending from the surface and through at least one hydrocarbon-bearing zone , the method comprising the steps of: ...

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Номер записи: 65
05-09-2013 дата публикации

Downhole Fluid Flow Control System Having Pressure Sensitive Autonomous Operation

Номер: US20130228341A1
Автор: Fripp Michael Linley, Gano John Charles
Принадлежит: Halliburton Energy Services, Inc.

A downhole fluid flow control system is operable to be positioned in a wellbore in a fluid flow path between a formation and an internal passageway of a tubular. The system includes a flow control component positioned in the fluid flow path that is operable to control fluid flow therethrough. The system also includes a pressure sensitive valve positioned in the fluid flow path in parallel with the flow control component. The valve autonomously shifts from a first position to a second position responsive to a change in a pressure signal received by the valve, thereby enabling fluid flow therethrough. 1. A downhole fluid flow control system operable to be positioned in a wellbore in a fluid flow path between a formation and an internal passageway of a tubular , the system comprising:a flow control component positioned in the fluid flow path operable to control fluid flow therethrough; anda pressure sensitive valve positioned in the fluid flow path in parallel with the flow control component, the valve autonomously shifting from a first position to a second position responsive to a change in a pressure signal received by the valve, thereby enabling fluid flow therethrough.2. The flow control system as recited in wherein the flow control component further comprises an inflow control device.3. The flow control system as recited in wherein the flow control component has directional dependent flow resistance.4. The flow control system as recited in wherein the pressure sensitive valve further comprises a sliding sleeve.5. The flow control system as recited in wherein the pressure sensitive valve further comprises a biasing constituent that biases the sliding sleeve in opposition to at least one component of the pressure signal.6. The flow control system as recited in wherein the pressure signal further comprises borehole pressure generated by formation fluid.7. The flow control system as recited in wherein the pressure signal further comprises tubing pressure.8. The flow ...

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Номер записи: 66
03-10-2013 дата публикации

METHOD AND APPARATUS FOR AUTONOMOUS DOWNHOLE FLUID SELECTION WITH PATHWAY DEPENDENT RESISTANCE SYSTEM

Номер: US20130255960A1
Автор: DeJesus Orlando, DYKSTRA Jason D., Fripp Michael Linley
Принадлежит:

An apparatus is described for controlling fluid flow in a downhole tubular. Fluid is flowed through a flow control system having a flow ratio control system and a pathway dependent resistance system. The flow ratio control system has a first and second passageway, where the ratio of fluid flowing through the passageways dependent on a characteristic of the fluid flow. The pathway dependent resistance system includes a vortex chamber with a first inlet directing flow primarily tangentially into the vortex chamber and the second inlet directing flow primarily radially into the vortex chamber. Undesired fluids, such as gas or water, in an oil well, are directed, based on their relative fluid flow characteristics, into the vortex primarily tangentially, thereby restricting flow when the undesired fluid is present. 1. A well device for installation in a wellbore in a subterranean zone , comprising:a fluid diode in fluid communication between an interior and an exterior of the well device.2. The well device of claim 1 , wherein the fluid diode is in fluid communication between the interior and the exterior to communicate production fluid from the exterior of the well device to the interior of the well device.3. The well device of claim 2 , wherein the well device comprises a section of a completion string.4. The well device of claim 1 , wherein the fluid diode is in fluid communication between the interior and the exterior to communicate injection fluid from the interior of the well device to the exterior of the well device.5. The well device of claim 4 , wherein the well device comprises a section of a working string.6. The well device of claim 1 , wherein the fluid diode comprises:an interior surface that defines an interior chamber, the interior surface includes a side perimeter surface and opposing end surfaces;a first port through one of the end surfaces; anda second port through the interior surface and apart from the first port.7. The well device of claim 6 , the ...

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Номер записи: 67
10-10-2013 дата публикации

Well tools selectively responsive to magnetic patterns

Номер: US20130264051A1
Автор: Donald G. Kyle, Matthew J. MERRON, Michael L. Fripp
Принадлежит: Halliburton Energy Services Inc

A system for use with a subterranean well can include a magnetic sensor, a magnetic device which propagates a magnetic field to the magnetic sensor, and a barrier positioned between the magnetic sensor and the magnetic device. The barrier can comprise a relatively low magnetic permeability material. A method of isolating a magnetic sensor from a magnetic device in a subterranean well can include separating the magnetic sensor from the magnetic device with a barrier interposed between the magnetic sensor and the magnetic device, the barrier comprising a relatively low magnetic permeability material. A well tool can include a housing having a flow passage formed through the housing, a magnetic sensor in the housing, and a barrier which separates the magnetic sensor from the flow passage, the barrier having a lower magnetic permeability as compared to the housing.

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Номер записи: 68
17-10-2013 дата публикации

METHOD OF SIMULTANEOUSLY STIMULATING MULTIPLE ZONES OF A FORMATION USING FLOW RATE RESTRICTORS

Номер: US20130269950A1
Автор: DYKSTRA Jason D., FRIPP Michael L.
Принадлежит: Halliburton Energy Services, Inc.

A method of simultaneously stimulating at least a first zone and a second zone of a subterranean formation comprises: flowing a fluid through at least a first flow rate restrictor and a second flow rate restrictor, wherein: (A) the first flow rate restrictor is located adjacent to the first zone, (B) the second flow rate restrictor is located adjacent to the second zone, (C) the first and second flow rate restrictors are connected in parallel, and (D) as at least one of the properties of the fluid changes, the flow rates of the fluid exiting the first and second flow rate restrictors are similar within a flow rate range; and allowing the fluid to stimulate at least the first zone and the second zone. 1. A method of simultaneously stimulating at least a first zone and a second zone of a subterranean formation comprising: (A) the first flow rate restrictor is located adjacent to the first zone,', '(B) the second flow rate restrictor is located adjacent to the second zone,', '(C) the first and second flow rate restrictors are connected in parallel, and', '(D) as at least one of the properties of the fluid changes, the flow rates of the fluid exiting the first and second flow rate restrictors are similar within a flow rate range; and, 'flowing a fluid through at least a first flow rate restrictor and a second flow rate restrictor, whereinallowing the fluid to stimulate at least the first zone and the second zone.2. The method according to claim 1 , wherein the fluid is an acidizing fluid.3. The method according to claim 1 , wherein the fluid is a heterogeneous fluid.4. The method according to claim 3 , wherein the fluid is a fracturing fluid.5. The method according to claim 1 , wherein the step of flowing further comprises flowing two or more fluids through at least the first and the second flow rate restrictors.6. The method according to claim 1 , further comprising a third flow rate restrictor claim 1 , wherein the third flow rate restrictor is located adjacent to a ...

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Номер записи: 69
24-10-2013 дата публикации

ALTERNATING FLOW RESISTANCE INCREASES AND DECREASES FOR PROPAGATING PRESSURE PULSES IN A SUBTERRANEAN WELL

Номер: US20130277066A1
Автор: DYKSTRA Jason D., FRIPP Michael L.
Принадлежит:

A method of propagating pressure pulses in a well can include flowing a fluid composition through a variable flow resistance system which includes a vortex chamber having at least one inlet and an outlet, a vortex being created when the fluid composition spirals about the outlet, and a resistance to flow of the fluid composition alternately increasing and decreasing. The vortex can be alternately created and dissipated in response to flowing the fluid composition through the system. A well system can include a variable flow resistance system which propagates pressure pulses into a formation in response to flow of a fluid composition from the formation. 1. A method of propagating pressure pulses in a subterranean well , the method comprising:flowing a fluid composition through at least one variable flow resistance system which includes a vortex chamber having at least one inlet and an outlet, a vortex being created when the fluid composition flows spirally about the outlet; anda resistance to flow of the fluid composition through the vortex chamber alternately increasing and decreasing.2. The method of claim 1 , wherein the vortex is alternately created and dissipated in response to the step of flowing the fluid composition through the variable flow resistance system.3. The method of claim 1 , wherein the pressure pulses are propagated upstream from the variable flow resistance system when the flow resistance alternately increases and decreases.4. The method of claim 1 , wherein the pressure pulses are propagated downstream from the variable flow resistance system when the flow resistance alternately increases and decreases.5. The method of claim 1 , wherein the pressure pulses are propagated from the variable flow resistance system into a subterranean formation when the flow resistance alternately increases and decreases.6. The method of claim 1 , wherein the pressure pulses are propagated through a gravel pack when the flow resistance alternately increases and ...

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Номер записи: 70
07-11-2013 дата публикации

Degradable Balls for Use in Subterranean Applications

Номер: US20130292123A1
Автор: Fripp Michael Linley, FULTON Dwight, Liang Feng, MURPHREE Zachary Ryan, WALTON Zachary William
Принадлежит:

Degradable balls for downhole use may include an incompliant degradable polymer and a compliant filler material, the incompliant degradable polymer having an elastic modulus of about 2 GPa or greater, and the compliant filler material having an elastic modulus of less than about 2 GPa. Such degradable balls may be useful in sealing segments of a wellbore and actuating wellbore tools. 1. A degradable ball for downhole use , the degradable ball comprising: an incompliant degradable polymer and a compliant filler material , the incompliant degradable polymer having an elastic modulus of about 2 GPa or greater , and the compliant filler material having an elastic modulus of less than about 2 GPa.2. The degradable ball of claim 1 , wherein the incompliant degradable polymer comprises at least one selected from the group consisting of poly(glycolic acid) claim 1 , crystalline poly(lactic acid) claim 1 , semi-crystalline poly(lactic acid) claim 1 , a polyhydroxyalkonate claim 1 , poly(hydroxybutyrate) claim 1 , an aliphatic polyester claim 1 , a polycarbonate claim 1 , an aliphatic polycarbonate claim 1 , a polyorthoester claim 1 , polyethylene terephthalate claim 1 , a copolymer thereof claim 1 , and a blend thereof.3. The degradable ball of claim 1 , wherein the compliant filler material comprises at least one selected from the group consisting of a vulcanized rubber particle claim 1 , a rubber fiber claim 1 , a thermoplastic particle claim 1 , a thermoplastic fiber claim 1 , a hollow glass sphere claim 1 , a hollow ceramic sphere claim 1 , a hollow metal sphere claim 1 , a hollow thermoplastic sphere claim 1 , a particulate of a compliant degradable polymer claim 1 , and any combination thereof.4. The degradable ball of claim 1 , wherein the compliant filler material comprises a plurality of particulates having an average diameter of about 50 nm to about 500 nm.5. The degradable ball of claim 1 , wherein the compliant filler material comprises a plurality of ...

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Номер записи: 71
14-11-2013 дата публикации

Downhole Fluid Flow Control System and Method Having Autonomous Closure

Номер: US20130299198A1
Автор: Fripp Michael Linley, Gano John Charles
Принадлежит: Halliburton Energy Services, Inc.

A downhole fluid flow control system for autonomously controlling the inflow of production fluids. The fluid flow control system includes a flow control assembly having a fluid flow path through which a fluid flows. A support structure is positioned in the fluid flow path. A plug is releasably coupled to the support structure such that when fluid flow through the fluid flow path induces sufficient movement in the support structure, the movement causes release of the plug from the support structure into the fluid flow path, thereby restricting subsequent fluid flow in at least one direction through the fluid flow path. 1. A downhole fluid flow control system comprising:a flow control assembly having a fluid flow path through which a fluid flows;a support structure positioned in the fluid flow path; anda plug releasably coupled to the support structure,wherein, fluid flow through the fluid flow path past the support structure induces movement in the support structure; andwherein, movement of the support structure causes release of the plug into the fluid flow path, thereby restricting fluid flow in at least one direction through the fluid flow path.2. The downhole fluid flow control system as recited in wherein the plug further comprises one of a spherical plug claim 1 , a spheroidal plug and a dart plug.3. The downhole fluid flow control system as recited in wherein the movement of the support structure further comprises oscillation of the support structure.4. The downhole fluid flow control system as recited in wherein the movement of the support structure causes the support structure to fatigue.5. The downhole fluid flow control system as recited in wherein the movement of the support structure causes the support structure to break.6. The downhole fluid flow control system as recited in wherein movement of the support structure increases responsive to an increase in fluid velocity.7. The downhole fluid flow control system as recited in wherein movement of the ...

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Номер записи: 72
21-11-2013 дата публикации

EROSION REDUCTION IN SUBTERRANEAN WELLS

Номер: US20130306318A1
Автор: ECHOLS Ralph H., FRIPP Michael L., Frosell Thomas J., SEVADJIAN Emile E.
Принадлежит:

A system for use with a subterranean well can include a tubular string with a fluid discharge apparatus, the fluid discharge apparatus including a curved flow path which directs a fluid to flow less toward a structure external to the tubular string. A fluid discharge apparatus can include a generally tubular housing having a longitudinal axis, and at least one curved flow path which directs fluid to flow more parallel to the longitudinal axis from an interior of the housing to an exterior of the housing. A method of mitigating erosion of a structure external to a discharge port in a well can include directing a fluid to flow through a curved flow path, thereby reducing impingement of the fluid on the structure in the well. 1. A method of mitigating erosion of a structure external to a fluid discharge apparatus in a subterranean well , the method comprising:directing a fluid to flow through a curved flow path, thereby reducing impingement of the fluid on the structure in the well, wherein the curved flow path is installed in an upstream portion of a generally tubular housing, wherein the upstream portion of the housing is radially enlarged relative to a downstream portion of the housing, and wherein the curved flow path is installed at a transition between the upstream and downstream portions.2. The method of claim 1 , wherein the curved flow path is interconnected in a tubular string claim 1 , and wherein the curved flow path induces the fluid to flow longitudinally through an annulus formed between the tubular string and the structure.3. (canceled)4. The method of claim 1 , further comprising mixing abrasive particles with the fluid prior to the directing step.5. The method of claim 1 , wherein the structure comprises a protective lining for a wellbore.6. The method of claim 1 , wherein the structure comprises a wall of a wellbore.7. The method of claim 1 , wherein the structure comprises a protective shroud in a wellbore.8. The method of claim 1 , wherein a flow ...

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Номер записи: 73
12-12-2013 дата публикации

METHODS OF REMOVING A WELLBORE ISOLATION DEVICE USING GALVANIC CORROSION

Номер: US20130327540A1
Автор: DAGENAIS Pete, Fripp Michael, HAMID Syed
Принадлежит: Halliburton Energy Services, Inc.

A wellbore isolation device comprises: at least a first material, wherein the first material: (A) is a metal or a metal alloy; and (B) is capable of at least partially dissolving when an electrically conductive path exists between the first material and a second material and at least a portion of the first and second materials are in contact with an electrolyte, wherein the second material: (i) is a metal or metal alloy; and (ii) has a greater anodic index than the first material. A method of removing the wellbore isolation device comprises: contacting or allowing the wellbore isolation device to come in contact with an electrolyte; and allowing at least a portion of the first material to dissolve. 1. A method of removing a wellbore isolation device comprising: (A) is a metal or a metal alloy; and', '(B) is capable of at least partially dissolving when an electrically conductive path exists between the first material and a second material and at least a portion of the first and second materials are in contact with the electrolyte,', (i) is a metal or metal alloy; and', '(ii) has a greater anodic index than the first material; and, 'wherein the second material], 'at least a first material, wherein the first material, 'contacting or allowing the wellbore isolation device to come in contact with an electrolyte, wherein the wellbore isolation device comprisesallowing at least a portion of the first material to dissolve.2. The method according to claim 1 , wherein the isolation device is capable of restricting or preventing fluid flow between a first zone and a second zone of the wellbore.3. The method according to claim 1 , wherein isolation device is a ball and a seat claim 1 , a plug claim 1 , a bridge plug claim 1 , a wiper plug claim 1 , or a packer.4. The method according to claim 1 , wherein the metal or metal alloy of the first material and the second material are selected from the group consisting of claim 1 , beryllium claim 1 , tin claim 1 , iron claim 1 , ...

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Номер записи: 74
12-12-2013 дата публикации

Systems and methods to harvest fluid energy in a wellbore using preloaded magnetostrictive elements

Номер: US20130328316A1
Автор: Michael Fripp, Paul F. Rodney
Принадлежит: Halliburton Energy Services Inc

A magnetostrictor assembly ( 100 ) includes a magnetostrictor element ( 105 ), a conductor coupled to the magnetostrictor element, and a bluff body ( 101 ) coupled to the magnetostrictor element via a transfer arm ( 103 ). The bluff body is to be placed in a fluid flow path to, at least in part, produce motion that, at least in part, causes strain in the magnetostrictor element. A preload mechanism comprising a control circuit ( 1100 ) may optimize a magnetostrictive generator.

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Номер записи: 75
12-12-2013 дата публикации

LOCATION OF DOWNHOLE LINES

Номер: US20130329522A1
Автор: FRIPP Michael L., Skinner Neal G.
Принадлежит: Halliburton Energy Services, Inc.

A method of determining an azimuthal orientation of a well tool relative to a line in a well can include connecting at least one acoustic source to the well tool, the acoustic source having a known azimuthal orientation relative to the well tool, and detecting at least one acoustic signal transmitted from the acoustic source to an acoustic sensor, the acoustic sensor having a known azimuthal orientation relative to the line. A system for determining an azimuthal orientation of one or more lines relative to a well tool in a wellbore can include at least one acoustic source having a known azimuthal orientation relative to the well tool, and an optical waveguide connected to a distributed acoustic sensing instrumentation, the waveguide having a known azimuthal orientation relative to the lines, and in which the distributed acoustic sensing instrumentation detects acoustic signals transmitted from the acoustic source to the waveguide. 1. A method of determining an azimuthal orientation of a well tool relative to a line in a well , the method comprising:connecting at least one acoustic source to the well tool, the acoustic source having a known azimuthal orientation relative to the well tool; anddetecting at least one acoustic signal transmitted from the acoustic source to an acoustic sensor, the sensor having a known azimuthal orientation relative to the line.2. The method of claim 1 , wherein the acoustic sensor comprises an optical waveguide.3. The method of claim 2 , wherein the line comprises the waveguide claim 2 , whereby the waveguide has the same azimuthal orientation as the line.4. The method of claim 2 , wherein the waveguide is positioned external to a casing.5. The method of claim 2 , wherein distributed acoustic signals are detected along the waveguide.6. The method of claim 2 , wherein the acoustic signal is detected at multiple longitudinally spaced apart locations along the waveguide.7. The method of claim 1 , wherein the line is positioned external to a ...

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Номер записи: 76
19-12-2013 дата публикации

METHODS OF REMOVING A WELLBORE ISOLATION DEVICE USING A EUTECTIC COMPOSITION

Номер: US20130333890A1
Автор: DAGENAIS Pete, Fripp Michael, HAMID Syed
Принадлежит: Halliburton Energy Services, Inc.

A wellbore isolation device comprises: a first composition, wherein the first composition comprises: (A) a first substance; and (B) a second substance, wherein the first composition has a solid-liquid phase transformation temperature less than the solid-liquid phase transformation temperatures of at least the first substance or the second substance at a specific pressure. A method of removing a wellbore isolation device comprises: increasing the temperature surrounding the wellbore isolation device; and allowing at least a portion of the first composition to undergo a phase transformation from a solid to a liquid. A method of inhibiting or preventing fluid flow in a wellbore comprises: decreasing the temperature of at least a portion of the wellbore; positioning the wellbore isolation device in the at least a portion of the wellbore; and increasing the temperature of the at least a portion of the wellbore. 1. A method of removing a wellbore isolation device comprising: [ (i) a first substance; and', '(ii) a second substance,, 'a first composition, wherein the first composition comprises, 'wherein the first composition has a solid-liquid phase transformation temperature less than the solid-liquid phase transformation temperatures of at least the first substance or the second substance at a specific pressure; and, 'increasing the temperature surrounding the wellbore isolation device, wherein the wellbore isolation device comprisesallowing at least a portion of the first composition to undergo a phase transformation from a solid to a liquid.2. The method according to claim 1 , wherein isolation device is a ball claim 1 , a plug claim 1 , a bridge plug claim 1 , a wiper plug claim 1 , or a packer.3. The method according to claim 1 , wherein the first composition is a eutectic composition claim 1 , a hypo-eutectic composition claim 1 , or a hyper-eutectic composition.4. The method according to claim 1 , wherein the first and second substances are different.5. The method ...

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Номер записи: 77
19-12-2013 дата публикации

WELLBORE ISOLATION DEVICE CONTAINING A SUBSTANCE THAT UNDERGOES A PHASE TRANSITION

Номер: US20130333891A1
Автор: FRIPP Michael L., HOWELL Matthew T., WALTON Zachary W.
Принадлежит: Halliburton Energy Services, Inc.

A wellbore isolation device comprises: a substance, wherein the substance: (A) is a plastic; and (B) undergoes a phase transition at a phase transition temperature, wherein the temperature surrounding the wellbore isolation device is increased or allowed to increase to a temperature that is greater than or equal to the phase transition temperature. A method of removing a wellbore isolation device comprises: causing or allowing the temperature surrounding the wellbore isolation device to increase; and allowing at least a portion of the substance to undergo the phase transformation. A method of inhibiting or preventing fluid flow in a wellbore comprises: decreasing the temperature of at least a portion of the wellbore; positioning the wellbore isolation device in the at least a portion of the wellbore; and causing or allowing the temperature surrounding the wellbore isolation device to increase. 1. A method of removing a wellbore isolation device comprising: (A) is a plastic; and', '(B) undergoes a phase transition at a phase transition temperature,', 'wherein the temperature surrounding the wellbore isolation device is increased or allowed to increase to a temperature that is greater than or equal to the phase transition temperature; and, 'causing or allowing the temperature surrounding the wellbore isolation device to increase, wherein the wellbore isolation device comprises a substance, wherein the substanceallowing at least a portion of the substance to undergo the phase transformation.2. The method according to claim 1 , wherein isolation device is a ball claim 1 , a plug claim 1 , a bridge plug claim 1 , a wiper plug claim 1 , or a packer.3. The method according to claim 2 , wherein the ball is a frac ball.4. The method according to claim 1 , wherein the plastic is a thermoplastic.5. The method according to claim 1 , wherein the substance is a polymer.6. The method according to claim 5 , wherein the polymer is a homopolymer or a copolymer.7. The method according ...

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Номер записи: 78
26-12-2013 дата публикации

HYDRAULIC PUMP WITH SOLID-STATE ACTUATOR

Номер: US20130343918A1
Автор: Dudley James H., FRIPP Michael L.
Принадлежит:

A hydraulic pump includes a port and a piston assembly fluidically coupled to the port. The piston assembly includes a piston and a solid-state actuator, where a shape change of the solid-state actuator is induced when a field is applied to the solid-state actuator, and where alternating shape changes of the solid-state actuator provide reciprocating movement to the piston. 1. A hydraulic pump comprising:a port; 'a piston; and', 'a piston assembly fluidically coupled to the port, wherein the piston assembly comprisesa solid-state actuator, wherein a shape change of the solid-state actuator is induced when a field is applied to the solid-state actuator, and wherein alternating shape changes of the solid-state actuator provide reciprocating movement to the piston.2. The hydraulic pump of claim 1 , wherein the field is a magnetic field.3. The hydraulic pump of claim 1 , wherein the field is an electric field.4. The hydraulic pump of claim 1 , wherein the port comprises an inlet or an outlet.5. The hydraulic pump of claim 1 , wherein the solid-state actuator comprises one or both of a magnetostrictive material and a piezoelectric material.6. The hydraulic pump of claim 1 , wherein the piston assembly further comprises:a coil disposed about the solid-state actuator to apply the field to the solid-state actuator.7. The hydraulic pump of claim 1 , further comprising an inlet valve and an outlet valve to rectify fluid flow through the port.8. The hydraulic pump of claim 1 , further comprising an inlet valve and an outlet valve fluidically coupled to the piston to facilitate a steady flow passage.9. The hydraulic pump of claim 1 , wherein the solid-state actuator comprises a stack of plates connected in parallel claim 1 , wherein the plates comprise piezoelectric material or magnetostrictive material.10. The hydraulic pump of claim 1 , wherein the piston assembly is part of an arrangement of piston assemblies to be driven together.11. The hydraulic pump of claim 10 , wherein ...

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Номер записи: 79
16-01-2014 дата публикации

FLUID FLOW CONTROL USING CHANNELS

Номер: US20140014351A1
Автор: DYKSTRA Jason D., Fripp Michael Linley, Zhao Liang
Принадлежит: Halliburton Energy Srvices, Inc.

A fluid flow control device disposable in a bore can include channels that can direct fluid flow based on one or more properties of the fluid more robustly. The channels may include a side channel between two other channels. The side channel can allow fluid flow to affect fluid flowing in one of the channels. Devices according to some aspects can differentiate between fluids having close, but different, properties and direct the fluid accordingly. Examples of fluid properties based on which the device can direct fluid include fluid density, fluid velocity, fluid viscosity, and Reynolds number of the fluid flow. 12-. (canceled)3. The subassembly of claim 4 , wherein the at least one fluid property comprises:Reynolds number of the fluid;fluid density;fluid velocity; orfluid viscosity.4. A subassembly for a fluid flow control device adapted to be disposed in a subterranean wellbore claim 4 , the subassembly comprising:a chamber having an exit opening:a first channel for directing fluid from a first inlet toward the chamber;a second channel for directing fluid from a second inlet toward the chamber; anda side channel for allowing fluid to flow from the second channel to the first channel to affect fluid flowing in the first channel;a primary channel in fluid communication with the first channel, the primary channel being configured for directing fluid toward the exit opening;a first diverted channel in fluid communication with the first channel; anda second diverted channel in fluid communication with the second channel,wherein the first diverted channel and the second diverted channel are configured for directing fluid toward a tangential opening of the chamber,wherein the side channel is adapted to allow an amount of fluid to flow from the second channel to the first channel to guide fluid to flow toward the primary channel, the amount of fluid being based on the at least one property of the fluid.5. The channel subassembly of claim 20 , wherein the fourth channel ...

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Номер записи: 80
30-01-2014 дата публикации

Expandable Screen Using Magnetic Shape Memory Alloy Material

Номер: US20140027108A1
Автор: Fripp Michael, Greci Stephen Michael, Lopez Jean-Marc
Принадлежит: Halliburton Energy Services, Inc.

A well screen assembly for use in a wellbore comprises a base pipe comprising one or more fluid passageways, and a shape-memory alloy disposed about the base pipe. The one or more fluid passageways are configured to provide fluid communication between an exterior of the base pipe and a central flowbore, and the shape-memory alloy is configured to transition between an expanded state and a compressed state in response to a trigger. 1. A well screen assembly for use in a wellbore comprising:a base pipe comprising one or more fluid passageways, wherein the one or more fluid passageways are configured to provide fluid communication between an exterior of the base pipe and a central flowbore; anda shape-memory alloy disposed about the base pipe, wherein the shape-memory alloy is configured to transition between an expanded state and a compressed state in response to a trigger.2. The well screen assembly of claim 1 , further comprising a filter element disposed about the base pipe claim 1 , wherein the shape-memory alloy is disposed between the base pipe and the filter element claim 1 , and wherein the shape-memory alloy is configured to expand the filter element when transitioned to the expanded state.3. The well screen assembly of claim 1 , further comprising a filter element disposed about the base pipe claim 1 , wherein the filter element is disposed between the base pipe and the shape-memory alloy.4. The well screen assembly of claim 3 , wherein the shape-memory alloy is configured to reduce a distance between a wellbore wall and the filter element when transitioned from the compressed state to the expanded state.5. The well screen assembly of claim 1 , further comprising a shroud disposed about and coupled to the base pipe.6. The well screen assembly of claim 5 , where the shape-memory alloy is coupled to the shroud between the shroud and the base pipe claim 5 , and wherein the shape-memory alloy is configured to expand radially inward when transitioned from the ...

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Номер записи: 81
06-02-2014 дата публикации

METHOD AND APPARATUS FOR EXPENDABLE TUBING-CONVEYED PERFORATING GUN

Номер: US20140034384A1
Автор: Crowdis Dennis, Fadul Javier, Fripp Michael, Hales John, Herman Paul, Moore Randy, Powell Bryan, Ringgenberg Paul
Принадлежит: Halliburton Energy Services, Inc.

Methods and apparatus are presented for a “disappearing” perforator gun assembly. In a preferred method of perforating a well casing, inserted into the well casing is a tubing conveyed perforator having an outer tubular made from a metallic glass alloy having high strength and low impact resistance. An inner structure is positioned within the outer tubular and holds one or more explosive charges. Upon detonating the explosive charges, the outer tubular is fragmented. The inner structure is preferably also substantially destroyed upon detonation of the one or more explosive charges. For example, the inner structure can be made from a combustible material, corrodible, dissolvable, etc., material. A disintegration-enhancing material is optionally positioned between the outer tubular and the inner structure. Additional embodiments are presented having gun housings which dematerialize upon detonation of the charges. 1. A method of perforating a well casing , comprising the steps of:inserting into the well casing a tubing conveyed perforator having an outer tubular made from a metallic glass alloy having high strength and low impact resistance, and an inner structure positioned within the outer tubular and holding one or more explosive charges;detonating the one or more explosive charges; andfragmenting the outer tubular upon detonation of the one or more explosive charges.2. A method as in claim 1 , further comprising the step of substantially destroying the inner structure upon detonation of the one or more explosive charges.3. A method as in claim 2 , wherein the inner structure is made from a combustible material claim 2 , a corrodible material claim 2 , or a dissolvable material.4. The method of claim 1 , wherein the metallic glass alloy is selected from the group consisting of ZrTiNiCuBeMgCuTbFeCrMoCB.5. The method as in claim 1 , wherein the tubing conveyed perforator further comprises a disintegration-enhancing material positioned between the outer tubular and the ...

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Номер записи: 82
13-02-2014 дата публикации

AUTONOMOUS FLUID CONTROL ASSEMBLY HAVING A MOVABLE, DENSITY-DRIVEN DIVERTER FOR DIRECTING FLUID FLOW IN A FLUID CONTROL SYSTEM

Номер: US20140041731A1
Автор: DeJesus Orlando, DYKSTRA Jason, FRIPP Michael L.
Принадлежит: Halliburton Energy Services, Inc.

An apparatus is presented for autonomously controlling fluid flow in a subterranean well, the fluid having a density which changes over time. An embodiment of the apparatus has a vortex chamber, a vortex outlet, and first and second inlets into the vortex chamber. Flow into the inlets is directed by a fluid control system which has a control passageway for directing fluid flow as it exits a primary passageway. A movable fluid diverter positioned in the control passageway moves in response to change in fluid density to restrict fluid flow through the control passageway. When fluid flow through the control passageway is unrestricted, fluid from the control passageway directs fluid exiting the primary passageway toward a selected vortex inlet. When flow through the control passageway is unrestricted, flow from the primary passageway is directed into the other vortex inlet. 1. An apparatus for autonomously controlling fluid flow in a subterranean well , the fluid having a density which changes over time , the apparatus comprising:a vortex assembly having a vortex chamber, a vortex outlet, and a first flow inlet and a second flow inlet into the vortex chamber;a fluid control system having a first fluid passageway and a second passageway, fluid exiting the first and second passageway directed into the vortex assembly; anda movable fluid diverter positioned in the second passageway, the fluid diverter moved by change in the fluid density, the fluid diverter movable to restrict fluid flow through the second passageway in response to change in the fluid density.2. An apparatus as in claim 1 , wherein the second passageway is for directing fluid flow as it exits the first fluid passageway.3. An apparatus as in claim 1 , the fluid control system further comprising a third passageway claim 1 , and a movable fluid diverter positioned in the third passageway.4. An apparatus as in claim 3 , wherein the second and third passageways are for directing fluid flow as it exits the first ...

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Номер записи: 83
20-02-2014 дата публикации

METHOD AND APPARATUS FOR CONTROLLING FLUID FLOW IN AN AUTONOMOUS VALVE USING A STICKY SWITCH

Номер: US20140048280A9
Автор: DYKSTRA Jason D., FRIPP Michael L.
Принадлежит: Halliburton Energy Services, Inc.

Apparatus and methods are described for autonomously controlling fluid flow in a tubular in a wellbore. A fluid is flowed through an inlet passageway into a biasing mechanism. A fluid flow distribution is established across the biasing mechanism. The fluid flow distribution is altered in response to a change in the fluid characteristic over time. In response, fluid flow through a downstream sticky switch assembly is altered, thereby altering fluid flow patterns in a downstream vortex assembly. The method “selects” based on a fluid characteristic, such as viscosity, density, velocity, flow rate, etc. The biasing mechanism can take various forms such as a widening passageway, contour elements along the biasing mechanism, or a curved section of the biasing mechanism passageway. The biasing mechanism can include hollows formed in the passageway wall, obstructions extending from the passageway wall, fluid diodes, Tesla fluid diodes, a chicane, or abrupt changes in passageway cross-section. 1. A method for controlling flow of fluid in a wellbore extending through a subterranean formation , the fluid having a characteristic which changes over time , the fluid flowing through an inlet passageway , a flow biasing mechanism , and a variable flow resistance assembly , the method comprising the following steps:flowing fluid through the inlet passageway;establishing a first fluid flow distribution across an outlet of the flow biasing mechanism; thenaltering the first fluid flow distribution to a second flow distribution across the outlet of the flow biasing mechanism in response to a change in the fluid characteristic; andchanging the fluid flow resistance of the variable flow resistance assembly in response to the altering of the distribution of flow from the outlet of the flow biasing mechanism.2. A method as in claim 1 , further comprising the step of flowing the fluid to the surface or into the formation.3. A method as in claim 1 , further comprising the steps of ...

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Номер записи: 84
20-02-2014 дата публикации

METHOD AND APPARATUS FOR AUTONOMOUS DOWNHOLE FLUID SELECTION WITH PATHWAY DEPENDENT RESISTANCE SYSTEM

Номер: US20140048282A1
Автор: DeJesus Orlando, DYKSTRA Jason D., Fripp Michael Linley, GANO John C., Holderman Luke
Принадлежит: Halliburton Energy Services, Inc.

Apparatus and methods for controlling the flow of fluid, such as formation fluid, through an oilfield tubular positioned in a wellbore extending through a subterranean formation. Fluid flow is autonomously controlled in response to change in a fluid flow characteristic, such as density or viscosity. In one embodiment, a fluid diverter is movable between an open and closed position in response to fluid density change and operable to restrict fluid flow through a valve assembly inlet. The diverter can be pivotable, rotatable or otherwise movable in response to the fluid density change. In one embodiment, the diverter is operable to control a fluid flow ratio through two valve inlets. The fluid flow ratio is used to operate a valve member to restrict fluid flow through the valve. 18-. (canceled)9. A flow control device for installation in a subterranean wellbore , the flow control device comprising:an interior surface that defines an interior chamber, the interior surface includes a side perimeter surface and opposing end surfaces, a greatest distance between the opposing end surfaces is smaller than a largest dimension of the opposing end surfaces;a first port through one of the end surfaces; anda plurality of second ports through the interior surface and apart from the first port, each of the plurality of second ports having open first and second ends for allowing fluid flow therethrough, the first ends in fluid communication with the interior chamber and the second ends in fluid communication with a common fluid source, the side perimeter surface operable to direct flow from at least one of the plurality of second ports to rotate about the first port.10. The flow control device of claim 9 , wherein the first port comprises an outlet from the interior chamber and the plurality of second ports comprises a plurality of inlets to the interior chamber.11. The flow control device of claim 10 , the plurality of inlets comprising a first inlet oriented to direct flow from ...

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Номер записи: 85
20-03-2014 дата публикации

Expandable Screen by Spring Force

Номер: US20140076540A1
Автор: Bonner Aaron James, Fripp Michael, Kang James Jun
Принадлежит: HALLIBURTON ENERGY SERVICES, INC

A sand control screen assembly selectively positionable within a wellbore. The sand control screen assembly comprises a pipe having an internal flow path, an external fluid collection subassembly in fluid communication with the internal flow path, a filter medium disposed in a fluid path between the exterior of the sand control screen assembly and the internal flow path, a biasing mechanism, configured to bias the fluid collection subassembly towards a wall of the wellbore, disposed between the fluid collection subassembly and the pipe, and a retaining mechanism configured to release the biasing mechanism in response to a trigger. 1. A sand control screen assembly selectively positionable within a wellbore , the sand control screen assembly comprising:a pipe comprising an internal flow path disposed therethrough;a fluid collection subassembly disposed externally to the pipe and in fluid communication with the internal flow path, wherein the fluid collection subassembly is configured to prevent at least some particulate matter from entering the internal flow path;a biasing mechanism disposed between the fluid collection subassembly and the pipe, wherein the biasing mechanism is configured to bias the fluid collection subassembly towards a wall of the wellbore; anda retaining mechanism configured to release the biasing mechanism in response to a trigger.2. The sand control screen assembly of claim 1 , wherein the retaining mechanism comprises an acid reactive material.3. The sand control screen assembly of claim 2 , wherein the retaining mechanism comprises at least one of barium claim 2 , sodium claim 2 , manganese claim 2 , chromium claim 2 , iron claim 2 , cobalt claim 2 , nickel claim 2 , zinc claim 2 , aluminum claim 2 , magnesium claim 2 , calcium claim 2 , tin claim 2 , alloys thereof claim 2 , compositions thereof claim 2 , or any combination thereof.4. The sand control screen assembly of claim 1 , wherein the retaining mechanism directly engages the biasing ...

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Номер записи: 86
27-03-2014 дата публикации

Expandable Screen by Spring Force

Номер: US20140083720A1
Автор: Bonner Aaron James, Fripp Michael, Kang James Jun
Принадлежит: Halliburton Energy Services, Inc.

A sand control screen assembly selectively positionable within a wellbore. The sand control screen assembly comprises a pipe having an internal flow path, an external fluid collection subassembly in fluid communication with the internal flow path, a filter medium disposed in a fluid path between the exterior of the sand control screen assembly and the internal flow path, a biasing mechanism, configured to bias the fluid collection subassembly towards a wall of the wellbore, disposed between the fluid collection subassembly and the pipe, and a retaining mechanism configured to release the biasing mechanism in response to a trigger. 1. A sand control screen assembly selectively positionable within a wellbore , the sand control screen assembly comprising:a pipe comprising an internal flow path disposed therethrough;a fluid collection subassembly disposed externally to the pipe and in fluid communication with the internal flow path, wherein the fluid collection subassembly is configured to prevent at least some particulate matter from entering the internal flow path;a biasing mechanism disposed between the fluid collection subassembly and the pipe, wherein the biasing mechanism is configured to bias the fluid collection subassembly towards a wall of the wellbore, and wherein the biasing mechanism comprises at least one spring; anda retaining mechanism configured to release the biasing mechanism in response to a trigger.2. The sand control screen assembly of claim 1 , wherein the retaining mechanism comprises an acid reactive material.3. The sand control screen assembly of claim 2 , wherein the retaining mechanism comprises at least one of barium claim 2 , sodium claim 2 , manganese claim 2 , chromium claim 2 , iron claim 2 , cobalt claim 2 , nickel claim 2 , zinc claim 2 , aluminum claim 2 , magnesium claim 2 , calcium claim 2 , tin claim 2 , alloys thereof claim 2 , compositions thereof claim 2 , or any combination thereof.4. The sand control screen assembly of claim 1 ...

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Номер записи: 87
27-03-2014 дата публикации

METHOD AND APPARATUS FOR EXPENDABLE TUBING-CONVEYED PERFORATING GUN

Номер: US20140083764A1
Автор: Crowdis Dennis, Fadul Javier, Fripp Michael, Hales John, Herman Paul, Moore Randy, Powell Bryan, Ringgenberg Paul
Принадлежит: Halliburton Energy Services, Inc.

Methods and apparatus are presented for a “disappearing” perforator gun assembly. In a preferred method of perforating a well casing, inserted into the well casing is a tubing conveyed perforator having an outer tubular made from a metallic glass alloy having high strength and low impact resistance. An inner structure is positioned within the outer tubular and holds one or more explosive charges. Upon detonating the explosive charges, the outer tubular is fragmented. The inner structure is preferably also substantially destroyed upon detonation of the one or more explosive charges. For example, the inner structure can be made from a combustible material, corrodible, dissolvable, etc., material. A disintegration-enhancing material is optionally positioned between the outer tubular and the inner structure. Additional embodiments are presented having gun housings which dematerialize upon detonation of the charges. 162-. (canceled)63. A method of perforating a well casing positioned downhole in a well , comprising the steps of:inserting into the well casing a tubing conveyed perforator having an outer tubular member and an inner structure positioned within the outer tubular, the inner structure holding one or more explosive charges, and a support structure without which the outer tubular member would collapse after insertion into the well;detonating the one or more explosive charges;damaging the support structure in response to the detonation; andcollapsing the outer tubular in response to damaging the support structure.64. A method of claim 63 , further comprising damaging a wire frame support structure positioned exterior to the charges.65. A method of claim 64 , further comprising combusting detonation cord attached to the wire frame support structure.66. A method of claim 63 , wherein the step of collapsing further includes the step of telescoping adjacent segments of outer tubular members.67. A method as in claim 63 , wherein the step of collapsing further includes ...

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Номер записи: 88
03-04-2014 дата публикации

Flow control devices on expandable tubing run through production tubing and into open hole

Номер: US20140090857A1
Автор: John Gano, Michael Fripp, Peter Besselink, Wilfried Van Moorleghem
Принадлежит: Halliburton Energy Services Inc

Disclosed is a downhole completion assembly for sealing and supporting an open hole section of a wellbore and providing flow control through the downhole completion assembly. One downhole completion system includes a first sealing structure arranged within an open hole section of a wellbore and being movable between a contracted configuration and an expanded configuration, a second sealing structure arranged axially adjacent the first sealing structure and also being movable between a contracted configuration and an expanded configuration, and a flow control device arranged between the first and second sealing structures and configured to provide a flow path for fluids to communicate between a surrounding subterranean formation and an interior of the downhole completion system.

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Номер записи: 89
06-01-2022 дата публикации

DISSOLVABLE SETTING TOOL FOR HYDRAULIC FRACTURING OPERATIONS

Номер: US20220003096A1
Автор: Fripp Michael Linley, Penno Andrew, Winkler Albert
Принадлежит:

A system for deploying an untethered dissolvable frac package for use in a hydraulic fracturing operation includes a dissolvable or degradable frac package with a dissolvable or degradable setting tool. The setting tool of the dissolvable frac package is configured to deploy a dissolvable frac plug at a predetermined position along the wellbore string and dissolve over time in the wellbore. 1. A wellbore system useful in hydraulic fracturing or stimulation operations , the system comprising:a wellbore string extending into a subterranean wellbore;a frac plug including a seal element movable from a first radially inward position to a second radially outward position to engage the wellbore string in response to movement to the second radially outward position;a dissolvable setting device including an actuator operably coupled to the frac plug to selectively move the seal element from the first position to the second position in response to receiving a trigger signal, the dissolvable setting device constructed of dissolvable materials such that the dissolvable setting device degrades into individual particles less than one half inch diameter in wellbore fluids and or acid; anda controller carried by the dissolvable setting tool, the controller operable to detect a predetermined depth in the wellbore string, and to provide the trigger signal to the actuator in response to detecting the predetermined depth.2. The wellbore system according to claim 1 , wherein the wellbore system comprises a bypass passage extending at least partially through the frac plug claim 1 , the bypass passage being open to receive a fluid from above the frac plug when the seal element is in the second position in the wellbore string.3. The wellbore system according to claim 2 , wherein the bypass passage is fluidly coupled with a pressure relief valve claim 2 , the pressure relief valve operable to prevent flow through the bypass passage until activated and permit flow through the bypass passage ...

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Номер записи: 90
07-01-2016 дата публикации

ISOLATION DEVICES CONTAINING A TRANSFORMING MATRIX AND A GALVANICALLY-COUPLED REINFORCEMENT AREA

Номер: US20160002999A1
Автор: FRIPP Michael L., Murphree Zachary R., WALTON Zachary W.
Принадлежит:

A method of using a wellbore isolation device comprises: introducing the wellbore isolation device into the wellbore, wherein the isolation device comprises: (A) a matrix, wherein the matrix has a phase transition temperature less than or equal to the bottomhole temperature of the wellbore; and (B) at least one reinforcement area, wherein the reinforcement area: (i) comprises at least a first material, wherein the first material undergoes galvanic corrosion; and (ii) has a greater tensile strength and/or shear strength than the matrix. 1. A method of using a wellbore isolation device comprising: (A) a matrix, wherein the matrix has a phase transition temperature less than or equal to the bottomhole temperature of the wellbore; and', (i) comprises at least a first material, wherein the first material undergoes galvanic corrosion; and', '(ii) has a greater tensile strength and/or shear strength than the matrix., '(B) at least one reinforcement area, wherein the reinforcement area], 'introducing the wellbore isolation device into the wellbore, wherein the isolation device comprises2. The method according to claim 1 , wherein the isolation device is a ball claim 1 , a plug claim 1 , a bridge plug claim 1 , a wiper plug claim 1 , or a packer.3. The method according to claim 1 , wherein the isolation device restricts or prevents fluid flow between a first zone and a second zone of a subterranean formation claim 1 , wherein the wellbore penetrates the subterranean formation.4. The method according to claim 1 , wherein the matrix comprises a metal claim 1 , a metal alloy claim 1 , a polymer claim 1 , or combinations thereof.5. The method according to claim 4 , wherein the metal alloy is a fusible metal alloy.6. The method according to claim 5 , wherein the matrix is a eutectic claim 5 , hypo-eutectic claim 5 , or hyper-eutectic composition.7. The method according to claim 4 , wherein the polymer is a thermoplastic.8. The method according to claim 1 , wherein the first ...

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Номер записи: 91
07-01-2016 дата публикации

TUBING PRESSURE OPERATED DOWNHOLE FLUID FLOW CONTROL SYSTEM

Номер: US20160003005A1
Автор: Fripp Michael, Pickle Brad R.
Принадлежит:

A downhole flow control system utilizes a tubing pressure operated valve to selectively open and close fluid flow across the system. The tubing pressure operated valve includes a piston responsive to tubing pressure, and a valve element responsive to piston movement. The valve element can be moved rotationally, longitudinally, or both, in response to the piston movement. The valve is movable between a closed and at least one open position. The piston and valve elements can be releasably attachable, such as by a one-way ratchet. The valve element can be a rotating valve operable by a J-slot mechanism to rotate to multiple positions in response to movement of the piston element. 1. A downhole fluid flow control system operable to be positioned in a wellbore extending through a subterranean formation and operable to control fluid flow between the wellbore and an internal passageway of a tubular , the system comprising:a tubing-pressure operated device positioned along a flow path between the interior passageway of the tubular and the exterior of the tubular;a piston element, biased towards a first position, slidably disposed in a piston annulus, the piston annulus having a pressure-transmitting port to the interior passageway of the tubular, the piston element movable to a second position responsive to a tubing-pressure change transmitted through the pressure-transmitting port; anda valve element attached to the piston element and movable in response to movement of the piston element between a closed position wherein fluid flow is blocked across the flow path and an open position wherein flow is allowed across the flow path.2. The system of claim 1 , wherein the flow path passes through a bypass port defined in the piston element.3. The system of claim 2 , wherein the piston element further includes a check valve positioned thereon operable to control fluid flow through the bypass port.4. The system of claim 1 , wherein the flow path passes through the piston annulus.5 ...

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Номер записи: 92
02-01-2020 дата публикации

CASING CONVEYED, EXTERNALLY MOUNTED PERFORATION CONCEPT

Номер: US20200003024A1
Автор: Barker James Marshall, DUSTERHOFT Ronald Glen, Fripp Michael Linley, Smith Jonathan Paul
Принадлежит:

Provided is an untethered downhole tool assembly. The untethered downhole tool assembly, in one aspect, includes a housing and a signal generator located on or in the housing, the signal generator capable of transmitting a passive or active signal to a downhole device located on an outside of a metal wellbore casing as it travels through an inside of the metal wellbore casing. 1. An untethered downhole tool assembly , comprising:a housing; anda signal generator located on or in the housing, the signal generator capable of transmitting a passive or active signal to a downhole device located on an outside of a metal wellbore casing as it travels through an inside of the metal wellbore casing.2. The untethered downhole tool assembly as recited in claim 1 , wherein the signal generator is capable of transmitting a passive magnetic signal claim 1 , passive acoustic signal claim 1 , passive vibration signal claim 1 , or a passive radiation signal through the metal wellbore casing.3. The untethered downhole tool assembly as recited in claim 1 , further including a power source located within the housing claim 1 , and further wherein the signal generator is a powered transmitter capable of transmitting an active wireless signal through the metal wellbore casing.4. The untethered downhole tool assembly as recited in claim 3 , wherein the powered transmitter is adapted to embed instructions for the downhole device on the active wireless signal.5. The untethered downhole tool assembly as recited in claim 1 , further including a radially deployable packer element coupled to the housing claim 1 , the radially deployable packer element movable from a radially retracted state to a radially deployed state.6. The untethered downhole tool assembly as recited in claim 5 , wherein the radially deployable packer element is movable from the radially retracted state to the radially deployed state upon receiving one or more signals from the downhole device located on the outside of the ...

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Номер записи: 93
02-01-2020 дата публикации

CASING CONVEYED, EXTERNALLY MOUNTED PERFORATION CONCEPT

Номер: US20200003033A1
Автор: Barker James Marshall, DUSTERHOFT Ronald Glen, Fripp Michael Linley, Smith Jonathan Paul
Принадлежит:

Provided is a downhole perforating device, a well system, and a method for perforating a well system. The downhole perforating device, in one aspect, includes a perforating structure for surrounding at least a portion of an outer surface of a wellbore casing. The downhole perforating device, according to this aspect, includes one or more perforation elements at least partially embodied within the perforating structure, the one or more perforation elements positioned to perforate the wellbore casing to an inside thereof, and electronics at least partially embodied within the perforating structure, the electronics for triggering the one or more perforation elements. 1. A downhole perforating device , comprising:a perforating structure for surrounding at least a portion of an outer surface of a wellbore casing;one or more perforation elements at least partially embodied within the perforating structure, the one or more perforation elements positioned to perforate the wellbore casing to an inside thereof; andelectronics at least partially embodied within the perforating structure, the electronics for triggering the one or more perforation elements.2. The downhole perforating device as recited in claim 1 , wherein the electronics include a receiver for sensing a radio frequency signal claim 1 , electromagnetic signal claim 1 , magnetic signal claim 1 , acoustic signal claim 1 , or vibration signal emanating from inside the wellbore casing.3. The downhole perforating device as recited in claim 2 , wherein the receiver is located radially outside an inner diameter of the wellbore casing.4. The downhole perforating device as recited in claim 1 , further including a power source at least partially embodied within the perforating structure claim 1 , the power source for powering the electronics.5. The downhole perforating device as recited in claim 1 , wherein the perforating structure has two or more radially spaced wellbore casing centralizers claim 1 , and further wherein ...

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Номер записи: 94
12-01-2017 дата публикации

Swab-Resistant Downhole Tools Comprising Sealing Elements Composed Of Shape Memory Polymers

Номер: US20170009552A1
Автор: Fripp Michael Linley, FROSELL Thomas, MURPHREE Zachary Ryan, ZHONG Xiaoguang Allan
Принадлежит: Halliburton Energy Services, Inc.

A swab-resistant downhole tool comprising a body and a sealing element, wherein at least a portion of the sealing element is composed of a shape memory polymer, the shape memory polymer having a glass transition temperature (“Tg”), and exhibiting a resilient characteristic above the Tg and a rigid characteristic below the Tg, and wherein the Tg is in the range of about 50° C. to about 150° C. 1. A swab-resistant downhole tool comprising a body and a sealing element ,wherein at least a portion of the sealing element is composed of a shape memory polymer, the shape memory polymer having a glass transition temperature (“Tg”), and exhibiting a resilient characteristic above the Tg and a rigid characteristic below the Tg, andwherein the Tg is in the range of about 50° C. to about 150° C.2. The swab-resistant downhole tool of claim 1 , wherein the shape memory polymer is selected from the group consisting of a thiol-based polymer claim 1 , an amorphous plastic claim 1 , and any combination thereof.3. The swab-resistant downhole tool of claim 2 , wherein the thiol-based polymer is selected from the group consisting of a thiol-ene reaction product claim 2 , a thiol-yne reaction product claim 2 , a thiol-epoxy reaction product claim 2 , and any combination thereof.4. The swab-resistant downhole tool of claim 2 , wherein the amorphous plastic is selected from the group consisting of polystyrene claim 2 , polymethylmethacrylate claim 2 , polyvinylchloride claim 2 , polyethylene terephthalate claim 2 , polyphenylene sulfide claim 2 , polycaprolactam claim 2 , and any combination thereof.5. The swab-resistant downhole tool of claim 1 , wherein the portion of the sealing element that is composed of the shape memory polymer encapsulates a rubber component.6. The swab-resistant downhole tool of claim 1 , wherein the portion of the sealing element that is composed of the shape memory polymer is encapsulated by rubber.7. A method comprising: 'wherein at least a portion of the sealing ...

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Номер записи: 95
12-01-2017 дата публикации

FLUIDIC PULSER FOR DOWNHOLE TELEMETRY

Номер: US20170009574A1
Автор: Felten Frederic, Fripp Michael Linley, Frosell Thomas Jules, MURPHREE Zachary Ryan, SHAH VIMAL
Принадлежит:

An example method includes providing fluid communication between an internal bore of a drill string and an annulus between the drill string and a borehole through a fluid channel in a side of a collar coupled to the drill string. Fluid may be circulated through the internal bore of the drill string. A fluid telemetry signal may be generated by selectively generating a vortex within the fluid channel. Providing fluid communication between the internal bore and the annulus through the fluid channel may include providing fluid communication between the internal bore and a vortex basin at least partially defining the fluid channel, through at least one of a first fluid flow path and a second fluid flow path between the vortex basin and the internal bore; and providing fluid communication between the vortex basin and the annulus through a fluid outlet of the vortex basin. 1. A method , comprising:providing fluid communication between an internal bore of a drill string and an annulus between the drill string and a borehole through a fluid channel in a side of a collar coupled to the drill string;circulating fluid through the internal bore of the drill string; andgenerating a fluid telemetry signal by selectively generating a vortex within the fluid channel.2. The method of claim 1 , wherein providing fluid communication between the internal bore and the annulus through the fluid channel comprisesproviding fluid communication between the internal bore and a vortex basin at least partially defining the fluid channel, through at least one of a first fluid flow path and a second fluid flow path between the vortex basin and the internal bore; andproviding fluid communication between the vortex basin and the annulus through a fluid outlet of the vortex basin.3. The method of claim 2 , whereinproviding fluid communication between the internal bore and the vortex basin through at least one of a first fluid flow path and a second fluid flow path comprises providing fluid ...

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Номер записи: 96
10-01-2019 дата публикации

Variable Flow Resistance System for Use with a Subterranean Well

Номер: US20190010783A1
Автор: Fripp Michael Linley, Frosell Thomas Jules, Kabir Zahed, MURPHREE Zachary Ryan
Принадлежит: Halliburton Energy Services, Inc.

A variable flow resistance system for use with a subterranean well includes a first flow path to receive a fluid, a flow rate sensor to measure a flow rate of the fluid received into the first flow path, and an actuator to control an inflow rate of the fluid received into the first flow path based upon the measured flow rate of the fluid. 1. A variable flow resistance system for use with a subterranean well , the system comprising:a first flow path to receive a fluid;a flow rate sensor to measure a flow rate of the fluid received into the first flow path; andan actuator to control an inflow rate of the fluid received into the first flow path based upon the measured flow rate of the fluid.2. The variable flow resistance system of claim 1 , wherein the flow rate sensor measures flow rate fluctuations of the fluid received into the first flow path claim 1 , the system further comprising:a receiver comprising the flow rate sensor to receive a control signal through the measured flow rate fluctuations of the fluid;wherein the actuator controls the inflow rate of the fluid received into the first flow path based upon the control signal received by the receiver.3. The variable flow resistance system of claim 2 , further comprising:a transmitter to transmit the control signal by generating the flow rate fluctuations of the fluid.4. The variable flow resistance system of claim 3 , wherein the transmitter is coupled to a choke claim 3 , a valve claim 3 , or a pump to generate the flow rate fluctuations of the fluid.5. The variable flow resistance system of claim 1 , further comprising a controller configured to control the actuator based upon the measured flow rate of the fluid claim 1 , wherein the actuator adjusts the inflow rate of the fluid received into the first flow path.6. The variable flow resistance system of claim 1 , further comprising a power source to provide power to the variable flow resistance system.7. The variable flow resistance system of claim 6 , wherein ...

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Номер записи: 97
09-01-2020 дата публикации

Tapered Fluidic Diode For Use As An Autonomous Inflow Control Device AICD

Номер: US20200011153A1
Автор: FELTEN Frederic Nicolas, Fripp Michael Linley, Greci Stephen Michael
Принадлежит:

A system for providing autonomous flow control of a fluid from a wellbore to an interior of a tubing string by using a variable flow resistance system. The system can include a body, with a chamber that can be configured to induce rotational flow in a fluid that flows through the chamber. The chamber can include an inlet for fluid entering the chamber and an outlet for fluid exiting the chamber. A cross-sectional area of the chamber can be reduced along a central axis of the chamber toward the outlet, with the cross-sectional area being perpendicular to a central axis. A well screen assembly may utilize one or more of the variable flow resistance systems to provide a determined flow resistance and/or flow rate of the fluid through the screen assembly. 1. A variable flow resistance system providing autonomous flow control of a fluid , the system comprising:a body;a chamber in the body, with the chamber configured to induce rotational flow in a fluid that flows through the chamber;an inlet through which the fluid enters the chamber;an outlet from which the fluid exits the chamber;the chamber having a cross-sectional area that decreases along a central axis of the chamber toward the outlet, wherein the cross-sectional area is perpendicular to a central axis; anda resistance to fluid flow through the chamber varies based on a physical property of the fluid.2. The system of claim 1 , wherein the inlet is angled away from the central axis of the chamber and the angle induces the rotational flow in the fluid.3. The system of claim 1 , wherein the physical property is at least one of viscosity claim 1 , velocity claim 1 , and density.4. The system of claim 1 , wherein the resistance to the fluid flow through the chamber is increased when an undesired fluid flows through the chamber and is decreased when a desired fluid flows through the chamber.5. The system of claim 4 , wherein the desired fluid is hydrocarbon liquid and the undesired fluid is gas and/or water.6. The ...

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Номер записи: 98
09-01-2020 дата публикации

SENSOR NIPPLE AND PORT FOR DOWNHOLE PRODUCTION TUBING

Номер: US20200011172A1
Автор: BROWN Clint Adam, Fripp Michael Linley, Frosell Thomas Jules, MARCUCCIO Suzi Marie
Принадлежит: HALLIBURTON ENERGY SERVICES

A tubular string formed by one or more tubulars with a central flow passage for an internal fluid therethrough and an external surface. The tubular having a wall thickness defined between external surface and the central flow passage and at least one sensor port disposed along a longitudinal length of the tubular. At least one sensor includes a main body and=nipple extending from the main body and inserted into the sensor port of the tubular. The nipple extends through the wall thickness sufficient to detect a property of an internal fluid within the central flow passage. 1. An array of sensors comprising:a plurality of communicatively coupled sensors disposed along a longitudinal length of a tubular string, the tubular string having a central flow passage therethrough;at least one of the plurality of sensors having a main body and a nipple extending from the main body, the nipple shaped for entry into a corresponding sensor port of a tubular of the tubular string, the nipple extending toward the central flow passage.2. The array of sensors of claim 1 , wherein the at least one of the plurality of sensors having the nipple includes a seal about the nipple for a sealed coupling with the corresponding sensor port of the tubular.3. The array of sensors of claim 1 , wherein the at least of the plurality of sensors having the nipple is coupled with the tubular via a clamp or seal.4. The array of sensors of claim 1 , wherein the plurality of sensors are connected claim 1 , one to the other claim 1 , via a conductive line.5. The array of sensors of claim 1 , wherein the sensor port extends from an external surface of the tubular toward the central flow passage claim 1 , the sensor port extending at least a portion of a wall thickness of the tubular.6. The array of sensors of claim 1 , wherein the sensor port is in fluidic communication with the central flow passage.7. A tubular string comprising:a tubular having a central flow passage for an internal fluid and an external ...

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Номер записи: 99
19-01-2017 дата публикации

IN-LINE RECEIVER AND TRANSMITTER FOR DOWNHOLE ACOUSTIC TELEMETRY

Номер: US20170016319A1
Автор: Fripp Michael Linley, Kyle Donald, WERKHEISER Gregory Thomas
Принадлежит:

An in-well type acoustic telemetry system includes an elongate tubular housing, an elongate transmitter in the tubular housing, and a receiver in the tubular housing. The transmitter is adapted to generate an output acoustic signal by linearly fluctuating along a transmitter axis in response to an electrical signal. The receiver is adapted to generate a second electrical signal by linearly fluctuating along a receiver axis that is parallel to or coincides with the transmitter axis. 1. An in-well type acoustic telemetry system , comprising:an elongate tubular housing;an elongate transmitter in the tubular housing adapted to generate an output acoustic signal by linearly fluctuating along a transmitter axis in response to an electrical signal; anda receiver in the tubular housing adapted to generate a second electrical signal by linearly fluctuating along a receiver axis that is parallel to or coincides with the transmitter axis.2. The system of claim 1 , where the transmitter comprises a laminated stack of an electrically responsive material adapted to strain along the transmitter axis in response to the electrical signal.3. The system of claim 2 , where the receiver comprises a laminated stack of electrically responsive material adapted to convert strain along the receiver axis into the second electrical signal.4. The system of claim 3 , where the transmitter and the receiver are configured as a unitary transceiver.5. The system of claim 3 , where the electrically responsive material comprises at least one item selected from the group consisting of piezoceramic wafers claim 3 , a piezoelectric claim 3 , a piezopolymer claim 3 , an electrostrictor claim 3 , and a ferroelectric material.6. The system of claim 1 , where the transmitter and the receiver each comprises an electrically responsive material selected from the group consisting of an electromagnetic voice coil and a magnetostrictor.7. The system of claim 1 , where the transmitter is adjacent the receiver.8. ...

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Номер записи: 100
17-01-2019 дата публикации

Degradable Abrasive For Erosive Jet Cutting

Номер: US20190017329A1
Автор: Fripp Michael Linley, Gano John Charles, Lanclos Brady, Walton Zach
Принадлежит:

An erosive jet can propel degradable, abrasive grit conveyed in a carrier fluid to erode a downhole structure, such as a tubular (e.g., cutting through a tubular) or formation (e.g., perforation actions). The abrasive grit can be selected to degrade or dissolve in the wellbore fluid (e.g., in carrier fluid pumped into the wellbore or in fluid originating from the wellbore). The abrasive grit can provide increased cutting or erosion efficiency in the erosive jet during the cutting operation, then may degrade (e.g., dissolve) in the wellbore fluid to avoid certain complications, such as clogging or residue build-up in the wellbore formation or on downhole equipment. A degradation accelerator can be introduced (e.g., in carrier fluid) to accelerate degradation of the abrasive grit in the wellbore fluid. Degradation accelerators can be temperature-activated, pH-activated, or otherwise time-delayed so the abrasive grit remains sufficiently intact to perform the desired erosion operation. 1. A method , comprising:supplying an erosion fluid to a downhole tool having a nozzle, the erosion fluid having an abrasive grit carried in a carrier fluid, the abrasive grit having a metal component and being degradable within wellbore fluid;outputting the erosion fluid through the nozzle at a pressure suitable for eroding a target material; andexposing the erosion fluid to the wellbore fluid to allow the erosion fluid to degrade within the wellbore fluid.2. The method of claim 1 , further comprising:adjusting a composition of the erosion fluid, wherein adjusting the composition of the erosion fluid includes mixing an additional carrier fluid component into the erosion fluid, wherein the additional carrier fluid component is selected to alter a susceptibility of the abrasive grit to degrade within the wellbore fluid.3. The method of claim 1 , further comprising:adjusting a composition of the erosion fluid by mixing an additional grit component into the erosion fluid, wherein the ...

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Номер записи: 101
17-04-2014 дата публикации

METHOD AND APPARATUS FOR MIXING FLUID FLOW IN A WELLBORE USING A STATIC MIXER

Номер: US20140102706A1
Автор: Fripp Michael Linley, Patton Ed
Принадлежит: Halliburton Energy Services, Inc.

Methods and apparatus are presented for mixing fluid flowing through a wellbore extending through a subterranean formation. A static mixer assembly is positioned in a tubing string, the mixer having a plurality of vanes extending radially into an interior fluid flow passageway. Downhole tools are movable through a tool passageway defined in the static mixer assembly. The tools can pass unobstructed by the fixed vanes. Alternately, the tool can flex the elastic vanes as it passes through, the vanes returning to position after passage of the tool. The vanes are preferably circumferentially spaced and longitudinally spaced. The vanes can extend from an interior wall surface of the assembly or from a sleeve inserted into the mixer assembly. 1. A method for mixing a fluid flowing through a wellbore extending through a subterranean formation , the method comprising the steps of:positioning a static mixer assembly in a tubing string along the wellbore, the tubing string defining an interior passageway which extends through the static mixer assembly, the static mixer having a plurality of static mixer vanes extending radially into the interior passageway;flowing a fluid through a fluid passageway defined through the static mixer assembly;mixing at least two components of the fluid using the static mixer assembly; andmoving a downhole tool through the interior passageway and through the static mixer assembly.2. The method as in claim 1 , wherein the plurality of static mixer vanes are circumferentially spaced apart and longitudinally spaced apart.3. The method as in claim 1 , wherein the static mixer vanes define an unobstructed passageway claim 1 , and wherein the step of moving a downhole tool further comprises the step of moving the downhole tool through the unobstructed passageway.4. The method as in claim 1 , the static mixer having a bore extending therethrough claim 1 , and wherein the plurality of static mixer vanes are positioned in an annular space defined by a ...

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Номер записи: 102
17-04-2014 дата публикации

PERFORATING ASSEMBLY CONTROL

Номер: US20140102788A1
Автор: Dagenais Pete C., FRIPP Michael L.
Принадлежит: Halliburton Energy Services, Inc.

A perforating assembly includes a material that can respond to a magnetic field by changing shape multiple times and causing a fire control circuit to activate and deactivate. The material may be a magnetic shape-memory alloy and can change shape when the magnetic field is removed or inverted. When the material changes shape, the material can cause another component of the perforating assembly to change position to activate or deactivate the fire control circuit, as desired. 1. A perforating assembly positionable in a wellbore traversing a subterranean formation , the perforating assembly comprising:a fire control circuit; anda material adapted to change shape multiple times in response to a magnetic field for causing the fire control circuit to activate and deactivate.2. The perforating assembly of claim 1 , wherein the material comprises a magnetic shape-memory alloy.3. The perforating assembly of claim 1 , wherein the perforating assembly is a tubing conveyed perforating gun.4. The perforating assembly of claim 1 , wherein the material is adapted to change shape in response to the magnetic field that is proximate to a wellhead of the wellbore.5. The perforating assembly of claim 1 , wherein the material is adapted to change shape in response to the magnetic field that is from a stationary device.6. The perforating assembly of claim 1 , wherein the fire control circuit is an initiator mechanism or a propagation mechanism for a charge in the perforating assembly.7. The perforating assembly of claim 1 , further comprising:a housing in which is defined a chamber, wherein the fire control circuit is located in the chamber, the fire control circuit comprising an upper portion and a lower portion; anda control device located in the chamber between the upper portion and the lower portion, the control device comprising the material.8. The perforating assembly of claim 7 , wherein the control device comprises:a control device housing comprising a body and a housing cap ...

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Номер записи: 103
21-01-2021 дата публикации

Metal That Hydrates In Wellbore Fluid And Creates An Expanding Cement

Номер: US20210017441A1
Автор: Fripp Michael Linley, Greci Stephen Michael, WALTON Zachary William
Принадлежит:

Methods and systems that utilize reactive metals that hydrate in the presence of a wellbore fluid. The reactive metals can be utilized in cement compositions, on the outer surface of the oilfield tubular in the form of a layer of the reactive metal(s), or on the outer surface of the oilfield tubular in the form of a layer of a composition that includes the reactive metal(s). 1. A method for cementing an oilfield tubular into a wellbore formed in a subterranean formation , the method comprising:introducing a cement composition into an annulus formed between an inner surface of the wellbore and an outer surface of the oilfield tubular,wherein the cement composition comprises a reactive metal that is reactive with a wellbore fluid to form a metal hydroxide in-situ of the wellbore,wherein the reactive metal is selected from magnesium, a magnesium alloy, calcium, a calcium alloy, aluminum, an aluminum alloy, or a combination thereof.2. The method of claim 1 , wherein the reactive metal is present in the cement composition as solid particles.3. The method of claim 2 , wherein the solid particles have a particle size of greater than 0.003 inches (0.0076 cm).4. (canceled)5. The method of claim 1 , wherein at least a portion of the outer surface of the oilfield tubular further comprises a layer of the reactive metal or a layer of a composition comprising the reactive metal.6. The method of claim 5 , wherein the layer comprises a coating of the reactive metal or a sleeve of the reactive metal.7. A method comprising:providing a layer of a composition comprising a reactive metal to at least a portion of an outer surface of an oilfield tubular, wherein the reactive metal is reactive with a wellbore fluid to form a metal hydroxide in-situ of a wellbore,wherein the reactive metal is selected from magnesium, a magnesium alloy, calcium, a calcium alloy, aluminum, an aluminum alloy, or a combination thereof.8. (canceled)9. The method of claim 7 , wherein the layer is a coating of the ...

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Номер записи: 104
28-01-2016 дата публикации

Liquid Valve for Flow Control Devices

Номер: US20160024882A1
Автор: Jean-Marc Lopez, Liang Zhao, Luke William Holderman, Michael Linley Fripp
Принадлежит: Halliburton Energy Services Inc

Certain aspects of the present invention are directed to a liquid valve assembly that can be disposed in a wellbore through a fluid-producing formation. The liquid valve assembly can include a housing and a liquid valve. The housing can define an inner chamber and an opening adapted to allow fluid to flow between the inner chamber and a passageway. The liquid valve can be disposed in the inner chamber. The liquid valve can include a yield stress fluid. The yield stress fluid can prevent fluid from flowing between the inner chamber and the passageway.

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Номер записи: 105
28-01-2016 дата публикации

Liquid Valve for Flow Control Devices

Номер: US20160024883A1
Автор: Fripp Michael Linley, Holderman Luke William, Lopez Jean-Marc, Zhao Liang
Принадлежит:

Certain aspects of the present invention are directed to a liquid valve assembly that can be disposed in a wellbore through a fluid-producing formation. The liquid valve assembly can include a housing and a liquid valve. The housing can define an inner chamber and an opening adapted to allow fluid to flow between the inner chamber and a passageway. The liquid valve can be disposed in the inner chamber. The liquid valve can include a yield stress fluid. The yield stress fluid can prevent fluid from flowing between the inner chamber and the passageway. 1. A liquid valve assembly configured for being disposed in a wellbore through a fluid-producing formation , the liquid valve assembly comprising:a housing comprising a flexible material and defining an inner chamber and an opening adapted to allow fluid to flow between the inner chamber and a passageway;a liquid valve disposed in the inner chamber, the liquid valve comprising a yield stress fluid configured for preventing the fluid from flowing between the inner chamber and the passageway; andan actuation mechanism configured to selectively position the liquid valve by compressing the housing.2. The liquid valve assembly of claim 1 , wherein the yield stress fluid is further configured for remaining in the inner chamber in response to an application of a force to the yield stress fluid in a direction of the opening.3. The liquid valve assembly of claim 1 , wherein the actuation mechanism is further configured to selectively position the liquid valve over the opening such that the liquid valve prevents the fluid from flowing between the inner chamber and the passageway.4. The liquid valve assembly of claim 1 , wherein the yield stress fluid comprises a Bingham plastic.5. The liquid valve assembly of claim 1 , wherein the opening has a diameter adapted to cause the yield stress fluid to prevent the fluid from flowing between the inner chamber and the passageway in response to the fluid exerting a force against the liquid ...

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Номер записи: 106
28-01-2016 дата публикации

Well Screen Assembly with Extending Screen

Номер: US20160024897A1
Автор: Bonner Aaron James, Franklin Matthew, Fripp Michael, Greci Stephen Michael, Holderman Luke William, Kang James J., Lopez Jean Marc, Zhao Liang
Принадлежит:

A well screen assembly residing in a well bore has a base pipe and a filtration screen carried on the base pipe. The screen is radially extended with force from fluid while maintaining the base pipe radially unextended. 1. A method comprising:with a well screen assembly residing in a well bore, the well screen assembly comprising a base pipe and a filtration screen carried on the base pipe,radially extending the screen by force from fluid while maintaining the base pipe radially unextended.2. The method of claim 1 , where radially extending the screen with force from fluid pressure comprises supplying fluid into a bladder between the screen and the base pipe.3. The method of claim 2 , comprising claim 2 , after radially extending the screen claim 2 , degrading the bladder.4. The method of claim 2 , comprising maintaining the screen radially extended by plastically deforming the bladder.5. The method of claim 1 , where openings in the screen are sealed with a degradable material and radially extending the screen comprises supplying fluid into a space between the screen and base pipe.6. The method of claim 5 , comprising sealing openings in the screen by providing the degradable material into the screen while the screen is in the well bore.7. The method of claim 5 , comprising claim 5 , after radially extending the screen claim 5 , degrading the degradable material.8. The method of where radially extending the screen with force from fluid pressure comprises supplying fluid into a center bore of the base pipe.9. The method of claim 1 , where radially extending the screen comprises extending the screen into contact with a wall of the well bore.10. The method of claim 1 , where radially extending the screen comprises extending a screen from a corrugated state.11. The method of claim 1 , where radially extending the screen comprises inserting an injection tool into a center bore of the base pipe.12. The method of claim 1 , comprising maintaining the screen radially ...

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Номер записи: 107
26-01-2017 дата публикации

TIME-DELAY COATING FOR DISSOLVABLE WELLBORE ISOLATION DEVICES

Номер: US20170022778A1
Автор: FRIPP Michael L., Murphree Zachary R., WALTON Zachary W.
Принадлежит:

A method of removing a wellbore isolation device comprises: introducing the isolation device into the wellbore, wherein at least a portion of the wellbore isolation device comprises: a first material; and a coating, wherein the coating: completely surrounds at least the first material prior to introduction of the isolation device into the wellbore. The coating can be made from: a frangible substance that loses structural integrity after introduction of the isolation device into the wellbore via application of a force; a substance that undergoes a phase transformation at the phase transformation temperature of the substance after a period of time has elapsed since introduction of the isolation device into the wellbore; or at least an anode of a galvanic system comprising the anode, a cathode, and an electrolyte, wherein the anode undergoes galvanic dissolution after introduction of the isolation device into the wellbore. 1. A method of removing a wellbore isolation device comprising: (A) a first material; and', (i) completely surrounds at least the first material prior to introduction of the isolation device into the wellbore;', '(ii) is made from a frangible substance; and', '(iii) loses structural integrity after introduction of the isolation device into the wellbore via application of a force; and, '(B) a coating, wherein the coating], 'introducing the isolation device into the wellbore, wherein at least a portion of the wellbore isolation device comprisescausing or allowing at least the portion of the first material to dissolve or undergo a phase transformation in the wellbore.2. The method according to claim 1 , wherein the isolation device restricts or prevents fluid flow between a first wellbore interval and a second wellbore interval.3. The method according to claim 1 , wherein isolation device is a ball and a seat claim 1 , a plug claim 1 , a bridge plug claim 1 , a wiper plug claim 1 , a packer claim 1 , or a plug for a base pipe.4. The method according to ...

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Номер записи: 108
10-02-2022 дата публикации

PROPPANT FLOW BACK RESTRICTION SYSTEMS, METHODS TO REDUCE PROPPANT FLOW BACK, AND METHODS TO DEPLOY A SCREEN OVER A PORT

Номер: US20220042398A1
Автор: Fripp Michael Linley, Greci Stephen Michael, Ornelaz Richard Decena
Принадлежит:

Proppant flow back restriction systems, methods to reduce proppant flow back, and methods to deploy a screen over a port are disclosed. A proppant flow back restriction system includes a tubular extending through a wellbore and having a port disposed along the tubular. The system also includes a screen positioned along the tubular. The system further includes a cover disposed in an interior region of the tubular, where the cover is shiftable from a first position to a second position, and from the second position to a third position. The cover covers the port while the cover is in the first position, and uncovers the port while the cover is in the second position. The cover also engages the screen while shifting from the second position to the third position to shift the screen over the port. 1. A proppant flow back restriction system , comprising:a tubular extending through a wellbore and having a port disposed along the tubular;a screen positioned along the tubular, the screen being shiftable from a first screen position to a second screen position over the port; anda cover disposed in an interior region of the tubular, wherein the cover is shiftable from a first position to a second position, and from the second position to a third position,wherein the cover covers the port while the cover is in the first position, and uncovers the port while the cover is in the second position, andwherein the cover engages the screen while shifting from the second position to the third position to shift the screen from the first screen position to the second screen position.2. The proppant flow back restriction system of claim 1 , wherein after the cover shifts from the first position to the second position claim 1 , the cover shifts from the second position to the third position if less than a threshold amount of pressure is applied to the cover.3. The proppant flow back restriction system of claim 2 , wherein the cover comprises a spring that is compressed when the cover ...

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Номер записи: 109
10-02-2022 дата публикации

COMPLETION SYSTEMS, METHODS TO PRODUCE DIFFERENTIAL FLOW RATE THROUGH A PORT DURING DIFFERENT WELL OPERATIONS, AND METHODS TO REDUCE PROPPANT FLOW BACK

Номер: US20220042402A1
Автор: Fripp Michael Linley, Ornelaz Richard Decena
Принадлежит:

Completion systems, methods to produce differential flow rate through a port during different well operations, and methods to reduce proppant flow back are disclosed. A completion system includes a tubular extending through a wellbore and having a first port and a second port. The completion system also includes a cover disposed along an interior of the tubular and configured to cover the first port and the second port while the cover is in a first position and is configured to uncover the first port and the second port while the cover is in a second position. The completion system further includes a valve disposed along the tubular and configured to differentially restrict fluid flow through the first port during different well operations. 1. A downhole completion system , comprising:a tubular extending through a wellbore and having a first port and a second port;a cover disposed along an interior of the tubular and configured to cover the first port and the second port while the cover is in a first position and is configured to uncover the first port and the second port while the cover is in a second position; anda valve disposed along the tubular and configured to differentially restrict fluid flow through the first port during different well operations.2. The downhole completion system of claim 1 , further comprising a screen disposed along the second port and configured to filter particles greater than a threshold size from flowing through the second port.3. The downhole completion system of claim 2 , further comprising an inflow control device that is fluidly coupled to the screen and configured to filter a fluid before the fluid flows from the wellbore through the second port into the tubular.4. The downhole completion system of claim 2 , further comprising an autonomous inflow control device that is fluidly coupled to the screen and configured to filter a fluid before the fluid flows from the wellbore through the second port into the tubular.5. The downhole ...

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Номер записи: 110
24-04-2014 дата публикации

System and Method for Downhole Communication

Номер: US20140110106A1
Автор: Donald Kyle, Michael L. Fripp, Pete Dagenais
Принадлежит: Halliburton Energy Services Inc

A method of servicing a wellbore extending from a surface and penetrating a subterranean formation is provided. The method comprises placing an assembly in the wellbore, wherein the assembly comprises at least a first downhole tool, a signal receiver subassembly, and a conveyance between the first downhole tool and the surface. The method further comprises the signal receiver subassembly receiving a first signal generated by contact between the wellbore and the assembly and initiating a first function of the first downhole tool based on the first signal.

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Номер записи: 111
24-04-2014 дата публикации

WELLBORE ISOLATION DEVICE MADE FROM A POWDERED FUSIBLE ALLOY MATRIX

Номер: US20140110123A1
Автор: FRIPP Michael L., Murphree Zachary R., WALTON Zachary W.
Принадлежит: Halliburton Energy Services, Inc.

A method of producing at least a portion of a wellbore isolation device comprising: providing a fusible alloy matrix in a powdered form; placing at least the particles of the fusible alloy matrix powder into a mold; compacting the particles located inside the mold via an application of pressure; and fusing the particles together to form a solid material, wherein the solid material forms the at least a portion of the wellbore isolation device. 1. A method of producing at least a portion of a wellbore isolation device comprising:providing a fusible alloy matrix in a powdered form;placing at least the particles of the fusible alloy matrix powder into a mold;compacting the particles located inside the mold via an application of pressure; andfusing the particles together to form a solid material, wherein the solid material forms the at least a portion of the wellbore isolation device.2. The method according to claim 1 , wherein the isolation device is a ball claim 1 , a plug claim 1 , a bridge plug claim 1 , a wiper plug claim 1 , or a packer.3. The method according to claim 1 , wherein the metal of the fusible metal alloy is selected from the group consisting of lead claim 1 , tin claim 1 , bismuth claim 1 , indium claim 1 , cadmium claim 1 , silver claim 1 , gallium claim 1 , zinc claim 1 , antimony claim 1 , copper claim 1 , and combinations thereof.4. The method according to claim 1 , wherein the fusible alloy matrix undergoes a phase transformation at or near the bottomhole temperature of the wellbore after a desired amount of time.5. The method according to claim 1 , wherein the step of placing further comprises placing other particles into the mold along with the particles of the fusible alloy matrix powder.6. The method according to claim 5 , wherein the other particles are density-reducing particles claim 5 , strength-enhancing particles claim 5 , or a combination thereof.7. The method according to claim 5 , wherein the other particles are selected from the ...

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Номер записи: 112
24-04-2014 дата публикации

VARIABLE FLOW RESISTANCE FOR USE WITH A SUBTERRANEAN WELL

Номер: US20140110128A1
Автор: DYKSTRA Jason D., Felten Frederic, FRIPP Michael L., Zhao Liang
Принадлежит: Halliburton Energy Services, Inc.

A variable flow resistance system for use with a subterranean well can include a structure which displaces in response to a flow of a fluid composition, whereby a resistance to the flow of the fluid composition changes in response to a change in a ratio of desired to undesired fluid in the fluid composition. Another system can include a structure which rotates in response to flow of a fluid composition, and a fluid switch which deflects the fluid composition relative to at least two flow paths. A method of variably resisting flow in a subterranean well can include a structure displacing in response to a flow of a fluid composition, and a resistance to the flow of the fluid composition changing in response to a ratio of desired to undesired fluid in the fluid composition changing. Swellable materials and airfoils may be used in variable flow resistance systems. 1. A variable flow resistance system for use with a subterranean well , the system comprising:a structure which displaces in response to a flow of a fluid composition, whereby a resistance to the flow of the fluid composition changes in response to a change in a ratio of desired to undesired fluid in the fluid composition.2. The system of claim 1 , wherein the structure is exposed to the flow of the fluid composition in at least first and second directions claim 1 , and wherein the resistance to the flow changes in response to a change in a proportion of the fluid composition which flows in the first and second directions.3. The system of claim 1 , wherein the structure is more biased in a first direction by the flow of the fluid composition more in the first direction claim 1 , and wherein the structure is more biased in a second direction by the flow of the fluid composition more in the second direction.4. The system of claim 3 , wherein the first direction is opposite to the second direction.5. The system of claim 3 , wherein the first and second directions comprise at least one of the group including ...

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Номер записи: 113
29-01-2015 дата публикации

SELECTIVE ELECTRICAL ACTIVATION OF DOWNHOLE TOOLS

Номер: US20150027723A1
Автор: FRIPP Michael L., Kyle Donald G., Murphree Zachary R., WALTON Zachary W.
Принадлежит: Halliburton Energy Services, Inc.

A method of activating a tool can include displacing a device in the tool, the device transmitting energy to a receiver of the tool, thereby activating the tool, and the transmitting including a control circuitry increasing electrical current flow between an electrical power source and a transmitter in response to a sensor detecting a predetermined stimulus downhole. A system can include a tool including a receiver and an electrical load, and a device which displaces relative to the tool, the device including a transmitter, a sensor and an electrical power source. Another method can include displacing a device in a tubular string including multiple downhole tools, each including a receiver and an electrical load, and the device including a transmitter and a sensor. The transmitter transmits energy to at least one of the receivers in response to sensor detection of a predetermined number of the tools traversed by the device. 1. A method of activating a downhole tool in a subterranean well , the method comprising:displacing a device in the downhole tool, the device transmitting energy to a receiver of the downhole tool, thereby activating the downhole tool; andthe transmitting including a control circuitry of the device increasing electrical current flow between an electrical power source of the device and a transmitter of the device in response to a sensor of the device detecting a predetermined stimulus downhole.2. The method of claim 1 , wherein the power source is independent of any electrical source external to the device.3. The method of claim 1 , wherein the predetermined stimulus comprises a predetermined number of other downhole tools traversed by the device.4. The method of claim 3 , wherein each of the other downhole tools includes a respective receiver which can receive energy from the device transmitter.5. The method of claim 1 , wherein the transmitter transmits at least one of the group consisting of electromagnetic energy claim 1 , kinetic energy claim ...

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Номер записи: 114