downhole component and method of setting up a production sleeve assembly within a well

专利摘要:
WELL BOTTOM COMPONENT, PRODUCTION GLOVE ASSEMBLY FOR USE IN A WELL AND METHOD OF CONFIGURING A PRODUCTION GLOVE ASSEMBLY INSIDE A WELL. A production sleeve assembly for use in a well comprises tubular well equipment, multiple fluid pathways configured to provide fluid communication within the downhole component, multiple electronic actuators configured to selectively provide fluid communication through a or more fluid pathways and at least one sensor coupled to multiple electronic actuators. One or more of the various electronic actuators is configured to selectively trigger so as to allow or prevent fluid flow through the corresponding fluid path among the various fluid paths in response to at least one sensor that receives a suitable signal .
公开号:BR112015013258B1
申请号:R112015013258-8
申请日:2013-02-08
公开日:2021-05-11
发明作者:Jean Marc Lopez；Luke William Holderman；Michael L. Fripp
申请人:Halliburton Energy Services, Inc；
IPC主号:

专利说明:

Fundamentals
[0001] Wells are sometimes drilled into underground formations to produce one or more fluids from the underground formation. For example, a well can be used to produce one or more hydrocarbons. Where fluids are produced from a time interval of a formation penetrated by a hole, it is known that balancing fluid production over the interval can lead to a reduction in the taper of water and gas, and more controlled as the proportion increases and the total amount of oil or other desired liquid produced from the range. Various devices and completion assemblies have been used to help balance fluid production from a gap in the hole. For example, various flow devices have been used in conjunction with well screens in order to restrict the flow of fluid produced through the screens in order to balance production over a range. summary
[0002] In one embodiment, a production sleeve assembly for use in a well comprises tubular well equipment, a plurality of fluid passages configured to provide fluid communication within the downhole component, a plurality of electronic actuators configured to selectively providing fluid communication through one or more plurality of fluid passages and at least one sensor coupled to a plurality of electronic actuators. One or more of the plurality of electronic actuators are configured to selectively actuate and permit or prevent fluid flow through a corresponding fluid passage of the plurality of fluid passages in response to at least one sensor that receives a compatible signal.
[0003] In one embodiment, a production sleeve assembly for use in a well comprises tubular well equipment, a plurality of fluid passages configured to provide fluid communication between an external portion of the tubular well equipment and the interior of the tubular equipment shaft, a plurality of electronic actuators and at least one sensor coupled to the plurality of electronic actuators. At least one of the plurality of electronic actuators comprises disrupting devices positioned adjacent to actuable devices, the plurality of electronic actuators being configured to selectively provide fluid communication through one or more of the plurality of fluid passages. The rupture device is configured to actuate the actuable device so as to permit fluid flow through at least one fluid passage of the plurality of fluid passages in response to at least one sensor that receives a compatible signal.
[0004] In one embodiment, a method of configuring a production sleeve assembly in a well comprises receiving a signal in a sensor, determining that the signal is a compatible signal, receiving, by one or more electronic actuators of a plurality of electronic actuators, power from a power source, driving one or more of the electronic actuators in response to the determination that the signal is a compatible signal and selectively opening one or more fluid passages of the plurality of fluid passages in response to the activation of the electronic trigger.
[0005] These and other features will be more clearly understood from the following detailed description taken in conjunction with the accompanying drawings and claims. Brief description of the figures
[0006] For a more complete understanding of the present disclosure and the respective advantages, the following brief description is now referred, taken in connection with the accompanying drawings and detailed description:
[0007] FIG. 1 is a schematic illustration of a well operating environment according to an embodiment;
[0008] FIGS. 2A-2B are partial cross-sectional views of a well network assembly comprising an electronic actuator environment;
[0009] FIGS. 3A-3B are partial cross-sectional views of another well network assembly comprising an electronic actuator environment;
[0010] FIGS. 4A-4B are partial cross-sectional views of a further well network assembly comprising an electronic actuator environment;
[0011] FIG. 5 is a partial cross-sectional view of a further well-network assembly comprising an embodiment of an electronic actuator; and
[0012] FIGS. 6A-6B are partial cross-sectional views of a well-network assembly comprising an embodiment of an electronic actuator. Detailed description of the modalities
[0013] In the following drawings and description, like parts are typically marked throughout the specification and drawings with the same reference numerals, respectively. In addition, like reference numerals may refer to like components in different embodiments disclosed herein. The figures in the drawings are not necessarily to scale. Certain features of the invention may be shown exaggeratedly to scale or somewhat schematic and some details of conventional elements may not be shown for clarity and brevity. The present invention is capable of embodiments in different ways. Specific embodiments are described in detail and are shown in the drawings, with the understanding that the present disclosure is not intended to limit the invention to the embodiments illustrated and described herein. It should be fully recognized that the different teachings of the modalities discussed herein can be used separately or in any suitable combination to produce the desired results.
[0014] Unless otherwise specified, the use of the terms "connect", "envelop", "pair", "attach", or any other term describing an interaction between elements is not intended to limit the interaction to interaction direct interaction between the elements and may also include indirect interaction between the described elements. Unless otherwise specified, use of the terms "above", "upper", "upwards", "above the well", or other terms shall be interpreted as generally of formation towards the surface or towards the surface of a body of water; similarly, use of "downward", "bottom", "downward", "bottom of the well", or other terms shall be interpreted as generally forming far from the surface or far from the surface of a body of water, regardless of the hole orientation. Use of one or more of the above terms cannot be interpreted as denoting positions along a perfectly vertical axis. Unless otherwise specified, use of the term "underground formation" shall be understood to encompass both areas below ground and areas below exposed ground covered by water, such as the sea or fresh water.
[0015] Well systems can be used to provide a completion configuration, including one or more flow restrictions for the purpose of balancing production across a sector of a well. A flow restriction may form a part of a well screen assembly and thus provide a desired resistance to fluid flow between the screen assembly chamber and the interior of the tubular pole equipment. In order to provide flexibility in the selection of resistance for flow, multiple flow restrictions can be positioned parallel and/or in series across the fluid passage, such as a flow chamber and/or one or more ports with flow restrictions. The well screen assembly may further include a bypass port or a passage parallel to the flow restriction(s) so that the bypass opening can provide a relatively unrestricted flow passage between the outside of the assembly. of screen and well and the interior of the tubular well equipment. Such a well screen assembly may comprise a fluid passage in series with the flow restriction and the interior of the tubular well equipment and fluid may flow from the screen assembly into the tubular well equipment through the fluid passage.
[0016] During installation, a member or the locking means may be positioned close to the fluid passage in order to prevent fluid flow between the formation and the interior of the tubular well equipment. After installation, when fluid flow within the well tubular equipment is desired, a member or means of actuation may act on the blocking member to allow fluid to flow through the fluid passage. As operators increasingly seek more complicated completions in deep-sea wells, highly deviated wells and extended-reach wells, the use of traditional drive sources such as pressurized fluid has become more complicated. Disclosed herein is a downhole drive system operable to selectively supply fluid flow through a fluid passage that does not require drive through pressurized delivery fluid to breach a barrier. The downhole drive system can be used for complicated completions in deep-sea wells, in highly deviated wells and in extended reach wells. As disclosed herein, the downhole drive system comprises an assembly of electronic actuators comprising electronic means for selectively providing and/or preventing the flow of formation fluid into the tubular downhole equipment.
[0017] The set of electronic actuators can be incorporated into a production sleeve assembly for use in a well, which can control fluid communication between the outside of the tubular well equipment and the interior of the tubular well equipment. The production sleeve assembly may comprise a chamber in fluid communication with the outside of the tubular well equipment, a flow control device and a fluid passage providing fluid communication between the chamber and the interior of the tubular well equipment. The combined fluid communication passage between the outside of the tubular well equipment and the interior of the tubular well equipment can be referred to as the fluid passage. An electronic actuator can be provided to control fluid flow through the fluid passage. For example, the production sleeve assembly can be installed inside the well with the electronic actuator assembly in its non-triggered configuration. In this configuration, fluid can be substantially prevented from flowing through the fluid passage. Once the production sleeve is installed, the electronic actuator can be actuated in order to allow fluid flow through the fluid passage and thus provide fluid communication from the outside of the tubular well equipment to the interior of the tubular well equipment . In some embodiments, the electronic actuator can be reset to a third state and/or return to the initial configuration and thus avoid fluid communication between the outside of the tubular well equipment and the interior of the tubular well equipment. The ability to reset the electronic actuator can provide increased flexibility in selecting the flow state and/or resistance to flow through the production sleeve assembly.
[0018] In one embodiment, the electronic actuator assembly may comprise a locking member or means and a retracting member or means connected to an actuator, such as an electromechanical actuator (e.g., a motor, a solenoid, a pressure generator and a set of pistons, etc.) to move the blocking member between an un-triggered setting and a triggered setting. Actuation can occur by activating an electromechanical actuator to cause the retraction member to move and thus reposition the locking member out of the fluid passage. The electromechanical trigger can be connected to a power source and a sensor so that the electromechanical trigger becomes electrically activated in response to the sensor that senses a signal. Various retraction member configurations are possible. In some embodiments, the retraction member is a piston that displaces the locking member at least partially out of the fluid passage. In other embodiments, the retract member is an interlocking mechanism which translates the locking member at least partially out of the fluid passage, for example, to unclog the port or fluid passage. In another modality, the electronic trigger comprises an electronic explosion disk. For example, in a non-triggered position, a disk can be positioned close to the fluid passage to prevent fluid flow through it. After actuation, the rupturing device can create an opening (eg a hole) in the disc, thus allowing fluid to flow through the opening. The bursting device may be connected to a power source and a sensor so that the bursting device becomes electrically activated to generate the opening in the hazard in response to detection of a signal by the sensor. In another embodiment, the electronic actuator may comprise an electrically triggered thermal expansion. The resulting thermal expansion can result from an exothermic chemical reaction and can be used to translate a glove or other moving member. For example, a thermal reaction can be used to generate heat and a gas, thereby providing a pressurized fluid capable of causing a sleeve or piston to translate or shift.
[0019] Thus, the disclosed modalities allow the user to selectively control fluid flow through the fluid passageway directing signal transmissions to the sensor. Furthermore, some modalities comprise simple components that remain secure even when installed in deep, highly deviated wells. Various sensor configurations are possible. In some embodiments, the sensor is a fluid sensor that can detect at least one particular physical property of a fluid, such as fluid pressure, flow, composition, etc. In some embodiments, the sensor is a fluid pressure sensor, which can be programmed to activate the electronic trigger in response to detection of a predetermined pressure. In some embodiments, the fluid pressure sensor can be programmed to respond to a first predetermined pressure by activating the electronic actuator to move the locking member a first distance so that the locking member partially covers the passage of fluid and/or clear a first fluid port and respond to a second predetermined pressure by activating the electronic actuator to move the second locking member a distance such that the locking member is substantially removed from the fluid passage and/ or clears a second fluid port, thus providing a means to selectively size the flow passage. In some modalities, the sensor is configured to detect particular pressure fluctuation patterns and, in response, activate the electronic trigger, in effect.
[0020] In some embodiments, the sensor is an electrical sensor. For example, in some embodiments, the sensor is an electromagnetic rangefinder that can detect particular electrical telemetry signals and then respond by activating the electromechanical actuator. In some embodiments, the sensor is a wireless sensor and the signal comprises a wireless electromagnetic signal. In other embodiments, the sensor is electrically coupled to a signal source and the signal travels from the source to the sensor via an electrical coupling.
[0021] The set of electronic actuators can be incorporated into a series production sleeve with a flow restriction. Multiple electronic actuators can be incorporated into a production sleeve, thus allowing the user to selectively adjust the flow in the well tubular equipment through the production sleeve by driving a plurality of actuators. Thus, the electronic actuator assemblies disclosed here provide a selective adjustment of the fluid flow in the well, through the use of simple and reliable components.
[0022] Figure 1 is a schematic illustration of a well system, indicated generally by 10, including a plurality of autonomous inflow control devices embodying principles of the present invention. A well 12 extends through several layers of the earth. Well 12 has a substantially vertical sector 14, the upper portion of which has been fitted with a casing column 16. Well 12 also has a substantially horizontal sector 18 which extends along an underground formation 20 carrying hydrocarbons. As illustrated, the substantially horizontal sector 18 of the well is an open hole. When shown as an open hole, the horizontal sector of the well, the invention will work in either direction and in an open or enclosed hole.
[0023] Positioned within the well 12 and extending from the surface is a pipe string 22. The pipe string 22 provides a conduit for fluids to move from the upstream of the formation 20 to the surface. Positioned within the pipe string 22 at the various production intervals adjacent to the formation 20 are a plurality of autonomous flow control systems 25 and a plurality of production pipe sectors 24. At both ends of each production pipe sector 24 there is a plug 26 which provides a fluid seal between the pipe string 22 and the well wall 12. The space between each pair of adjacent plugs 26 defines a production gap.
[0024] Each of the production piping sectors 24 may optionally include a sand control capability. The sand control screen elements or filter media associated with the production piping sections 24 are designed to allow fluids to flow therethrough, but to prevent oversized particulate matter from flowing through them. In one embodiment, the filter medium is of the type known as "wound wire", as it is made of a wire nearly helically wound around the tubular well equipment, with a spacing between the wire rolls being chosen to allow for fluid flow through the filter media while preventing particles larger than a selected size from passing between the wire coils. It should be understood that the generic term "filter medium" as used herein is intended to include and encompass all types of similar structures that are commonly used in gravel fill well completions that allow fluid to flow through the filter or between the screen while limiting and/or preventing the flow of particles (eg, other commercially available screens, cracked or perforated coatings or pipes; synthesized metal screens; mesh screens, synthesized size; pipes with screen; pre-packaged screens and/or coatings; or combinations thereof). Furthermore, an outer protective skirt having a plurality of perforations therethrough can be positioned around the exterior of any such filter means.
[0025] Through the use of the flow control system 25 of the present invention at one or more production intervals, some control over the volume and composition of the fluids produced becomes possible. For example, in an oil production operation, an unwanted fluid component such as water, steam, carbon dioxide or natural gas is entering one of the production ranges, the flow control system in that range will restrict accordingly. autonomous, or will resist, the production of unwanted fluid from that interval. It will be appreciated that whether a liquid is desired or unwanted depends on the purpose of the production or injection operation being conducted. For example, when you want to produce oil from a well, without producing water or gas, then oil is a desired fluid and water and gas are unwanted fluids.
[0026] The fluid flowing in the production piping sector 24 typically comprises more than one fluid component. Typical components are natural gas, petroleum, water, steam or carbon dioxide. The proportion of these components in the liquid flowing in each production piping sector 24 will vary over time and based on the conditions of formation 20 and well 12. Similarly, the composition of the fluid flowing in the various piping sectors of the production across the entire production column can vary significantly from sector to sector. The flow control system is designed to reduce or restrict the production of unwanted liquids from any particular range. In effect, a larger proportion of the desired fluid component (eg oil) will be produced within the well.
[0027] Although Figure 1 represents a flow control system at each production interval, it should be understood that any number of systems of the present invention can be developed in a production interval without deviating from the principles of the present invention. Similarly, inventive flow control systems need not be associated with all production intervals. They can only be present at some of the well's production ranges or they can be inside the well to address multiple production ranges.
[0028] Referring next to FIGS. 2A and 2B, here is shown an ad production glove assembly comprising a chamber in fluid communication with the outside of the well tubular equipment (e.g. formation 20), a flow control device 100, a set of electronic actuators 110 and a fluid passage 101 providing fluid communication between the chamber and the interior of the tubular well rig 120 through the fluid passage 103. The production sleeve assembly may comprise an outer housing 102 disposed over a tubular well rig 105 , thus forming an annulus between the outer housing 102 and the tubular well equipment 105. The components of the production sleeve assembly can be disposed within the annulus and the fluid passage 101 can extend along the annulus at the same time. wherein it provides fluid communication between the outside of the production sleeve assembly and the inside of the tubular well equipment 120.
[0029] In one embodiment, the fluid flow control device 100 may be integrated with a set of electronic actuators 110 in accordance with the present invention. The production sleeve assembly may be suitably coupled with other fluid flow control devices, seal assemblies, downhole piping equipment and/or other downhole tools to form a pipe string as described above. The fluid flow control device 100 may comprise a sand control screen sector 106 and a flow restriction sector 107. The sand control screen sector 106 may comprise a media filter or a sand screen element. optional appropriate sand control such as a wire roller screen, a woven mesh screen and the like, designed to allow fluids to flow along them, but also to prevent excessively large particulate matter from flowing. It will be appreciated that any suitable filter element can be used with the production glove assembly described herein. In the illustrated embodiments, an outer protective skirt 108 having a plurality of perforations 109 can be positioned around the outside of the filter means and serve to protect the filter means, if present, from damage during transport of the production sleeve assembly. in the well. The flow restriction sector 107 can be fluidly coupled to the sand control screen sector through an access port 111.
[0030] The flow restriction sector 107 may comprise one or more flow restrictions 104 generally disposed within the fluid passage 101, and each of the flow restrictions 104 may be configured to provide a specific resistance to fluid flow through of the fluid restriction 104. The combined resistance to flow of a fluid through the production sleeve assembly can then be determined by the combined effect of one or more flow restriction openings to flow through the production sleeve assembly. Flow restriction 104 can be selected to provide resistance to balance production over a range. Various types of flow restrictions can be used with the flow control device described here. In the embodiment shown in FIG. 2, the flow restriction 104 comprises a nozzle comprising a central opening 118 (e.g., an orifice) configured to generate a resistance to a specific pressure drop in a fluid flow through the flow restriction 104. The central opening 118 it can have a variety of configurations, from a rounded cross-section to a cross-section where the first edge or the second edge comprises a sharply square edge. In general, the use of a square edge on the first edge and/or the second edge and/or a non-circular cross section can result in a greater pressure drop across the hole than with other shapes. Furthermore, the use of a square edge can result in a pressure drop across the flow restriction which depends on the viscosity of the fluid passing through the flow restriction. The use of a square edge can result in a greater pressure drop through flow restriction for an aqueous fluid than for a hydrocarbon fluid, thus presenting a greater resistance to the flow of any water being produced relative to any hydrocarbon (eg oil or gas) that is being produced. Thus, the use of a central opening comprising a square edge can advantageously resist the flow of water compared to the flow of hydrocarbons. In some embodiments described in this document, a plurality of nozzle-type flow restrictions may be used in series.
[0031] Each flow restriction 104 may also comprise one or more restriction tubes. Restriction tubes generally comprise tubular sectors with a plurality of internal restrictions (eg holes). The internal restrictions are configured to have a relatively greater resistance to flow through the restriction tube than the remaining portions of the interior of the restriction tube itself. Restriction tubes can generally have a cylindrical cross-section, although other cross-sectional shapes are possible. The restriction tubes can be positioned within the fluid passage with the fluid passing through the restriction tubes, and the restriction tubes can generally be aligned with the longitudinal axis of the well tubular equipment in the fluid passage. The plurality of internal constraints can then provide the specified resistance to flow.
[0032] Other suitable flow restrictions may also be used, including, but not limited to, narrow flow tubes, annular passages, bent tube flow restrictions, helical tubes, and the like. The narrow flow tubes can comprise any tube that has a length to diameter ratio greater than approximately 2.5 and provides the flow with the desired resistance. Similarly, annular passages comprise narrow flow passages that provide a resistance to flow due to frictional forces imposed by the surface of the fluid passage. A curved tube flow restriction comprises a tubular structure that forces the fluid to change direction when entering and flowing through the flow restriction. Similarly, a helical tube flow restriction comprises a fluid passage that forces the fluid to follow the helical flow passage as it flows through the flow restriction. Repeatedly changing fluid performance through flow restrictions with bent tube and/or helical tube increases flow resistance and may allow the use of a larger flow passage that may not be clogged as easily as flow passages narrow flow tubes and/or annular passages. Each of these different types of flow restriction can be used to provide a desired resistance to flow and/or to the pressure drop of a fluid flow through the flow restriction. Since the flow resistance can change based on the type of fluid, the type of flow restriction can be selected to provide the desired flow resistance for one or more types of liquid.
[0033] As illustrated in Figures 2A and 2B, the set of electronic actuators 110 can be positioned close to the fluid passage 101, so that, in a non-actuated position, the locking member 113 can, at least partially, prevent the fluid flow between the flow control device 100 and the interior of the tubular well apparatus 120. In the specific embodiment illustrated in FIGS. 2A and 2B, the locking member 113 comprises a connector; however, those skilled in the art will appreciate that the locking member can comprise any type of member configured to restrict or prevent fluid flow through the flow passage, including, but not limited to, meshes, connectors, valves, pistons, sliding sleeves and the like. In one embodiment, the locking member may only partially close the fluid passage and there may be holes in the locking member. The locking member 113 can be coupled to an electromechanical actuator 114 via a retraction member 115. In the specific embodiment illustrated in FIG. 2, the retraction member 115 comprises a rod; however, those skilled in the art will identify that the retracting member may comprise any type of member configured to couple or connect the locking member to the electromechanical actuator, including a connecting member, a screw gear, a translation rod, a rotating rod or the like. Electromechanical actuator 114, via retraction member 115, can move locking member 113 to alter the flow through fluid passages 103. For example, electromechanical actuator 114 can move retraction member 115 to displace the member lock 113 from a first position (shown in FIG. 2A), which prevents fluid flow through the fluid passage 103, to a second position (shown in FIG. 2B), which allows fluid flow through fluid passage 103. In some embodiments, locking member 113 may block a plurality of ports, each capable of providing a different flow passage through the fluid passage. For example, electromechanical actuator 114 can move retraction member 115 to displace locking member 113 so as not to block a first port, allowing fluid flow through a first flow passage. Electromechanical actuator 114 may further be configured to move retraction member 115 to move locking member 113 into a second position, which allows fluid flow through a second port, alone or in combination with the first port. In the specific embodiment illustrated in FIGS. 2A and 2B, electromechanical actuator 114 is coupled to a solenoid (not shown) and can cause retraction member 115 to move linearly in order to reposition locking member 113. However, electromechanical actuator 114 can also do so. causing the retraction member 115 to move in a non-linear manner. For example, in cases where the retracting member comprises a screw gear and the locking member comprises a connector, the electromechanical actuator can cause the screw gear to rotate in order to translate the connector.
[0034] As illustrated in Figures 2A and 2B, a power source 116 can be coupled to the electronic driver 110 to provide the power to drive the electronic driver. In one embodiment, the power source 116 can comprise a battery, can be coupled to a power generating device, can be coupled to a power source within the well, can be coupled to a power source outside the well, or any combination of these. A current source (such as a capacitor) (not shown) could be used in conjunction with one or more batteries in the power supply. In one embodiment, the power source 116 may comprise an electrical coupling with the well surface, where power is supplied from an energy source at the well surface. In this embodiment, the casing and/or the tubular shaft of the well can form a portion of an electrical passage for the production sleeve assembly. In one embodiment, the power source and/or the power generating device may be sufficient to turn on the electronic driver, sensor or combinations thereof. The power source can be coupled to a single electronic actuator and/or a sensor, which can result in a plurality of power sources being coupled to a plurality of electronic actuators. In one embodiment, power source 116 can be coupled to a plurality of electronic drivers, and in some embodiments, a single power source can be coupled to all electronic drivers in a set of production sleeves and/or in the well. The power source and/or power generating device may provide power in the range of approximately 0.001 watts to approximately 10 watts, alternatively approximately 0.5 watts to approximately 1.0 watts. In some embodiments, the power source and/or power generating device may provide power in the range of approximately 0.001 watts to approximately 1.0 watt or approximately 0.002 watts to approximately 0.5 watts.
[0035] The set of electronic actuators may comprise a sensor 117. In the embodiment of FIG. 2, sensor 117 comprises a fluid pressure sensor. Pressure sensor 117 can be located close to the tubular well rig and an opening 118 can be positioned within the wall of the tubular well rig to provide a differential pressure across the pressure sensor 117. pressure 117 can be configured to activate electronic actuator 110 upon detection of a predetermined value of fluid pressure. In some embodiments, pressurized fluid is collected above the well and delivered through tubular well equipment. In some modalities, pressurized fluid is collected inside the well. For example, fluid pulse telemetry can be performed, where at least one fluid reserve (e.g., a produced fluid such as water, oil and/or gas) (not shown) is situated at the bottom of the well and its Fluid inlet into the tubular well equipment is controlled through a valve. Digital commands can be transmitted to the valve to determine the opening and closing of the valve. With the opening and closing of the valve, the fluid inside the tubular well equipment can have pressure fluctuations representing pressure signals, which are then detected by the pressure sensor.
[0036] The pressure sensor 117 can be configured to detect a pressure value that is less than the pressure value required to rupture an explosion disk that may be present in the well. In other words, the use of pressure variations can make it possible to use relatively small pressure fluctuations within the well. Thus, the disclosed pressure sensor offers superior operability in complicated completions involving deep-sea wells, highly deviated wells and extended-range wells, where the ability to create differential pressure may be limited. Pressure sensor 117 can be configured to detect a value (eg a pressure value) transmitted as an analog and/or digital transmission.
[0037] Various types of sensors besides fluid pressure sensors can also be used. For example, the sensor may comprise a fluid composition sensor which triggers an electronic trigger in response to detection of a particular fluid composition. The fluid composition sensor can trigger the electronic actuator to move the locking member 113 to a first position in response to detecting a first fluid composition and to move the locking member 113 to a second position in response to detecting a second fluid composition. Alternatively, the fluid sensor comprises a fluid flow sensor. The fluid flow sensor can be configured to activate the electronic trigger to reposition the locking member 113 in response to detection of fluid flow through the sensor.
[0038] Furthermore, the sensor need not be a fluid sensor and other types of signal detectors can be used to maintain compliance with the principles of this disclosure. For example, the sensor can be a voltage sensor, a hydrophone, an antenna, or any other type of signal detector that is capable of receiving a signal. It should be noted that the sensor can be replaced by other types of sensors and the retraction member can be operated in response, for example, to the detection of a certain type of physical property (eg pressure, temperature, resistivity, ratio of oil/gas, cutting off water, radioactivity, etc.) after a certain period of time, etc.
[0039] In other embodiments, the sensor comprises an electrical sensor. The electrical sensor can comprise a wired or wireless sensor, and can detect analog or digital transmissions. In cases involving a wireless sensor, the electrical signal can be an electromagnetic signal. The electromagnetic signal can be delivered from a source above the well or from a source within the well, for example, from a connector positioned inside the well. In some embodiments, the well may comprise repeaters in order to facilitate wireless signal transmission.
[0040] The electronic trigger 110 may comprise a receiving circuit comprising a microprocessor, a memory or the like to respond to the presence of an appropriate signal from a sensor, to analyze and interpret the signal and to trigger the electronic trigger 110 in response to the determination that the electronic actuator 110 should be operated. For example, the receiving circuit can be configured to amplify the electrical signal from the receiving antenna, to determine if the signal is an appropriate signal according to one or more normals, to trigger the electronic trigger based on the determination that the signal is an appropriate sign and/or any combination thereof, as would be noticed by one skilled in the art when viewing this disclosure. In this mode, the receiving circuit can be in signal communication with the receiving antenna. In one embodiment, the receiving circuit can receive an electrical signal from a receiving antenna and generate an output response (eg, an electrical current or an electrical voltage). In one embodiment, the receiving circuit may comprise any suitable configuration, for example comprising one or more printed circuit boards, one or more integrated circuits (eg an ASIC), one or more discrete circuits, one or more devices, one or more passive device components (for example, a resistor, an inductor, a capacitor), one or more microprocessors, or one more microcontrollers, one or more wires, one or more electromechanical interfaces, one or more power sources and/ or any combinations thereof. For example, the receiving circuit may comprise a resistor-inductor-capacitor circuit and may configure the receiving antenna to resonate and/or respond at a predetermined frequency. As noted above, the receiving circuit may comprise a single, unitary or non-distributed component capable of performing the function disclosed herein; alternatively, the receiving circuit may comprise a plurality of distributed components capable of performing the functions disclosed herein.
[0041] Various modalities can provide various flow configurations in order to provide a selectable resistance to flow through the production sleeve assembly. Referring to FIGS. 3A and 3B, there is shown here a production sleeve assembly comprising a fluid flow control device 200 comprising a plurality of electronic actuator assemblies 204, 205, 206 associated with a plurality of fluid passages 201, 202, 203 and each fluid passageway 201, 202, 203 may provide fluid communication between the fluid flow control device 200 and the interior of the tubular well equipment 120. Each set of electronic actuators 204, 205, 206 may be associated with by minus one sensor 210, 211, 212. In the embodiment depicted in FIGS. 3A and 3B, the first set of electronic actuators 204 comprises a first locking member 213, a first retracting member 215, a first electromechanical actuator 214, a first power source 216 and a first sensor 210; the second electronic actuator assembly 205 comprises a second locking member 217, a second retracting member 219, a second electromechanical actuator 218, a second power source 220 and a second sensor 211; and the third set of electronic actuators 206 comprises a third locking member 221, a third retracting member 223, a third electromechanical actuator 222, a third power source 224, and a third sensor 212. In the embodiment of FIGS. 3A and 3B, sensors 210-212 may comprise fluid pressure sensors to detect pressure fluctuations and the signal may comprise a pulse of fluid pressure. First sensor 210 may be configured to activate a first electromechanical actuator 214 in response to a first signal to thereby allow fluid flow through a fluid flow passage, second sensor 211 may be configured to activate a second electronic trigger 205 in response to a second signal and thus allow fluid flow through a second fluid passage, and the third sensor 212 may be configured to activate a third electronic trigger 206 in response to a third signal and thereby permit the flow of fluid through a third fluid passage. When illustrated as locking members adjacent to fluid passages, it should be understood that the locking members can be configured to respond to differential pressure across the locking members (eg having a differential area to act as a piston) and/or mechanical biasing force (eg a spring force). Pressure or differential force can serve to bias the lock members and overcome any frictional forces present between the lock member actuations.
[0042] In one embodiment, a plurality of electronic triggers 204, 205, 206 can be configured to trigger based on a single signal. For example, the second and third sensors 211, 212 can be configured to activate the second and third electronic actuator 205, 206 in response to a fourth signal and thus allow fluid flow through the second and third passages of fluid 202, 203. The second fluid passage 202 may comprise greater resistance to fluid flow than the third fluid passage due to, for example, a more restrictive flow restriction 208, 209. Actuation of the plurality of electronic actuators 204, 205, 206 can be temporarily separated, for example, executing it sequentially over a period of time rather than simultaneously in response to a single signal. In some embodiments, one or more of the plurality of electronic triggers 204, 205, 206 may be configured to have a plurality of trigger conditions based on different signals. For example, one signal can drive one or more of the plurality of electronic drivers 204, 205, 206 and a separate signal can drive a different plurality of the plurality of electronic drivers 204, 205, 206.
[0043] In operation, the well tubular string comprising one or more of the production sleeve assemblies may be positioned in the well with one or more of the closed fluid passages 201-203. In one embodiment, all fluid passages can be closed off to allow various completions and/or installation procedures to be performed without clogging the fluid passages. For example, a gravel packing procedure can be performed to pack the annulus between the well wall and the tubular well equipment and/or production sleeve assembly with gravel. Various completion procedures such as hydraulic fracturing operations, acid treatments and the like can be performed in order to prepare the formation for production.
[0044] Once the tubular well string has been installed and fitted to the well, the production sleeve assembly can be reconfigured to a desired state. In some modalities, production sleeve assembly reconfiguration can be used from testing and/or conditions within the well. In order to reconfigure the production glove assembly, a first signal can be generated and transmitted to a first sensor. Upon detection by the first sensor of a first signal, the first electronic actuator 204 can be actuated in order to cause a first locking member 213 to translate from a first position (shown in Figure 3A) to a second position ( shown in figure 3B). As can be seen in FIG. 3B, the second position may comprise a retracted position which may permit fluid flow through the first fluid passageway 201 and provides fluid communication between the outside of the tubular well rig and the interior of the tubular well rig 120. In one embodiment, the first fluid passage 201 can provide a relatively unrestricted fluid passage.
[0045] When the production glove set must be additionally configured, a second signal can be generated and transmitted to a second sensor 211. From the detection of the second signal by the second sensor 211, a second set of electronic actuators 205 can be actuated to open fluid communication through a second fluid passage 202. Any subsequent fluid passage, such as a third fluid passage 203, can remain substantially blocked. The second fluid passage 202 may provide a restricted fluid passage with a flow restriction 208 established within the fluid passage. Alternatively or additionally, a fluid passage having a lower resistance to fluid flow than the second fluid passage, but having a greater resistance to fluid flow than the first fluid passage may be provided by generating a third signal. and transmitting the third signal to a third sensor 212. Upon detection of the third signal by the third sensor 212, a second set of electronic actuators 206 can be actuated to open fluid communication through a second fluid passageway 203. When the third signal is created before the second signal, or without it, the second fluid passage 202 may remain closed to fluid communication. Then, a general fluid passage can be provided through the first fluid passage 201 and the third fluid passage 203, and the resistance to flow through the fluid passage they generate can be based on the combination of the individual resistances provided by the first fluid passage. 201 and third fluid passage 203. Since first fluid passage 201 is relatively unrestricted with respect to second fluid passage 202 and third fluid passage 203, most of any flow may pass through the first. fluid passage 201.
[0046] In yet another modality, a fourth signal can be generated and transmitted to the production glove set. The second sensor 211 and the third sensor 212 can be configured to respond to the fourth signal and to drive the second electronic driver 205 and the third electronic driver 206, thereby opening the second fluid passage 202 and the third fluid passage 203. A general fluid passage can then be provided through the second fluid passage 202 and the third fluid passage 203, and the resistance to flow through the general fluid passage can be based on the combination of the individual resistances provided in the second fluid passage 202 and in the third fluid passage 203.
[0047] As would be noted to anyone skilled in the art, with the contribution of this publication, the production sleeve assembly can comprise various fluid flow control devices, flow restrictions and electronic actuator assemblies. Furthermore, the trigger need not involve fluid pressure pulses. For example, the signal may comprise a delivery of pressurized liquid from the top of the well. In such circumstances, the first sensor may be configured to trigger the first electronic trigger in response to a first pressure value, the second sensor may be configured to trigger the second electronic trigger in response to a second pressure value, and the third sensor can be configured to trigger the third electronic trigger in response to a second pressure value. Alternatively, the signal may comprise a type of signal other than pressure pulse telemetry (eg, acoustic tubular column, manipulation, electromagnetic signal, etc.). Furthermore, both the second and third sensors can be configured to trigger the second and third electronic trigger in response to a fourth signal. Similarly, all sensors can be configured to trigger corresponding electronic triggers in response to a fifth signal, thus opening all fluid passages through the production sleeve assembly at once.
[0048] In some embodiments, the sets of electronic actuators may comprise electrical sensors, for example: electromagnetic signal sensors. In such circumstances, the first sensor may be configured to trigger the first electronic trigger in response to a first pressure value, a second sensor may be configured to trigger the second electronic trigger in response to a second electromagnetic signal, and the third sensor may be configured to trigger the third electronic trigger in response to a third electromagnetic signal. Furthermore, both the second and third sensors can be configured to trigger the second and third electronic triggers in response to a fourth telemetry signal, and the first, second and third sensors can be configured to trigger the first, second and the third electronic trigger in response to a fifth signal.
[0049] Over the life of the well, it may be desirable to increase or decrease the flow rate associated with the fluid flow passage. In such circumstances, the user can, during production, selectively tailor the flow rate by changing the fluid passages that are unblocked. For example, in one modality, in addition to responding to any of the signals described above, the second sensor can be configured to respond to a sixth signal as well. In response to the sixth signal, the second sensor may trigger the second electronic actuator to extend the second retraction member so that the second locking means at least partially prevents fluid flow between the second fluid passage. The third sensor can be configured to detect a seventh signal and, in response to this, trigger the third electronic actuator to extend the third retraction member so that the third locking member at least partially prevents fluid communication through the third fluid passage. In addition, the second sensor and third sensor can be configured to detect an eighth signal. In response to the detection of the eighth signal, the second and third electronic actuator may actuate the second and third retraction member to extend the second and third locking member and prevent fluid flow through the second and third fluid passages. . Furthermore, the first sensor may be configured to detect a ninth signal in addition to the first signal and, in response, move the locking member so that fluid flow through the first fluid passage is substantially avoided. The ninth signal can be distinguished from signals two through eight, so that the first blocking member is controlled independently of the other blocking members; or the ninth sign can be the same as any of signs two through eight. For example, the ninth sign can be the same as the eighth sign. Thus, the user can substantially avoid fluid communication through the tubular equipment portion of the well by transmitting the ninth signal.
[0050] One reasonably skilled in the art will appreciate that the system can comprise any number of sets of electronic actuators and is not limited to a second or a third set. Furthermore, each sensor can be configured to detect any number of signals and thus multiple groupings of sets of triggers in a system can be triggered together. For example, the system may comprise a first set of electronic actuators comprising a first sensor for detecting a first signal to thereby open a first fluid passage. After opening the first fluid passage, additional signals can be transmitted in order to reconfigure the production sleeve assembly. For example, the second signal may open a second fluid passage and a third fluid passage; a third signal can open a fourth fluid passage, a fifth fluid passage and a sixth fluid passage; a fourth signal can open the second, third, fourth and fifth fluid passages; a fifth signal can open the first, second and third fluid passages; a sixth signal can open the first, third, fourth, and fifth fluid passages, etc. Consequently, the system provides a variety of fluid flow passage options and allows a user to specifically tailor the flow passage according to well conditions.
[0051] Referring next to FIGS. 4A and 4B, there is shown an electronic actuator assembly 301 comprising a locking member 313, a retract member 315, an electromechanical actuator 314, a power source 316, and a sensor 317. The retract member 315 may move locking member 313 to various actuated positions. As in the other modalities described in this document, the set of electronic actuators 301 can be installed in the well in its non-triggered configuration. In this configuration, the locking member 313 can be in its non-actuated position, where fluid flow through the fluid passage can be substantially avoided. Thereafter, the locking member 313 can be repositioned to several actuated positions, each allowing different levels of fluid flow through the fluid passageway 303. A sensor 317 can detect one or more signals and actuate the electronic actuator 301 to reposition the locking member 313 to a particular actuated position, based on the type of signal the sensor detects.
[0052] In the specific embodiment illustrated in FIG. 4A and 4B, sensor 317 is an electrical sensor that detects various electromagnetic signals. However, those skilled in the art will appreciate that the sensor need not be an electromagnetic sensor and that it could be any type of sensor, including a fluid pressure sensor, a fluid flow sensor, or a fluid composition sensor. Furthermore, the blocking member 313 is illustrated as a blocking fluid pathway 303, but it should be understood that the blocking member 313 could also be configured to block the flow restrictor 112 alone or in combination with one or more parts of the fluid pathway 303. Any combination of fluid pathways may be blocked and/or selectively uncovered in accordance with the modalities disclosed herein.
[0053] In operation, a user can transmit a first electromagnetic signal and, upon detection of the first signal by the sensor 317, the electronic actuator 301 can trigger and cause the retract member 315 to move the locking member 313 only slightly to a first actuated position in which the locking member 313 unlocks a first port to provide fluid communication along the first fluid path 304. The first fluid path 304 may comprise a first fluid restriction 307 and thus provide a flow of restricted fluid through the first fluid path 304. A second signal can then be transmitted and, upon detection of the second signal by the sensor 317, the electronic driver 301 can drive and cause the retraction member 315 to move the member. lock 313 to a second actuated position. FIG. 4B illustrates an embodiment of a mounting of the electronic actuator 301 in a second actuated position. As shown in FIG. 4B, in the second actuated position, the locking member 313 may unlock a second port to provide fluid communication along the second fluid path 305. The second fluid path 305 may comprise a flow restriction 308 which is a fluid flow minus restrictive than the associated first flow restriction 307 of the first fluid path 304, thus reducing the total resistance to flow through the production sleeve assembly. A third signal may be transmitted and, upon detection of the third signal by sensor 317, electronic actuator 301 may actuate and cause retract member 315 to move locking member 313 to a third actuated position. In the third actuated position, the locking member 313 can unlock a third port to provide fluid communication along the third fluid pathway 306, as well as the first and second fluid pathways 304, 305. The third fluid pathway 306 can comprise a flow restriction 309 which is less restrictive than the first flow restriction 307 or the second flow restriction 308, thus reducing the total resistance to flow through the production sleeve assembly.
[0054] In order to increase the resistance of the flow through the flow control device 300 and/or to decrease the flow rate through the fluid path 303, a fourth signal can be transmitted to trigger the electronic actuator 301. After upon detection of the fourth signal by sensor 317, electronic actuator 301 can trigger and cause retract member 315 to move locking member 313 back to the second actuated position (as indicated in FIG. 4B), thereby closing the third fluid pathway 306. In one embodiment, the fourth signal can be the same as the second signal, so the selection of the first, second, or third signal indicates the relative actuated position (eg, first actuated position, second position actuated or the third actuated position, respectively) that the electronic actuator 301 can cause the locking member 313 to assume. For example, transmission of the first signal and reception of the first signal by sensor 317 can cause electronic actuator 301 to actuate locking member 313 to the first actuated position. Thus, during production, the user can selectively adapt the flow rate by changing the specific way in which various fluid pathways 304, 305 and 306 are blocked or unblocked.
[0055] It will be immediately evident to those skilled in the art that the electronic actuator assembly 301 can comprise virtually any number of actuated positions and that the sensor 317 can detect virtually any number of corresponding signals. Thus, actuator 301 can be designed to increase fluid flow through the pathway by virtually any number of incremental amounts between a fully closed position and a fully open position.
[0056] Referring next to FIG. 5, there is depicted an embodiment wherein a fluid control device 400 comprises a plurality of fluid pathways 401-403 and an electronic actuator assembly 406-408 associated with each fluid pathway 401-403. One or more fluid pathways 401-403 may also be associated with flow restriction 411-413 to provide special resistance. For example, the first electronic actuator assembly 406 may be associated with the first fluid path 401 and a first flow restriction 411, which may provide a first resistance to fluid flow, a second electronic actuator assembly 407 may be associated with a second fluid path 402 and a second flow restriction 412, which may provide a second resistance to fluid flow and a third electronic actuator assembly 408 may be associated with a third fluid path 403 and a third restriction flow 413, which can provide a third resistance to fluid flow. The electronic actuator assemblies 406-408 may be communicatively coupled to at least one sensor 410. At least one sensor 410 may be configured to detect any types of signals, e.g., a fluid pressure signal (e.g., a signal from the fluid pulse, a sonic signal, etc.) or an electromagnetic signal and the sensor can be configured to detect a multitude of signals. Each set of trigger 406-408 may comprise its own sensor, or (as shown in FIG. 5) each set of trigger 406-408 may be in communication with a sensor 410. Alternatively, the system may comprise a plurality of sensors and each sensor may be in communication with more than one trigger assembly.
[0057] In the specific embodiment depicted in FIG. 5, a sensor 410 is communicatively coupled to all three assemblies of electronic actuator 406-408. Sensor 410 may comprise receiving a circuit described herein that is capable of detecting a plurality of signals. For example, a first signal may correspond to the retraction of the first set of electronic actuator 406; a second signal may correspond to the length of the first set of electronic actuator 406; a third signal may correspond to the retraction of the second electronics assembly 407; a fourth signal may correspond to the length of the second set of electronic actuator 407; a fifth signal may correspond to the retraction of the third set of electronic actuator 408; a sixth signal may correspond to the extent of the third set of electronic trigger 408. The multiplicity of signals may also include signals associated with a plurality of sets of electronic trigger 406-408. For example, a seventh signal may correspond to the retraction of the first set of electronic actuator 406 during the extension of the second set of electronic actuator 407; an eighth signal may correspond to the retraction of the first and second sets of electronic actuator 406, 407 during extension of the third set of electronic actuator 408; a ninth signal may correspond to the retraction of the first and third sets of electronic actuator 406, 408 during extension of the second set of electronic actuator 407; and so on for each subset of the 406-408 electronic actuator assemblies. In addition, electronic actuator assemblies 406-408 may be configured similarly to that described with respect to the embodiment of FIGS. 4A and 4B. For example, in response to a given signal, the retracting member 414, 416, 418 may move the locking member 415, 417, 419 to one of several positions so that the locking member 415, 417, 419 partially locks the fluid pathway 401-403 substantially blocks fluid pathway 401-403 or substantially opens fluid pathway 401-403. Alternatively, in response to a specific signal, the retracting member 414, 416, 418 may move the locking member 415, 417, 419 to one of several positions such that the locking member 415, 417, 419 locks or opens one or more ports for providing fluid communication along one or more corresponding fluid pathways 401-403. Thus, any combination of fluid pathways can be selectively open and/or closed so that each configuration produces a distinct overall flow path. Therefore, the disclosed system allows the user to selectively adjust the flow path.
[0058] Referring to FIGS. 6A-6B, one embodiment of a fluid flow device comprising another embodiment of an electronic actuator assembly 501 is illustrated schematically. Fluid flow control device 500 may comprise a sensor 510 and an electronic actuator 501 and may be appropriately coupled to other similar fluid flow control devices, seal assemblies, production piping equipment and/or other manufacturing tools. downhole in order to form a pipe string described above. In one embodiment, electronic actuator 501 comprises an electronic rupture device 517 and an actuable device 511. The actuable device 511 may comprise any device configured to provide fluid communication in response to being punctured by the rupture device, such as a disc. rupture, a membrane, a shear pin and the like.
[0059] FIGS. 6A and 6B illustrate a piston 513 slidably and sealably disposed within the fluid path that initially blocks fluid communication along the fluid path 514 through the fluid port. Piston 513 may be inclined toward actuable device 511 by pressure acting on an area of differential piston. Alternatively, a biasing device such as a spring may engage and act on the piston to bias the piston towards the actuable device 511. Initially, displacement of the piston 513 towards the actuable device 511 is substantially impeded by a fluid 515 disposed within of a fluid chamber 516 formed between the actuable device 511 and the piston 513. The fluid 515 may be a substantially incompressible fluid such as hydraulic fluid but could alternatively be a compressible fluid such as nitrogen, a combination of substantially incompressible fluids, a combination of compressible fluids or a combination of one or more compressible fluids with one or more substantially incompressible fluids. While fluid 515 prevents piston 513 from moving sufficiently to open communication through fluid path 514, piston 513 is able to float as pressure differences between the pressure in fluid path 101 and fluid chamber 516 are balanced.
[0060] The actuable member 511 may initially prevent and/or restrict fluid from escaping from the chamber 516. As shown in FIGS. 6A and 6B, the actuable member 511 is depicted as a disk member and may be formed of a metal but alternatively could be made of plastic, composite, glass, ceramic, a mixture of these materials, or other material suitable for containing initially fluid 515 in chamber 516 while being configured to fail in response to being ruptured by the rupturing device.
[0061] The disruption device 517 may comprise any device configured to trigger the triggerable device and create fluid communication. In one embodiment, the rupture device may comprise a chemical jet nozzle assembly. The chemical jet nozzle assembly may include a chemical element or energetic material, an ignition agent and a nozzle. The chemical element can be formed from any suitable component configured to generate an exothermic chemical reaction, for example a thermite reaction. The ignition agent may be connected to the receiving circuit through an electrical coupling so that, when it is determined that the electronic actuator is to be operated, the receiving circuit can supply electrical current to an ignition agent.
[0062] Once the ignition agent is started, the chemical element can be started, and the nozzle can focus the heat and molten materials created in the exothermic reaction into a hot jet that is directed to the actionable device. The hot jet causes a hot spot focused on the actionable device resulting in the desired actuation of the actionable device. It is noted that the mode of actuation of the actionable device may include penetration, melting, combustion, ignition, weakening or other degradation of the barrier. Fluid communication is thus established between a chamber and a low pressure chamber adjacent to the rupturing device 517 through the opening formed in the actuable device. The opening may allow fluid 515 to exit the chamber as the piston is urged towards the actuable device 511 now disrupted by the pressure of the fluid path acting in the area of the differential piston. Alternatively, a biasing device can drive piston 513 toward rupture device 517. The configuration of the electronic drive can then be seen in FIG. 6B. When the piston translates past the port, fluid communication may be allowed along the fluid path through the port.
[0063] Several other designs are also possible for the 501 electronic actuator comprising a 517 break and a 511 actuable device. Suitable electronic actuators may include any described in U.S. Patent Publication No. 2010/0175867 to Wright, et al. titled “Well Tools Incorporating Valves Operable by Low Electrical Power Input,” U.S. Patent Publication No. 2011/0174504 to Wright, et. al. entitled "Well Tools Operable Via Thermal Expansion Resulting from Reactive Materials," and US Patent Publication No. 2011/0265987 to Wright, et al. entitled "Downhole Actuator Apparatus Having a Chemically Activated Trigger", each of which is incorporated herein instrument by reference in full.
[0064] The sensor 510 may comprise any sensors and/or sensor types described herein. In one embodiment, the sensor comprises several electrical sensors. The electrical sensor can be coupled to a wireless power source such as a battery. In addition, or as an alternative to the wireless power source, the electrical sensor can be wired to a power source such as a generator and/or a power source at the well surface.
[0065] The electrical sensor 510 may be configured to detect an electromagnetic signal wirelessly and/or may be configured to detect an electromagnetic signal from a signal source through an electrical line. The electromagnetic signal source can be located at the top or the bottom of the well. In some embodiments (including the embodiment shown in FIG. 6) electrical sensor 510 may receive an electrical signal through electrical line 518 which couples electrical sensor 510 to a wireless connection (not shown) and the wireless connection may receive signals wireless from one of the top of the source well. The wireless link can be connected to multiple electrical sensors via one or more electrical lines 518, thus allowing a user to control multiple electronic actuator assemblies by communicating with a single wireless link. In some embodiments, the electrical sensor 510 is wired to the power source and the signal source. In these cases, the sensor connection to the power source can use the same electrical line or a different line as a connection from the sensor to the signal source. In the specific embodiment shown in FIG. 6, sensors 510 are electrically coupled to the power source and to the wireless link via a single power line 518.
[0066] The electronic sensor 510 may comprise receiving a circuit described in this document that is capable of detecting various signals. In one embodiment, sensor 510 may comprise an electrical card comprising a wireless sensor and the wireless signal may be an electromagnetic signal and/or a sonic signal. The electrical board can be electrically coupled to a plurality of electronic actuators. The electrical board may be programmed to detect a multitude of signals and the multiplicity of signals may comprise signals associated with each subset of electronic actuators. For example, a first signal may correspond to the first electronic trigger, a second signal may correspond to a second set of the electronic trigger, a third signal may correspond to the third set of the electronic trigger, a fourth signal may correspond to a fourth set of the electronic trigger , a fifth signal may correspond to the first set of electronic trigger and the second set of electronic trigger, a sixth signal may correspond to the first set of electronic trigger and third set of electronic trigger, and so on for each subset. Thus, by selecting the specific signal transmitted to the sensor, the triggering of the electronic trigger or a plurality of electronic triggers can be selectively controlled.
[0067] While FIG. 6A and FIG. 6B illustrate a fluid path through the production glove assembly, it should be understood that various other components may be incorporated into the production glove assembly in keeping with the principles of the present disclosure. In one embodiment, a flow restriction may be arranged in series or parallel with fluid path 514. For example, a flow restriction may be arranged parallel with fluid path 514 and fluid flow may initially proceed through of the production sleeve assembly through a flow restriction. A port on the tubular well rig can provide a restricted flow through the production sleeve assembly. The fluid path 514 can then be configured to provide a bypass path with a lower resistance to fluid flow compared to the fluid path through flow restriction. Additional arrangements of the components described in this document are possible in keeping with the modalities disclosed herein.
[0068] In operation, the production sleeve assembly can be installed in a well in its non-triggered configuration (indicated in FIG. 6A). In the non-actuated configuration, fluid flow from the outside of the well tubular equipment to the inside of the well tubular equipment 120 can be substantially impeded by means of the piston 513. In order to start the production flow, at least one electronic actuator 501 may be actuated to thereby supply fluid flow through at least one fluid path 514 between the exterior of the well tubular equipment to the interior of the well tubular equipment 120.
[0069] The production sleeve assembly can be reconfigured by initiating a signal transmission. After transmission, the signal can travel to sensor 510 located inside the well. One or more intermediate receivers and/or transmitters (eg repeaters) may be present between the original transmission source and the sensor associated with a specific electronic trigger. When the signal is received by the sensor, the sensor can detect the signal, and a receiving circuit associated with the sensor and/or the electronic driver can determine whether the first signal corresponds to a signal to drive one or more electronic drivers. After the receiving circuit determines that the first signal comprises a suitable signal (eg pattern or specific type of amplitude, phase, slope, signal profile, etc.) to trigger the electronic trigger, an initiator can be ignited to do with than the rupture device to pierce an actionable device. In response, the perforated actionable device containing an opening can allow fluid flow through a corresponding fluid pathway. In some embodiments, the perforated, actuable device may result in movement of a piston or other locking member located in the fluid pathway, thereby allowing fluid to flow through the fluid pathway.
[0070] The production sleeve assembly can be further reconfigured by transmitting a second signal that corresponds to the opening and/or closing of a specific fluid path. After transmission, the signal can travel through the well to the sensor. When the signal hits the sensor, the sensor can detect the second signal, and the receiving circuit can determine if the signal is an appropriate signal. After the receiving circuit determines that the second signal comprises a signal suitable for triggering a second electronic trigger, an initiator can be ignited to cause the rupture device to pierce a triggerable device. In response, the perforated actionable device containing an opening can allow fluid flow through a corresponding fluid pathway. In some embodiments, the perforated, actuable device may result in movement of a piston or other locking member located in the fluid pathway, thereby allowing fluid to flow through the fluid pathway.
[0071] The sign may comprise a single sign representing the opening of all fluid pathways that must be opened. Alternatively, the signal may comprise more than one signal, where each signal represents the opening of one or some of the fluid pathways that are to be opened. In one embodiment, suitable signals can be transmitted over the life of the well to reconfigure one or more fluid pathways through the production sleeve assembly.
[0072] In one embodiment, several sets of the production sleeve may be arranged along the length of the well. One or more production sleeve assemblies may be disposed at various zones along the well, thus forming a completion assembly for producing fluid into the well's tubular equipment. When multiple production glove assemblies are present, some or all of the production glove assemblies may comprise the electronic actuator 501 assembly and sensors as described in this document. In addition, the specific configuration of the assemblies of electronic actuator 501 and sensors 510 in each of the production sleeve assemblies comprising these parts may be the same or different. For example, a first production glove assembly may comprise an electronic actuator assembly 501 comprising an electromechanical actuator while a second production glove assembly may comprise an electronic actuator assembly 501 comprising a rupture device. Likewise, for any specific production sleeve assembly that comprises multiple electronic actuator assemblies, each electronic actuator assembly may be the same or different.
[0073] When one or more sets of the production sleeve described in this document are present in the well, a signal can be used to drive only one set of the electronic driver 501. For example, a transmitter can transmit a signal that activates a set of the driver specific electronic 501 in a first set of the production glove. In order to drive another set of electronic driver 501, a second signal may be transmitted to drive one or more remaining electronic driver sets in the same production sleeve assembly or in a different production sleeve assembly. This process can be repeated to trigger the desired number of electronic actuator 501 assemblies in the wellbore and thereby configure the desired number of fluid pathways within the wellbore. In one embodiment, a single signal transmitted by the transmitter can drive a plurality of electronic driver sets 501 which can be the same or different production sleeve sets. For example, two or more sets of Electronic Trigger 501 in different production sleeves can be configured to trigger based on the same signal. In this modality, a transmitter can be used to drive a plurality of sets of the electronic driver 501 in a single transmission. For example, two or more production glove sets can be transferred from a run initially in configuration to an open configuration. Other reconfigurations described in this document may also be possible.
[0074] In one embodiment, a transmitter can transmit several signals at the same time, which can drive a plurality of electronic drivers, which may or may not be in the same set of the production sleeve. For example, the transmitter can transmit multiple signals, each signal being configured to drive one or more electronic triggers. The use of a single transmission comprising several signals can allow relatively quick reconfiguration of the completion set comprising several sets of the production glove.
[0075] While the production glove assembly and methods described in relation to Figures 2-6 are generally described in terms of the transit of the plurality of fluid pathways from a closed configuration to a restricted configuration and, thereafter, to a configuration open, the production sleeve set can transition between any number of configurations. For example, flow paths through a production sleeve assembly can transition from a closed position to a restricted position to a closed position. Alternatively, the production glove assembly can transition from a restricted position to a closed position to an open position. In one modality, any combination of these settings is possible. In addition, using the plurality of electronic actuator sets can allow more or less than three configurations. For example, the production glove assembly can transition from a closed position to an open position using the electronic actuator, sensors, actuating members, locking members and/or breaking devices described in this document. In one embodiment, the production sleeve assembly could transition between four or more fluid path configurations.
[0076] In addition, when multiple sets of the production sleeve are disposed along the tubular string of the well, each set of the production sleeve may have the same number of transitions and configurations or a different number of transitions and configurations. For example, a first production sleeve set may have three separate fluid path configurations (e.g., closed, restricted, open) while a second production sleeve assembly may have four or more separate fluid path configurations. The ability to provide different configurations and transitions can allow a well tubular string comprising one or more production sleeve sets to be reconfigured as desired during production, with some zones having more potential configurations than others.
[0077] After the description of the systems and methods in this document, several modalities may include, among others:
[0078] In a first embodiment, a downhole component comprises tubular downhole equipment, a plurality of fluid pathways configured to provide fluid communication within the downhole component, a plurality of electronic actuators configured to selectively provide , fluid communication via one or more fluid pathways and at least one sensor coupled to a plurality of electronic actuators. At least one or more electronic actuators comprise a locking member coupled to an electromechanical actuator and one or more electronic actuators are configured to selectively actuate and allow or prevent fluid flow through a corresponding fluid pathway of the plurality of fluid pathways in response at least one sensor that receives an adequate signal.
[0079] A second embodiment may include the downhole component of the first embodiment, wherein the plurality of fluid pathways are configured to provide fluid communication between the exterior of the tubular well equipment and the interior of the tubular well equipment.
[0080] A third embodiment may include the downhole component of the first and second embodiments further comprising a power source coupled to one or more electronic drivers, in which the power source is configured to provide power to drive one or more electronic actuators.
[0081] A fourth embodiment may include the downhole component of the third embodiment, wherein the power source comprises at least a battery, a downhole generator, a surface power source or a bottom power source of the well.
[0082] A fifth embodiment may include the downhole component of the third embodiment, wherein the power source is located on the well surface.
[0083] A sixth embodiment may include the downhole component of any of the first and fifth modes, further comprising a section of the sand control screen disposed in series with the plurality of fluid pathways.
[0084] A seventh mode may include the downhole component of any one of the first to sixth modes, further comprising one or more restrictions, in which one or more flow restrictions are disposed in at least one of the plurality of pathways of fluid.
[0085] An eighth embodiment may include the downhole component of any one of the first through seventh embodiments, wherein the locking member is configured to selectively provide fluid communication via two or more fluid pathways.
[0086] A ninth modality may include the downhole component of any of the first and eighth modalities, wherein two or more electronic actuators are configured to selectively trigger in response to at least one sensor that receives the appropriate signal.
[0087] A tenth embodiment may include the downhole component of any one of the first to ninth embodiments, wherein at least one sensor comprises a pressure sensor.
[0088] An eleventh embodiment may include the downhole component of the tenth embodiment, wherein the suitable signal comprises at least a pressure, a pressure wave, one or more pressure pulses, or a sonic signal.
[0089] A twelfth modality may include the downhole component of any one of the first to eleventh modality, wherein one or more electronic actuators are further configured to selectively trigger the transition of fluid path plurality of a first configuration to a second configuration in response to at least one sensor receiving an appropriate signal, wherein in the first configuration all fluid pathways are substantially closed to fluid flow and wherein in the second configuration one or more fluid pathways are open to the flow.
[0090] In a thirteenth embodiment, a production glove assembly for use in a well and the production glove assembly comprise well tubular equipment, the plurality of fluid pathways configured to provide fluid communication between the exterior of the tubular equipment of well and the interior of the tubular well equipment, the plurality of electronic actuators and at least one sensor coupled to the plurality of electronic actuators. At least one of the plurality of electronic actuators comprises disrupting devices positioned adjacent to actuable devices, the plurality of electronic actuators being configured to selectively provide fluid communication through one or more of the plurality of fluid pathways. The rupture device is configured to actuate the actuable device so as to permit fluid flow through at least one fluid path among the plurality of fluid paths in response to at least one sensor that receives a suitable signal.
[0091] A fourteenth modality may include the production glove assembly of the thirteenth modality, wherein the rupturing device comprises a chemical initiator that is configured to ignite based on at least one sensor that receives an appropriate signal.
[0092] A fifteenth embodiment may include the production sleeve assembly of the thirteenth or the fourteenth embodiment, wherein the triggerable device is configured to provide fluid communication in response to being triggered.
[0093] A sixteenth embodiment may include the downhole component of any one of the thirteenth and fifteenth modes, wherein the actuable device is disposed in a first fluid path among the plurality of fluid paths, and wherein which the triggerable device is configured to provide fluid communication through the first fluid path after triggering.
[0094] A seventeenth modality may include the downhole component of any one of the thirteenth and sixteenth modality, wherein the first fluid pathway comprises a flow restriction.
[0095] An eighteenth modality may include the downhole component of any one of the thirteenth and seventeenth modes, further comprising a piston disposed in a fluid path among the plurality of fluid paths, wherein the piston is configured to shift in response to providing fluid communication through the actuable device and wherein the piston is configured to provide fluid communication through the fluid pathway in response to the shift.
[0096] In a nineteenth modality, a method of configuring a production sleeve assembly in a well comprises receiving a signal in a sensor, determining that the signal is an appropriate signal, receiving, by one or more electronic actuators among the plurality of electronic actuators, power from a power source, driving one or more electronic actuators in response to the determination that the signal is a suitable signal and selectively opening one or more fluid pathways from the plurality of fluid pathways in response to actuation of the electronic trigger.
[0097] A twentieth embodiment may include the method of the nineteenth embodiment, wherein one or more fluid pathways are configured to provide fluid communication between the exterior of the tubular well equipment and the interior of the tubular well equipment.
[0098] A twenty-first mode may include the method of the nineteenth and twentieth modes, further comprising the selective closure of one or more fluid pathways in response to actuation of the electronic actuator.
[0099] A twenty-second modality may include the downhole component of any one of the nineteenth and twenty-first modalities, wherein the energy source is located on the well surface.
[00100] A twenty-fourth modality may include the downhole component of any one of the nineteenth to twentieth modalities, wherein the suitable signal comprises at least a pressure, a pressure wave, one or more pressure pulses, or a sonic signal.
[00101] While the embodiments of the invention have been shown and described, their modifications can be made by those skilled in the art without abandoning the meaning and teachings of the invention. The modalities described herein are exemplary only and are not intended to be a limiting factor. Many variations and modifications of the invention disclosed in this document are possible and are within the scope of the invention. Numerical ranges or limitations are expressly to the contrary, such express ranges or limitations shall be understood to include iterative ranges or limitations such as magnitudes covered with expressly stated ranges or limitations (eg, from about 1 to about 10 includes, 2, 3, 4, etc.; greater than 0.10 includes 0.11, 0.12, 0.13, etc.). For example, whenever a numerical range with a lower bound, Rl and an upper bound, Ru, is disclosed, any number falling within the range is specifically disclosed. In particular, the following numbers within the range are specifically disclosed: R=Rl+k* (Ru-Rl), where k is a variable ranging from 1% to 100% with an increment of 1%, that is, k is 1%, 2%, 3%, 4%, 5%... 50%, 51%, 52%, ..., 95%, 96%, 97%, 98%, 99% or 100%. In addition, any numerical range defined by two R numbers as defined in the example above is also specifically disclosed. Use of the term "optionally" in relation to any element of a statement is intended to say that the subject element is necessary, or alternatively, not necessary. Both alternatives are intended to be within the scope of the claim. Use of broader terms such as comprises, includes, having, etc. should be understood to provide support for narrower terms such as consisting of, essentially consisting of, substantially understood, etc.
[00102] In this sense, the scope of protection is not limited by the above-stated description but is only limited by the claims that follow, in that scope, including all equivalents of the subject matter of the claims. Each and every claim is incorporated into the specification as an embodiment of the present invention. Thus, the claims are a further description and a complement to the embodiments of the present invention. The discussion of a reference in the detailed description of the embodiments is not an admission that it is the state of the art for the present invention, especially any reference that may have a publication date after the priority date of this application. Disclosures of all patents, patent applications, and publications cited herein are hereby incorporated by reference insofar as they provide exemplars, procedural, or other details in addition to those set forth.

权利要求:
Claims (14)
[0001]
1. Downhole component, characterized in that it comprises: - a tubular well equipment (22); - filter means; - an outer protective skirt (108) having a plurality of perforations (109) positioned around the outer part of the filter means; - a plurality of fluid pathways (103) configured to provide fluid communication within the downhole member; - a plurality of electronic actuators configured to selectively provide fluid communication through one or more of the plurality of fluid pathways (103), at least one of the plurality of electronic actuators comprising a locking member (113) coupled to a electromechanical actuator (114); and - at least one sensor (117) coupled to the plurality of electronic actuators, one or more of the plurality of electronic actuators being configured to selectively actuate to allow or prevent fluid flow through a corresponding fluid pathway (103) of the plurality of fluid pathways in response to at least one sensor (117) receiving a suitable signal, and wherein the suitable signal comprises at least one of a pressure, a pressure wave, one or more pressure pulses or a sonic signal .
[0002]
2. Downhole component according to claim 1, characterized in that the plurality of fluid pathways (103) is configured to provide fluid communication between the exterior of the tubular well equipment (22) and the interior of the tubular equipment of well (22).
[0003]
3. Downhole component according to claim 1 or 2, characterized in that it further comprises a power source (116) coupled to one or more of the plurality of electronic actuators, in which the power source (116) is configured to supply power to drive one or more of the plurality of electronic drives.
[0004]
4. Downhole component according to claim 3, characterized in that the power source (116) comprises at least a battery, a downhole generator, a surface energy source or an energy source from the bottom of the well.
[0005]
5. Downhole component according to claim 3, characterized in that the power source (116) is located on the well surface.
[0006]
6. Downhole component according to any one of claims 1 to 5, characterized in that it further comprises a section of the sand control screen arranged in series with the plurality of fluid pathways (103).
[0007]
7. Downhole component according to any one of claims 1 to 5, characterized in that it further comprises one or more flow restrictions, in which one or more flow restrictions are arranged in at least one of the plurality of fluid pathways (103).
[0008]
8. Downhole component according to any one of claims 1 to 7, characterized in that the locking member (113) is configured to selectively provide fluid communication through two or more of the plurality of fluid pathways (103).
[0009]
9. Downhole component according to any one of claims 1 to 7, characterized in that two or more of the plurality of electronic actuators are configured to selectively trigger in response to at least one sensor (117) receiving the suitable sign.
[0010]
10. Downhole component according to any one of claims 1 to 9, characterized in that one or more of the plurality of electronic actuators are further configured to selectively drive the transition of the plurality of fluid pathways (103) of a first configuration to a second configuration in response to at least one sensor (117) receiving an appropriate signal, wherein in the first configuration all of the pathways of the plurality of fluid pathways (103) are closed to fluid flow, and wherein in the second configuration one or more of the fluid pathways are open to flow.
[0011]
11. Method of configuring a production sleeve assembly inside a well, characterized in that it comprises: - receiving a signal in a sensor (117); - determine that the signal is a suitable signal; - receiving, by one or more electronic actuators of the plurality of electronic actuators, energy from a power source (116); - trigger one or more electronic triggers in response to the determination that the signal is the proper signal; and - selectively opening one or more fluid pathways (103) of one of the plurality of fluid pathways in response to actuation of the electronic actuator, the appropriate signal comprising at least one of a pressure, a pressure wave, one or more pulses pressure or a sonic signal.
[0012]
12. The method of claim 11, characterized in that one or more fluid pathways (103) provide fluid communication between the exterior of the tubular well equipment (22) and the interior of the tubular well equipment (22).
[0013]
13. Method according to claim 11, characterized in that the power source (116) is located on the surface of the well.
[0014]
14. Method according to any one of claims 11, 12 and 13, characterized in that it further comprises the selective closure of one or more fluid pathways (103) in response to the activation of the electronic trigger.

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AU2013377936B2|2017-02-16|

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CA2896147C|2017-09-12|

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EP2920409B1|2017-11-01|

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US20140338922A1|2014-11-20|

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WO2014123539A1|2014-08-14|

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法律状态:
2018-12-04| B06F| Objections, documents and/or translations needed after an examination request according [chapter 6.6 patent gazette]|

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2020-02-04| B06U| Preliminary requirement: requests with searches performed by other patent offices: procedure suspended [chapter 6.21 patent gazette]|

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2021-03-02| B09A| Decision: intention to grant [chapter 9.1 patent gazette]|

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2021-05-11| B16A| Patent or certificate of addition of invention granted|Free format text: PRAZO DE VALIDADE: 20 (VINTE) ANOS CONTADOS A PARTIR DE 08/02/2013, OBSERVADAS AS CONDICOES LEGAIS. |

优先权:

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申请号 | 申请日 | 专利标题

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PCT/US2013/025419|WO2014123539A1|2013-02-08|2013-02-08|Electronic control multi-position icd|

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