Systems and methods for flow control

Abstract

A method for valve actuation includes detecting, via a sensor, a subterranean fluid property at a location near to the sensor, sending a first signal to a controller, where the first signal is indicative of the subterranean fluid property at the location proximate to the sensor, and converting the first signal into a second signal, where the second signal is indicative of a subterranean fluid property at a location near a valve. The method further includes determining a downhole condition based on the second signal and actuating the valve based on the downhole condition.

Description

IS23.0163-WO-PCT SYSTEMS AND METHODS FOR FLOW CONTROL CROSS-REFERENCE TO RELATED APPLICATIONS

[0001] The present application claims the benefit of United States Provisional Application No.63 / 690878 filed September 5, 2024, the entirety of which is incorporated by reference herein and should be considered part of this specification. BACKGROUND

[0002] The present disclosure generally relates to systems and methods for pumping fluid in a subterranean well.

[0003] This section is intended to introduce the reader to various aspects of art that may be related to various aspects of the present disclosure, which are described and / or claimed below. This discussion is believed to be helpful in providing the reader with background information to facilitate a better understanding of the various aspects of the present disclosure. Accordingly, it may be understood that these statements are to be read in this light, and not as admissions of prior art.

[0004] In production stage oilfield applications, after drilling into a subterranean formation, subterranean fluid (e.g., oil) is transferred to an above ground location (e.g., collection site). In some applications, the various locations containing subterranean fluids may include various pressures, and / or may deplete at varying times, relative to other wellbore locations. To optimize production, an extraction system (e.g., a string, downhole assembly) may include one or more downhole flow control valves (FCVs) that may control the flow of subterranean fluid into the system, through the well string, and towards the above ground location. In some instances, the FCV may be an electric flow control valve (eFCV), including one or more downhole electronic components configured to control the flow of subterranean fluid into the well string. Unfortunately, existing eFCVs may be susceptible to damage from downhole conditions, such as turbulent flow of the subterranean fluid. SUMMARYIS23.0163-WO-PCT

[0005] A summary of certain embodiments disclosed herein is set forth below. It should be understood that these aspects are presented merely to provide the reader with a brief summary of these certain embodiments and that these aspects are not intended to limit the scope of this disclosure. Indeed, this disclosure may encompass a variety of aspects that may not be set forth below.

[0006] In certain embodiments, a method for valve actuation includes detecting, via a sensor, a subterranean fluid property at a location near to the sensor, sending a first signal to a controller, where the first signal is indicative of the subterranean fluid property at the location proximate to the sensor, and converting the first signal into a second signal, where the second signal is indicative of a subterranean fluid property at a location near a valve. The method further includes determining a downhole condition based on the second signal and actuating the valve based on the downhole condition.

[0007] In certain embodiments, a system for fluid flow regulation includes a wellbore system that may be inserted into a wellbore to extract fluid from the wellbore and a valve disposed at a first location on the wellbore system, where the valve may regulate fluid flow from the wellbore into the wellbore system. The system further may include a sensor disposed at a second location on the wellbore system, where the second location is downstream of the first location relative to a direction of fluid flow and where the sensor is configured to detect a fluid property at the second location. The system further may include a controller configured to, receive a first signal indicative of the fluid property at the second location, convert the first signal to a second signal indicative of a fluid property at the first location, determine a downhole condition based on the second signal, and actuate the valve based on the downhole condition.

[0008] In certain embodiments, a method for valve actuation includes detecting, via a sensor, a first subterranean fluid property at a location proximate to the sensor, sending a first signal to a controller, where the first signal is indicative of the first subterranean fluid property at the location proximate to the sensor and converting the first signal into a second signal, where the second signal is indicative of the first subterranean fluid property at a location proximate an electronic flow control valve. The electronic flow control valve may include aIS23.0163-WO-PCT choke configured to enable fluid communication between a wellbore and a wellbore system, where the electronic flow control valve comprises a sleeve configured to cover and uncover the choke. The method further includes actuating the sleeve of the electronic flow control valve to cover and uncover the choke based on the second signal.

[0009] The brief summary presented above is intended only to familiarize the reader with certain aspects and contexts of embodiments of the present disclosure without limitation to the claimed subject matter. BRIEF DESCRIPTION OF THE DRAWINGS

[0010] These and other features, aspects, and advantages of the present disclosure will become better understood when the following detailed description is read with reference to the accompanying drawings in which like characters represent like parts throughout the drawings, wherein:

[0011] FIG. 1 is a schematic side view of a wellsite having an extraction system comprising a flow control valve, in accordance with embodiments described herein;

[0012] FIG. 2 is a schematic side view of a wellsite having an extraction system comprising one or more flow control valves, in accordance with embodiments described herein;

[0013] FIG. 3 is a schematic side view of a flow control valve, in accordance with embodiments described herein;

[0014] FIG.4 is a schematic view of an actuator of a flow control valve, in accordance with embodiments described herein;

[0015] FIG. 5 is a flow diagram of a process for actuating a flow control valve, in accordance with embodiments described herein; and

[0016] FIG. 6 is a flow diagram of a process for actuating a flow control valve, in accordance with embodiments described herein.IS23.0163-WO-PCT DETAILED DESCRIPTION

[0017] Certain embodiments commensurate in scope with the present disclosure are summarized below. These embodiments are not intended to limit the scope of the disclosure, but rather these embodiments are intended only to provide a brief summary of certain disclosed embodiments. Indeed, the present disclosure may encompass a variety of forms that may be similar to or different from the embodiments set forth below.

[0018] As used herein, the term “coupled” or “coupled to” may indicate establishing either a direct or indirect connection (e.g., where the connection may not include or include intermediate or intervening components between those coupled), and is not limited to either unless expressly referenced as such. The term “set” may refer to one or more items. Wherever possible, like or identical reference numerals are used in the figures to identify common or the same elements. The figures are not necessarily to scale and certain features and certain views of the figures may be shown exaggerated in scale for purposes of clarification.

[0019] As used herein, the terms “inner” and “outer”; “up” and “down”; “upper” and “lower”; “upward” and “downward”; “above” and “below”; “inward” and “outward”; and other like terms as used herein refer to relative positions to one another and are not intended to denote a particular direction or spatial orientation. The terms “couple,” “coupled,” “connect,” “connection,” “connected,” “in connection with,” and “connecting” refer to “in direct connection with” or “in connection with via one or more intermediate elements or members.”

[0020] Furthermore, when introducing elements of various embodiments of the present disclosure, the articles “a,” “an,” and “the” are intended to mean that there are one or more of the elements. The terms “comprising,” “including,” and “having” are intended to be inclusive and mean that there may be additional elements other than the listed elements. Additionally, it should be understood that references to “one embodiment,” “an embodiment,” or “some embodiments” of the present disclosure are not intended to be interpreted as excluding the existence of additional embodiments that also incorporate theIS23.0163-WO-PCT recited features. Furthermore, the phrase A “based on” B is intended to mean that A is at least partially based on B. Moreover, unless expressly stated otherwise, the term “or” is intended to be inclusive (e.g., logical OR) and not exclusive (e.g., logical XOR). In other words, the phrase A “or” B is intended to mean A, B, or both A and B.

[0021] In some oilfield operations, recovering subterranean fluid (e.g., liquid oil, natural gas, water, and / or other well fluids) includes inserting a string (e.g., well pump string, well pump system, well pump stack) into a wellbore (e.g., borehole, drill hole, casing) extending into one or more subterranean formations containing the subterranean fluid. In some instances, one or more flow control valves (FCVs) may be positioned at various depths along the string to control an amount of subterranean fluid and / or other downhole substances (e.g., undesirable solids) entering the string. In this way, the FCV may maintain a desired flow rate through the string to maintain a string pressure, reducing and / or preventing blowouts and other undesirable mechanical faults (e.g., damage to one or more string components or tools). In some operations, the FCV may be operated (e.g., opened, closed) hydraulically, while in other instances, the FCV may be electronic (e.g., electronic flow control valve, eFCV). Advantageously, oilfield operations that utilize eFCVs, may experience a reduction in cost and complexity while controlling flow through the pump of the string, compared to non- electronic FCVs. eFCVs may include one or more electrical components (e.g., actuator, controller) configured to control and / or maintain a flow rate (e.g., subterranean fluid flow rate) through the valve and further through the string.

[0022] Some embodiments of eFCVs may include one or more sensors configured to detect one or more parameters of the eFCV, the string (e.g., other components of the string), and / or subterranean fluid (e.g., flow rate, pressure, temperature, vibration), wherein a controller may operate the eFCV based on the detected parameter. Unfortunately, a position of the sensor relative to the intake of an eFCV (e.g., the choke, the holes) may result in the detected parameters not being indicative of a condition or parameter near the choke of the eFCV. Therefore, the present disclosure relates to systems and methods for detecting one or more parameters of the eFCV, the string, and / or subterranean fluid near the intake of the eFCV. Further, the present disclosure relates to systems and methods for using the one orIS23.0163-WO-PCT more parameters near the intake of the eFCV to determine one or more downhole conditions (e.g., flow rate, gas slugging, solid ingress, formation fracturing, component wear), and controlling the eFCV accordingly.

[0023] FIG. 1 illustrates an embodiment of an extraction system 10 (e.g., subterranean fluid extraction system, hydrocarbon extraction system, wellbore system, or wellsite system) having a downhole assembly 100 (e.g., pump assembly) positioned in a borehole or wellbore 102. The wellbore 102 may include one or more perforations 104, extending through an optional casing 106 of the wellbore 102 to one or more surrounding formations 108 (e.g., oil reservoir, subterranean formation). The perforations 104 may enable fluid 110 (e.g., subterranean fluid, oil, natural gas, water, or other well fluid) to flow from a respective surrounding formation 108 to the wellbore 102. Within the wellbore 102, the fluid 110 may be pumped or otherwise transferred to an above ground location via the downhole assembly 100 for further refining. Specifically, the downhole assembly 100 may be detachably lowered into wellbore 102 after a drilling operation to a desired location (e.g., near the surrounding formation 108), where then operation of the downhole assembly 100 may begin.

[0024] The downhole assembly 100 may include one or more components configured to transfer the flow of fluid 110 from the downhole location (e.g., wellbore 102) to the surface. For example, the downhole assembly 100 may include a motor 112 (e.g., submersible motor) such as an induction motor or magnetic motor, configured to drive a submersible gearbox 114 positioned on the downhole assembly 100. The submersible gearbox 114 may be configured to drive a pump 132 (e.g., progressive cavity pump, electric pump, etc.). Specifically, as fluid 110 (e.g., oil) flows into the wellbore 102 from the surrounding formation 108 through perforation 104, the motor 112 may operate the pump 132 to extract the fluid 110 from the wellbore 102 to a well head 120 (e.g., a tree (e.g., Christmas tree)) and further to an appropriate above ground production location. In some embodiments, the downhole assembly 100 may further include a gas separator (e.g., vortex gas separator assembly or VGSA), configured to separate the fluid 110 into liquid and gas state components.IS23.0163-WO-PCT

[0025] The fluid 110 may enter the downhole assembly 100, and / or a pipe or string 124 through a choke 122 (e.g., intake), where the fluid 110 may then be transferred to the well head 120. As will be discussed in further detail below, the choke 122 may be controlled by a flow control valve 123 (e.g., FCV, electric flow control valve (e.g., eFCV)) integrated into the downhole assembly 100 and / or the string 124. Although FIG.1 illustrates the choke 122 disposed below the pump 132, it will be appreciated the choke 122 and corresponding FCV 123 may be positioned at any relative location on the downhole assembly 100, such as above the pump 132. Further, although the choke 122 and corresponding FCV 123 are illustrated on the downhole assembly 100 in FIG. 1, it should be appreciated that the choke 122 and corresponding FCV 123 may be positioned on the string 124 in addition or alternative to the illustrated choke 122 and FCV 123.

[0026] In some embodiments, the downhole assembly 100 may receive power from a downhole location (e.g., within the wellbore 102), for example, through a power cartridge (e.g., battery pack) of the downhole assembly 100. In other embodiments, one or more components of the downhole assembly 100 may receive power from an above ground location (e.g., outside of the wellbore 102). In such embodiments where the downhole assembly 100 utilizes an above ground power source, the downhole components (e.g., motor 112, FCV 123) may be powered (e.g., electrically powered) by a power source 126 (e.g., variable speed drive, switchboard). Specifically, the downhole components (e.g., motor 112, gas separator, FCV 123) may be electrically coupled to the power source 126 via, for example, a power line 129. In some embodiments, the power line 129 may be external to one or more components of the downhole assembly 100. In any case, the power line 129 may electrically couple one or more components of the downhole assembly 100 to the power source 126 and a cable junction box 130.

[0027] FIG.2 illustrates a schematic view of the extraction system 10 that may include a downhole assembly 100 coupled to a string 124 disposed within a wellbore 102 and configured to receive and extract fluid 110 to transfer to an above ground location. In some extraction systems, such as extraction system 10 illustrated in FIG.2, there may be more than one subterranean formation 108 (e.g., subterranean formation 108a, 108b). As discussedIS23.0163-WO-PCT above, in order to increase production, the extraction system 10 may include more than one FCV 123 each including a corresponding choke 122 configured to intake subterranean fluids 110. For example, the extraction system 10 may include a first and second FCV 123a, 123b on the string 124, configured to control flow of subterranean fluid flowing through perforations 104 fluidly coupling the wellbore 102 to a first subterranean formation 108a. Likewise, the extraction system 10 may include a third FCV 123c disposed on the downhole assembly 100, configured to control flow of subterranean fluid 110 flowing through perforations 104 fluidly coupling the wellbore 102 to a second subterranean formation 108b. As will be appreciated, subterranean formation 108a may have different downhole properties and fluid compositions than subterranean formation 108b. As such, the FCVs 123a, 123b, 123c may be controlled separately based on respective subterranean fluid properties at each respective location.

[0028] By controlling (e.g., via the FCVs 123) subterranean fluid flow throughout the extraction system 10 (e.g., downhole assembly 100, string 124), the extraction system 10 may maintain a string pressure, reducing and / or preventing blowouts and other undesirable mechanical faults (e.g., damage to one or more extraction system 10 components or tools). Although three FCVs 123 are illustrated, it will be appreciated more or less FCVs 123 at one or more different location may be incorporated into the extraction system 10 to enable increased fluid regulation.

[0029] FIG. 3 illustrates and embodiment of an FCV 123 that may be used in the extraction system 10 of either of FIGS.1 and 2. Although the FCV 123 is discussed below as disposed on the string 124, it will be appreciated the FCV 123 may be at other locations of the extraction system 10, such as the downhole assembly 100. The FCV 123 may be integrated onto and / or into the string 124 at one or more locations within the wellbore 102, such that subterranean fluid 110 may enter the string 124 at various locations. For example, as discussed above, the FCV 123 may include a choke 122 (e.g., intake, inlet) configured to receive subterranean fluid 110 flow from the surrounding subterranean formation 108. The subterranean fluid 110 may be combined with a flow 134 from a downhole location relativeIS23.0163-WO-PCT to the FCV 123, to create a combined stream through the string 124. The flow 134 may be received into the string 124 through a second FCV at a downhole location.

[0030] Structurally, the FCV 123 may include the intake or choke 122 configured to enable the string 124 of the extraction system 10 to receive subterranean fluid 110 from the surrounding subterranean formation 108. The choke 122 may include one or more holes within the string 124 to fluidly couple the wellbore 102 to the interior of the string 124. For example, the choke 122 may include multiple holes disposed around (e.g., radially or circumferentially outside) the string 124, such that subterranean fluid 110 may enter the string 124 at various locations around the circumference of the string 124.

[0031] Further, the FCV 123 may include a valve or sleeve 128 configured to occlude (e.g., cover) the choke 122, such that the flow of subterranean fluid 110 entering the string 124 may be regulated or maintained. For example, the sleeve 128 may be disposed external to the string 124, and may radially surround the string 124, such that the outer circumference of the string 124 is covered at least partially by the sleeve 128. In some embodiments, the sleeve 128 may be disposed internal to the string 124, such that an interior circumference of the string 124 may at least partially surround the sleeve 128. The sleeve 128 may extend (e.g., linearly extend, linearly translate) in a direction 142 parallel to an axis 146 extending through the length of the string 124 and may retract in a direction 150 opposite of the direction 142. In other words, the sleeve 128 may extend or retract in a direction of subterranean flow through the string 124 and / or downhole assembly 100. In embodiments employing an external sleeve, the sleeve 128 may extend along the length of the string 124 in the direction 142 to occlude (e.g., cover) the choke 122 to reduce and / or prevent subterranean fluid 110 from entering the string 124. For example, upon determining no subterranean fluid110 is desired through the choke 122, the sleeve 128 may be actuated to extend to a position covering (e.g., radially covering) radial holes of the choke 122. Upon determining subterranean fluid 110 is desired through the choke 122 and into the respective section of the string 124, the sleeve 128 may be actuated to a position to uncover (e.g., radially uncovering) the radial holes of the choke 122. In some embodiments, upon determining partial subterranean fluid 110 flow is desired into the string 124, the sleeve 128 may be actuated toIS23.0163-WO-PCT extend (e.g., extend in the direction 142) to a position at least partially occluding (e.g., radially occluding, covering) the radial holes of the choke 122. An internal sleeve 128 (e.g., internal to the string 124 and / or the downhole assembly 100) may operate in a similar manner to an external sleeve 128 as discussed above. That is, an internal sleeve 128 may extend within the string 124 along the direction 142 to underlie the radial holes of the choke 122 to fluidly decouple the wellbore 102 from the interior of the string 124.

[0032] In some embodiments, the FCV 123 may be an electronic FCV, configured to electronically actuate the sleeve 128 to cover and uncover the choke 122 in a manner as discussed above. For example, the FCV 123 may include an actuator 154 (e.g., electronic actuator) configured to translate an axial linkage (e.g., a shaft and / or a piston 158) coupled to the sleeve 128 along the directions 142, 150 to cover and uncover the radial holes of the choke 122 based on one or more conditions or parameters. The piston 158 may be coupled to the sleeve 128 by any suitable attachment mechanism, for example, through friction fit, one or more fasteners, and / or chemical adhesives. The actuator 154 may be disposed external or internal to the string 124 and / or the downhole assembly 100 and may be disposed at various locations within the extraction system 10. That is, extraction system 10 may include multiple actuators 154 at various locations along the wellbore 102 configured to each actuate a respective sleeve 128 to cover a respective choke 122. In some embodiments, one actuator 154 may actuate more than one FCV 123 and / or other components of the extraction system 10.

[0033] To adjust or translate the sleeve 128, the actuator 154 may include an electric drive 162 coupled to the piston 158, configured to translate the piston 158 along the direction 142, 150, to position the sleeve 128 in one or more locations relative to the holes of the choke 122 (e.g., covering, uncovering, partially covering). The electric drive 162 may be a linear motor configured to convert electrical power into a linear motion of the piston 158. In certain embodiments, the electric drive 162 may include an electric motor that rotates a shaft having external threads (e.g., male threaded shaft) relative to a linearly movable body having internal threads (e.g., female threaded body), thereby converting rotational motion of the electric motor into linear motion of the linearly movable body coupled to the piston 158. In certainIS23.0163-WO-PCT embodiments, the electric drive 162 may include an electric motor coupled to a gear assembly or transmission, which is configured to convert the rotational motion of the electric motor into linear motion of the piston 158. For example, the gear assembly may include a planetary gear assembly having a sun gear, a plurality of planet gears disposed about the sun gear, and a ring gear disposed about the plurality of planet gears. By further example, the gear assembly may include a rack and pinion assembly having a circular gear or pinion driven to rotate by the electric motor, while the pinion rotates along a linear gear or rack to convert the rotational motion of the pinion into linear motion of the rack. In some embodiments, the electric drive 162 may receive power (e.g., electrical power) from an above ground location, such as power source 126 shown in FIG.1. In some embodiments, the electric drive 162 may receive power (e.g., electrical power) from a below ground location, such as a battery.

[0034] In some embodiments, the actuator 154 may include a controller 166 configured to perform one or more downhole operations based on one or more inputs. For example, the controller 166 may send a signal to the electric drive 162 to actuate the sleeve 128 to a closed position (e.g., occluding position, covering position) based on a detected parameter, a signal received from a above ground source (e.g., above ground controller, human operator), and / or a signal received from a below ground source (e.g., other controllers on other actuators through the extraction system 10). The controller 166 may further send a signal to the electric drive 162 to actuate the sleeve 128 to an open position (e.g., uncovering position, non- occluding position) based on a detected parameter, a signal from a above ground source, and / or a signal from a below ground source. Indeed, as will be discussed further below, the controller 166 may communicate with the electric drive 162 to actuate the sleeve 128 to any desired position based on predictive algorithms performed within the controller 166 or another controller (e.g., a controller of another FCV) of the extraction system 10.

[0035] In some embodiments, the actuator 154 may include a monitoring system 170 communicatively coupled to the controller 166 and configured to detect one or more parameters of the extraction system 10. For example, the monitoring system 170 may include one or more sensors configured to detect one or more properties of the subterranean fluid (e.g., subterranean fluid flow) within the extraction system 10 (e.g., within the string 124IS23.0163-WO-PCT and / or downhole assembly), and / or one or more properties of the subterranean fluid outside of the extraction system 10. In some embodiments, the monitoring system 170 may include sensors configured to detect temperature, pressure, and / or vibrations associated with the subterranean fluid 110 flow internal and / or external to the extraction system 10. In some embodiments, the electric drive 162, the controller 166, and the monitoring system 170 may be disposed on the same PCB board of the actuator 154 and within the same housing on the extraction system 10.

[0036] In some embodiments, the controller 166 may be configured to instruct the electric drive 162 based on one or more predictive algorithms (e.g., health prediction algorithms) performed within the controller 166 (e.g., a processor of the controller 166). For example, upon receiving a signal from the monitoring system 170 indicative of one or more detected properties (e.g., temperature, pressure, and / or vibrations), the controller 166 may perform one / or more predictive algorithms based on the one or more detected properties. That is, the controller 166 may input the parameters of the signal into the algorithm alone or along with other variable or fixed parameters within the extraction system 10. Upon performing the one / or more predictive algorithms, the controller 166 may instruct the electronic drive 162 to translate the sleeve 128 to a desired position, based on the result of the one or more predictive algorithms.

[0037] In some embodiments, the monitoring system 170 may be configured to detect one or more properties of the subterranean fluid 110 flow at a location offset from the point of detection, such as, at the choke 122. That is, the actuator 154, and the monitoring system 170 within the actuator 154, may be offset from the choke 122 by a distance 174 defined by a first location 178 indicative of the subterranean fluid 110 flow within the extraction system 10 proximate the monitoring system 170 and a second location 182 indicative of the subterranean fluid 110 flow within the extraction system 10 proximate to the intake of the choke 122. As will be appreciated, one or more properties of the subterranean fluid 110 flow at the second location 182 (e.g., choke 122 location) may be desired to obtain subterranean fluid 110 flow characteristics at the choke 122. Advantageously, in some embodiments, the controller 166 may be configured to determine or predict one or more properties ofIS23.0163-WO-PCT subterranean fluid 110 flow at the second location 182 based on the detected data obtained from the monitoring system 170 at the first location 178.

[0038] For example, the monitoring system 170 may detect vibrations 188 (e.g., frequency) of the subterranean fluid 110 flow at the first location 178, proximate to the monitoring system 170. The monitoring system 170 may then send or otherwise communicate with the controller 166 a signal indicative of the detected vibrations 188 where the controller 166 may then predict the vibrations of the subterranean fluid 110 flow at the second location 182 proximate the intake of the choke 122, based on the detected vibrations 188. Specifically, the controller 166 may performed one or more algorithms utilizing the detected vibrations 188 and optionally the distance 174 to predict the vibrations of the subterranean fluid 110 flow at the second location 182. In this way, the controller 166 may perform one or more predictive algorithms using the determined or predicted vibrations of the second location 182 to predict one or more downhole conditions at the choke 122 or a location near the choke 122. In certain embodiments, the one or more predictive algorithms may include computer models of vibrations passing through certain mediums, such as various characteristics of the well fluids (e.g., oil, water, gas, etc.), materials used in the construction of the equipment (e.g., string, choke 122, etc.), or any combination thereof. The various characteristics of the well fluids may include a fluid composition, a temperature, a pressure, a flow rate, a direction of flow, or any combination thereof, of the well fluids. The materials used in the equipment may change the vibrations differently depending on the material composition, wall thickness, geometry, etc. The one or more predictive algorithms may include computer models of fluid flows causing vibrations, computer models of the equipment including the choke, historical data of vibration versus various operating parameters, testing data of vibration in the equipment, or any combination thereof.

[0039] FIG.4 is a schematic portrayal of an actuator 154 that may be used in any of the systems of FIGS.1-3 with an FCV 123 (e.g., an electric flow control valve). As discussed above, the actuator 154 may include an electric drive 162 configured to linearly translate a piston to position a sleeve in various locations relative to a choke, thereby controlling flow of fluid into the extraction system (e.g., extraction system 10). The electric drive 162 mayIS23.0163-WO-PCT be communicatively coupled to the controller 166, configured to receive one or more signals from the controller 166 indicative of a call or control signal to position the sleeve 128. For example, upon receiving a call to enable subterranean fluid flow to enter the string and / or downhole assembly, the controller 166 may send a signal to the electric drive 162 to translate (e.g. linearly translation) the piston in a first direction to move the sleeve away from the choke, to at least partially uncover the choke, enabling fluid flow into the extraction system. Further, upon receiving a call to disable subterranean fluid flow from entering the string and / or downhole assembly, the controller 166 may send a signal to the electric drive 162 to translate (e.g. linearly translate) the piston in a second direction to move the sleeve towards the choke, to at least partially cover the choke, reducing fluid flow into the extraction system. Although the electric drive 162 is discussed as pertaining to a piston and a sleeve of an electric FCV, it should be appreciated that the methods and systems described herein may be applied to other FCVs (e.g., hydraulic flow control valves, hybrid flow control valves), ball valves, gate valves, blowout preventers, and / or any other suitable flow control device.

[0040] To facilitate control of one or more components of the FCV 123, the controller 166 may include a memory 186 with instructions stored thereon for controlling operation of the FCV 123 and components of the FCV 123 (e.g., actuator 154). The controller 166 may also include a processor 190 (e.g., processing circuitry) configured to execute instructions stored on the memory 186. For example, the processor 190 may include one or more application specific integrated circuits (ASICs), one or more field programmable gate arrays (FPGAs), one or more general purpose processors, or any combination thereof. Additionally, the memory 186 may include a non-transitory computer-readable medium that may include volatile memory, such as random-access memory (RAM), and / or non-volatile memory, such as read-only memory (ROM), optical drives, hard disc drives, solid-state drives, or any other suitable non-transitory computer-readable medium storing instructions that, when executed by the processor 190, may control operation of the actuator 154.

[0041] Additionally, the actuator 154 may include the monitoring system 170 communicatively coupled to the controller 166 and configured to communicate one or more signals indicative of a detected property of the subterranean fluid to controller 166. TheIS23.0163-WO-PCT controller 166 may then send a signal to operate the electric drive based on the detected property received from the monitoring system 170. For example, the monitoring system 170 may include, among others, a vibration sensor 194, a temperature sensor 198, and / or a pressure sensor 202 each configured to detect a property (e.g., vibration, temperature, and pressure) of the subterranean fluid within the string and / or downhole assembly of the system. Although three sensors are illustrated (e.g., vibration sensor 194, temperature sensor 198, pressure sensor 202), it should be appreciated that any number and type of sensors may be used within the actuator 154. In some embodiments, one or more sensors 194, 198, 202 may be integrated into the same PCB (e.g., printed circuit board) as the controller 166 and electric drive 162. For example, one or more sensors 194, 198, 202 may be MEMS (Microelectromechanical systems) based and arranged at various locations on a common PCB board with the controller 166, the electric drive 162, and other components of the FCV 123. In some embodiments, the sensors 194, 198, 202 may be positioned at different distances relative to the intake of the choke of the FCV. For example, in some embodiments, the vibration sensor 194 may be disposed at a first distance relative to the intake of the choke, and the pressure sensor may be disposed at a second distance relative to the intake of the choke, and the first distance may be greater than the second distance.

[0042] The vibration sensor 194 may be configured to detect vibrations 206 of the subterranean fluid flow within the extraction system (e.g., string 124 and downhole assembly 100) and / or external to the extraction system (e.g., wellbore, subterranean formation). For example, the vibration sensor 194 may be an accelerometer configured to receive a vibrational force from the subterranean fluid which may produce an electrical signal that is proportional to the force. The signal may then be communicated to the controller 166 to be converted into a detected vibration that may be used by the controller 166 to determine and / or predict a downhole condition. In some embodiments, upon receiving the detected vibrations 206 (e.g., detected by the vibration sensor 194) of the subterranean fluid, the controller 166 may perform one or more predictive algorithms to predict a downhole condition. For example, the controller 166 may include one or more predictive algorithms stored within memory 186 of the controller 166. Upon receiving a call to determine and / or predict a downhole condition, the processor 190 may perform the one or more predictive algorithmsIS23.0163-WO-PCT within the memory 186 to determine and / or predict a downhole condition based on the detected vibrations 206. Based on the result of the one or more predictive algorithms, the controller 166 may send a signal to the electric drive 162 to translate the sleeve to a desired position (e.g., open, closed, partially open) relative the choke, thereby regulating fluid flow into the extraction system. For example, upon determining and / or predicting a downhole condition that may result in damage to the actuator 154, based on the detected vibrations 206, the controller 166 may signal the electric drive 162 to position the sleeve to occlude or at least partially occlude the choke, reducing and / or preventing localized flow into the extraction system. In this way, the FCV 123 (e.g., controller 166 of the FCV) may maintain a desired subterranean fluid flow condition within the extraction system, reducing damage to the electric components of the system (e.g., actuator 154).

[0043] In some embodiments, based on the detected vibrations 206 and / or the result of the one or more predictive algorithms performed by the controller 166, the controller 166 may send a signal to an above ground operator 210. For example, upon receiving the signal indicative of the detected vibration 206 from the vibration sensor 194, the controller 166 may send a signal to the operator alerting the operator of the downhole condition. Similarly, upon determining and / or predicting a downhole condition based on performing one or more predictive algorithms utilizing the detected vibrations 206, the controller 166 may send a signal to the operator alerting the operator 210 of the downhole condition. The signal may include displaying on a graphical display a notification alerting the operator 210 of the downhole condition, such as a warning display. Further, the signal may include presenting one or more actuation options, on a graphical display, to the operator 210. The actuation options may include, among others, an option to position the sleeve in an occluding position over the choke, an uncovering position over the choke, or a partially covering potion over the choke.

[0044] In some embodiments, the controller 166 may be a first controller and the controller 166 may be configured to send a signal to second controller 214 based on the detected vibrations 206 and / or the result of the one or more predictive algorithms performed by the controller 166 using the detected vibrations 206. For example, the second controllerIS23.0163-WO-PCT 214 may be a controller of a second FCV disposed in the same extraction system (e.g., on the same string and / or of the same downhole assembly). Upon receiving the signal from the controller 166, the second controller 214 may perform one or more actions based on the signal. For example, upon receiving a signal from the controller 166 indicative of a downhole condition near a first FCV, the second controller 214 may instruct a respective electric drive of a second FCV to regulate the subterranean fluid flow into the extraction system. In this way, the extraction system may maintain and / or regulate subterranean fluid flow in an expedited manner, based on the detected vibrations, determined downhole conditions, and / or predicted downhole conditions. As such, damage to the components (e.g., actuator) of the extraction system may be reduced. Although the second controller 214 is discussed as pertaining to the second FCV, it should be appreciated that the second controller 214 may be of any component of the extraction system, such as, a pump, a blowout preventer, a gauge, and / or any other suitable component.

[0045] As discussed above, the controller 166 may further predict a vibration associated with a location proximate the choke intake. That is, upon receiving the detected vibrations 206 (e.g., detected by the vibration sensor 194) of the subterranean fluid flow at the detection location (e.g., at the vibrational sensor 194), the controller 166 may perform one or more conversion algorithms to predict subterranean fluid vibrations proximate the intake of the choke. For example, the vibration sensor 194 may be offset from the intake of the choke such that the detected vibrations 206 may not be indicative of vibrations proximate to the intake of the choke. The controller 166 may include one or more conversion algorithms stored within memory 186 of the controller 166 configured to convert (e.g., predict, adjust) the detected vibrations 206 to vibrations proximate the intake of the choke. Upon receiving a call to determine and / or predict vibrations at the intake of the choke, the processor 190 of the controller 166 may perform the one or more conversion algorithms within the memory 186 to determine and / or predict vibrations at or proximate the intake of the choke, based on the detected vibrations 206 and / or a distance between the vibration sensor 194 location and the location of the intake of the choke. Upon determining the vibrations at the intake of the choke, the controller 166 may perform one or more predictive algorithms based on the determined vibrations to determine or predict one or more downhole conditions at the intakeIS23.0163-WO-PCT of the choke. In some embodiments, based on the determined vibrations at the intake of the choke, and / or the predicted downhole conditions, the controller 166 may send a signal to the electric drive 162 to translate the sleeve to a desired position (e.g., open, closed, partially open) relative the choke to regulate fluid flow into the extraction system.

[0046] In some embodiments, the controller 166 may include artificial intelligence (AI) configured to implement machine learning, such as convolutional neural network (CNN) techniques. When enabled in the controller 166, the artificial intelligence may analyze input (e.g., source) data (e.g., detected sensor data) to determine expected downhole conditions, such as subterranean fluid turbulent flow, gas slugging, solids ingress, formation fracturing and other conditions. For example, upon receiving the detected vibrations 206, and / or the determined vibrations proximate the intake to the choke, the AI of the controller 166 may determine expected or predicted downhole conditions based on the detected vibrations 206, and / or the determined vibrations proximate the intake to the choke. In some embodiments, the AI may determine downhole conditions based on both the detected vibrations 206 and the determined vibrations at the intake of the choke (e.g., determined from the conversion algorithms.)

[0047] To facilitate identifying downhole conditions, the AI may be trained to determine and implement machine learning parameters. For example, when the AI implements convolutional neural network (CNN) techniques, the machine learning parameters may indicate number of convolution layers, inter-connections between layers, and / or convolution weights (e.g., coefficients) corresponding to each convolution layer. In some embodiments, the AI may be trained by recursively adjusting the machine learning parameters based at least in part on expected downhole conditions identified by processing (e.g., analyzing) training data, for example, with known sensor data and / or downhole condition data.

[0048] As discussed above, the actuator 154 may include a temperature sensor 198 in addition or alternative to the vibration sensor 194. The temperature sensor 198 may be MEMS based and integrated on the same PCB board as the controller 166, the electric drive 162, and the other sensors 194, 198, 202. As will be appreciated the actuator 154 may be configured to perform similar determinations and / or predictions as discussed above for theIS23.0163-WO-PCT vibration sensor 194. That is, the controller 166 may be configured to receive a signal indicative of a temperature of the subterranean fluid (e.g., detected temperature 218) within the extraction system (e.g., the string, downhole assembly). Further, the controller 166 may perform one or more predicative algorithms to determine a downhole condition based on the detected temperature 218. In some embodiments, the controller 166 may be configured to perform conversion algorithms to determine a temperature of the subterranean fluid near or proximate the intake of the choke, in a manner similar to that discussed above. Further, the AI within the controller 166 may be configured to analyze the detected temperature 218 and / or the temperature of the subterranean fluid near or proximate the intake of the choke to determine expected downhole conditions, in a manner similar to that discussed above. Based on the detected temperature 218, the determined temperature at the intake of the choke, a determined downhole condition, and / or a predicted downhole condition, the controller 166 may communicate with the electric drive 162 to actuate the sleeve of the FCV to a desired position (e.g., closed, open, partially open) relative the choke.

[0049] As discussed above, the actuator 154 may include pressure sensor 202 in addition or alternative to the vibration sensor 194 and / or the temperature sensor 198. The pressure sensor 202 may be MEMS based and integrated on the same PCB board as the controller 166, the electric drive 162, and the other sensors 194, 198. As will be appreciated the actuator 154 may be configured to perform similar determinations and / or predictions as discussed above for the vibration sensor 194 and temperature sensor 198. That is, the controller 166 may be configured to receive a signal indicative of a pressure of the subterranean fluid flow (e.g., detected pressure 222) within the extraction system (e.g., the string, downhole assembly). Further, the controller 166 may perform one or more predicative algorithms to determine a downhole condition based on the detected pressure 222. In some embodiments, the controller 166 may be configured to perform conversion algorithms to determine pressure of the subterranean fluid flow near or proximate the intake of the choke, in a manner similar to that discussed above. Further, the AI within the controller 166 may be configured to analyze the detected pressure 222 and / or the pressure of the subterranean fluid flow near or proximate the intake of the choke to determine expected downhole conditions, in a manner similar to that discussed above. Based on the detected pressure 222, the determined pressureIS23.0163-WO-PCT at the intake of the choke, a determined downhole condition, and / or a predicted downhole condition, the controller 166 may communicate with the electric drive 162 to actuate the sleeve of the FCV to a desired position (e.g., closed, open, partially open) relative the choke.

[0050] Although detecting and analyzing vibrations, temperature, and pressure are discussed independent of each other, it should be appreciated that any of the above methods may include analyzing two or more detected properties of the subterranean fluid in combination. For example, the controller 166 may receive a first signal indicative of the detected vibrations 206 and a second signal indicative of the detected temperature 218, where then the controller 166 may perform one or more predictive algorithms to determine one or more downhole conditions based on both the detected vibrations 206 and the detected temperature 218. In some embodiments, the controller 166 may perform one or more conversion algorithms for each respective detected property (e.g., detected vibrations 206, detected temperature 218, detected pressure 222) to determine each property value at the intake of the choke or another offset location from the detection location. With the determined property value at the intake of the choke or another offset location, the controller 166 may then perform one or more predictive algorithms, and / or may execute machine learning to determine or predict a downhole condition. In certain embodiments, a combination of two or more measured properties (e.g., detected vibrations 206, detected temperature 218, detected pressure 222) may be used to predict various downhole conditions in the wellbore, the choke, in the subterranean formation, or anywhere at the wellsite. For example, certain combinations of vibration, temperature, and pressure may be indicative of certain fluid flows (e.g., fluid composition, such as water content, salinity, oil content, gas content, etc.), fractures, damage to equipment, or any combination thereof. In certain embodiments, the measured properties (e.g., detected vibrations 206, detected temperature 218, detected pressure 222) may be used specifically to monitor and control fluid flows at the choke (or any other type of valve), thereby improving performance of the valve, reducing wear of the valve, and improving safety at the wellsite.

[0051] As is used in the present disclosure, a downhole condition may include, but is not limited to, one or more physical properties (e.g., compositions) of subterranean fluid flowIS23.0163-WO-PCT through the extraction system (e.g., the string, the downhole assembly), one or more physical properties of the subterranean fluid flow external to the system (e.g., within the subterranean formation, within the wellbore but outside of the extraction system), fluid flow characteristics (e.g., flow rate), gas slugging, turbulent flow, solids ingress (e.g., solids flow rate) into the extraction system, subterranean formation fractures, mechanical failures of the extraction system or components of the extraction system, and / or corrosion of components of the extraction system.

[0052] FIG.5 illustrates a flow diagram for a process 300 of actuating a valve (e.g., FCV) based on detected subterranean fluid flow properties. At block 304, one or more sensors (e.g., vibration sensor 194, temperature sensor 198, pressure sensor 202) may detect one or more properties of subterranean fluid through an extraction system (e.g., extraction system 10). The sensors may then communicate to a controller (e.g., controller 166) a signal indicative of the detected subterranean fluid property (e.g., detected vibrations 206, detected temperature 218, detected pressure 222).

[0053] At block 308, the controller may perform signal conditioning of the signal received from the one or more sensors. For example, the controller may include a signal conditioning module that is configured to perform one or more conditioning techniques on the one or more signals received by the sensors indicative of a detected subterranean fluid property. That is, the signal conditioning module may amplify the received signal, filter the signal to reduce undesired interferences (e.g., noise), linearize the signal, isolate the signal, convert the signal into a digital form for processing in a processor of the controller, and / or other suitable filtering steps.

[0054] At block 312, the controller may perform one or more algorithms (e.g., conversion algorithms) to determine a subterranean fluid property (e.g., determined property) at a location near or proximate to the intake of the choke. For example, the controller may perform one or more algorithms to adjust the signal indicative of the detected subterranean fluid property to account for the distance between the detection location and the intake of the choke. Specifically, the one or more algorithms may adjust one or more signal characteristics (e.g., amplitude, phase characteristics) to compensate for the distance between the detectionIS23.0163-WO-PCT location (e.g., sensor location) and the intake of the choke and the medium of communication (e.g., physical medium, electrical medium).

[0055] At block 314, the controller may perform one or more predictive algorithms (e.g., health prediction algorithm) to assess the impact of the subterranean fluid flow property (e.g., vibration, temperature, and / or pressure) on the extraction system. That is, the one or more predictive algorithms may utilize the one or more determined properties (e.g., vibrations, temperature, and / or pressure) to predict a downhole condition, such as, erosion of one or more components of the extraction system, gas slugging, fluid flow, mechanical damage of one or more components of the extraction system, and / or other downhole conditions. In some embodiments, the predictive algorithm may be at least partially based on historical data indicative of one or more previous subterranean fluid properties and / or historical data indicative of one or more previous downhole conditions.

[0056] At block 318, the controller may notify a process control element of a determination based on the result of the predicative algorithm discussed above in block 314. In some embodiments, the process control element may be an above ground operator (e.g., human operator). That is, upon a determination based on the predicative algorithm discussed in block 314, the controller may communicate to an above ground operator a notification that may include a visual and / or audio alerts, one or more actuation options, and / or other notification options. That is, the controller may send a signal to a display (e.g., graphical display) of the operator to display a visual alert and / or actuation options. In some embodiments, the process control element may be an automated system configured to perform one or more automated actions, such as, actuating the valve. In some embodiments, the controller may notify or otherwise communicate with both the above ground operator and the automated system upon determining the result of the predictive algorithm. In some embodiments, the process control element may be a second controller controlling another component of the extraction system.

[0057] At block 322, the controller may send a signal to an electric drive of an actuator to actuate a valve, based on the result of the predictive algorithm. For example, the valve may be an FCV, and the electric drive may be configured to actuate a sleeve of the FCVIS23.0163-WO-PCT based on a downhole condition as predicted or determined by the predictive algorithm. That is, upon determining (e.g., based on the predictive algorithm) that a downhole condition is present or will be present, the controller may send a signal to the electric drive to actuate the sleeve to a desired location (e.g., occluding the choke, uncovering the choke, partially covering the choke). For example, upon determining a downhole condition that may be harmful to one or more electric components within the system (e.g., the controller), the controller may send a signal to the electric drive to actuate the sleeve to occlude, or at least partially occlude, one or more holes of the choke. In this way, subterranean fluid flow into the system may be reduced and / or prevented, reducing hard to the electric components of the system and improving electrical operation. It should be noted that although actuation of the valve is discussed as at least partially based on the predictive algorithm and / or a downhole condition, it will be appreciated the valve may be actuated under other instances, for example, to maintain or increase a desired subterranean fluid flow through the extraction system.

[0058] FIG.6 illustrates a flow diagram for a process 400 of actuating a valve (e.g., FCV) based on detected subterranean fluid properties. For example, at block 404, a controller (e.g., controller 166) may receive a signal indicative of a subterranean fluid property (e.g., subterranean fluid flow property) from one or more sensors. That is, one or more sensors (e.g., vibration sensor 194, temperature sensor 198, pressure sensor 202) may detect one or more properties of subterranean fluid through the extraction system. The sensors may then communicate to a controller (e.g., controller 166) a signal indicative of the detected subterranean fluid property (e.g., detected vibrations 206, detected temperature 218, detected pressure 222).

[0059] At block 408, the controller may select an algorithm and / or build an AI model based on the signal received from the sensors. That is, the controller may include memory which may comprise one or more algorithms to be performed by a processor of the controller. Based on the signal (e.g., signal indicative of the detected subterranean fluid property) and / or based on the desired determination, the controller may select and / or build an AI. For example, upon receiving a signal indicative of a detected vibration, the controller my select a predictive algorithm based on vibrations and configured to determine and / or predict aIS23.0163-WO-PCT likelihood of turbulent flow of the subterranean fluid. As another example, upon receiving a signal indicative of a detected vibration, the controller may select a predictive algorithm based on vibrations and configured to determine and / or predict a likelihood of an undesired flow rate of solids into the extraction system (e.g., string, downhole assembly), through a valve.

[0060] In some instances, the controller may select an algorithm and / or build an AI configured to convert (e.g., adjust) the signal to a second signal indicative of the subterranean fluid flow property at a location proximate the intake of the valve (e.g., eFCV). That is, upon receiving a signal indicative of a detected vibration, the controller may select a conversion algorithm based on vibrations and configured to determine and / or predict vibrations (e.g., an amount of vibrations) at a location proximate or near the intake of a valve. In some embodiments, the controller may select algorithms and or build AI models based on more than one subterranean fluid property. For example, upon receiving a signals indicative of a detected vibration and a detected temperature, the controller may select a predictive algorithm based on vibrations and temperature and configured to determine and / or predict a likelihood of a undesired flow rate of solids into the system (e.g., string, downhole assembly), through a valve.

[0061] At block 412, the controller may perform the selected algorithm as discussed in block 408 and / or may train the selected AI model. For example, upon selection of an algorithm, the controller may input the necessary parameters (e.g., subterranean fluid properties (e.g., vibrations, temperature, pressure), distance) into the selected algorithm to perform a determination and / or prediction. In embodiments employing AI models, the controller may train the AI model, for example, by using historical data from the subterranean fluid properties, downhole condition data, or other historical data.

[0062] As a result of performing the selected algorithm and / or training the selected AI model, the controller may determine and / or predict a downhole condition, such as, erosion of one or more components of the extraction system, gas slugging, fluid flow, mechanical damage of one or more components of the extraction system, and / or other downhole conditions.IS23.0163-WO-PCT

[0063] At block 420, the controller may send one or more signals to various elements to perform one or more actions based on the result of the predictive algorithm and / or AI model. For example, the controller may notify an operator of the result, such as, displaying a warning and / or displaying one or more actuation options. Further, the controller may send a signal to an electric drive of an actuator to actuate a valve, based on the result of the predictive algorithm and / or the AI model. For example, the valve may be an FCV, and the electric drive may be configured to actuate a sleeve of the FCV based on a downhole condition as predicted or determined by the predictive algorithm and / or AI model.

[0064] Technical effects of the embodiments described above include temperature, pressure, and / or vibration measurements in proximity to a valve (e.g., choke) in a downhole environment, enabling improved operating of the valve and various downhole equipment. The measurements may be taken at a distance from the valve, such as in a housing having electronics and / or a controller for the actuator of the valve, while a predictive algorithm may be used to predict values of the measurements at the valve and / or elsewhere in the downhole environment. The measurements may be used to determine or predict various downhole conditions, such as gas slugging, turbulent flow, solids ingress, erosion, mechanical damage, or any combination thereof.

[0065] The subject matter described in detail above may be defined by one or more clauses, as set forth below.

[0066] A method for valve actuation includes detecting, via a sensor, a subterranean fluid property at a location near to the sensor, sending a first signal to a controller, where the first signal is indicative of the subterranean fluid property at the location proximate to the sensor, and converting the first signal into a second signal, where the second signal is indicative of a subterranean fluid property at a location near a valve. The method further includes determining a downhole condition based on the second signal and actuating the valve based on the downhole condition.IS23.0163-WO-PCT

[0067] The method of any preceding clause, where the valve is an electronic flow control valve comprising a sleeve and a choke, where actuating the valve comprises linearly translating the sleeve to move between an open position and a closed position of the choke.

[0068] The method of any preceding clause, where converting the first signal to the second signal comprises inputting the first signal into a conversion algorithm of the controller, where the conversion algorithm is configured to produce the second signal based at least on the first signal.

[0069] The method of any preceding clause, where converting the first signal to the second signal comprises inputting a distance into the conversion algorithm, where the distance is a distance between the sensor and the valve.

[0070] The method of any preceding clause, where the sensor is a vibration sensor and the subterranean fluid property is a vibration.

[0071] The method of any preceding clause, where determining the downhole condition comprises inputting the second signal into a predictive algorithm of the controller.

[0072] The method of any preceding clause, comprising inputting historical subterranean fluid property data, historical downhole condition data, or a combination therefore, into the predictive algorithm.

[0073] The method of any preceding clause, where the downhole condition is a flow rate of the subterranean fluid, gas slugging, flow rate of one or more solids through the valve, turbulent flow of the subterranean fluid, or fracturing of a subterranean formation.

[0074] The method of any preceding clause, where the downhole condition is a damaging condition to the controller.

[0075] The method of any preceding clause, comprising sending a notification to an above ground operator based on the downhole condition.IS23.0163-WO-PCT

[0076] The method of any preceding clause, where the notification comprises displaying an alert on a graphical display or displaying one or more actuation options of the valve on the graphical display.

[0077] A system for fluid flow regulation includes a wellbore system that may be inserted into a wellbore to extract fluid from the wellbore and a valve disposed at a first location on the wellbore system, where the valve may regulate fluid flow from the wellbore into the wellbore system. The system further may include a sensor disposed at a second location on the wellbore system, where the second location is downstream of the first location relative to a direction of fluid flow and where the sensor is configured to detect a fluid property at the second location. The system further may include a controller configured to, receive a first signal indicative of the fluid property at the second location, convert the first signal to a second signal indicative of a fluid property at the first location, determine a downhole condition based on the second signal, and actuate the valve based on the downhole condition.

[0078] The system of any preceding clause, where the valve is an electronic flow control valve comprising: a choke configured to enable fluid communication between the wellbore and the wellbore system, a sleeve configured to be positioned relative to the choke to regulate a flow of fluid into the wellbore system from the wellbore, and an actuator comprising and electric drive configured to linearly translate the sleeve in a first direction to cover the choke and a second direction to uncover the choke.

[0079] The system of any preceding clause, where converting the first signal to the second signal comprises inputting the first signal into a conversion algorithm, where the conversion algorithm is based at least partially on the first location and the second location.

[0080] The system of any preceding clause, where determining the downhole condition comprises inputting the second signal into a predictive algorithm, where the predictive algorithm is at least partially based on historical fluid property data.IS23.0163-WO-PCT

[0081] The system of any preceding clause, where the sensor is a microelectromechanical systems (“MEMS”) based sensor, where the sensor is positioned on a printed circuit board with the controller.

[0082] A method for valve actuation includes detecting, via a sensor, a first subterranean fluid property at a location proximate to the sensor, sending a first signal to a controller, where the first signal is indicative of the first subterranean fluid property at the location proximate to the sensor and converting the first signal into a second signal, where the second signal is indicative of the first subterranean fluid property at a location proximate an electronic flow control valve. The electronic flow control valve may include a choke configured to enable fluid communication between a wellbore and a wellbore system, where the electronic flow control valve comprises a sleeve configured to cover and uncover the choke. The method further includes actuating the sleeve of the electronic flow control valve to cover and uncover the choke based on the second signal.

[0083] The method of any preceding clause, where the sensor is a first sensor, where the method comprises detecting, via a second sensor, a second subterranean fluid property at the location proximate the sensor, sending a third signal to the controller, wherein the third signal is indicative of the second subterranean fluid property at the location proximate the sensor, converting the third signal into a fourth signal, wherein the fourth signal is indicative of the second subterranean fluid property at the location proximate the electronic flow control valve, and actuating the sleeve of the electronic flow control valve to cover and uncover the choke based on the second signal and the fourth signal.

[0084] The method of any preceding clause, where the first sensor is a vibration sensor, the second sensor is a temperature sensor, the first subterranean fluid property is a vibration and the second subterranean fluid property is a temperature.

[0085] The method of any preceding clause, wherein converting the first signal into the second signal comprises inputting the first signal into a predictive algorithm.IS23.0163-WO-PCT

[0086] The foregoing description, for purpose of explanation, has been described with reference to specific embodiments. However, the illustrative discussions above are not intended to be exhaustive or to limit the disclosure to the precise forms disclosed. Many modifications and variations are possible in view of the above teachings. Moreover, the order in which the elements of the methods described herein are illustrated and described may be re-arranged, and / or two or more elements may occur simultaneously. The embodiments were chosen and described in order to best explain the principals of the disclosure and its practical applications, to thereby enable others skilled in the art to best utilize the disclosure and various embodiments with various modifications as are suited to the particular use contemplated.

[0087] Finally, the techniques presented and claimed herein are referenced and applied to material objects and concrete examples of a practical nature that demonstrably improve the present technical field and, as such, are not abstract, intangible or purely theoretical. Further, if any claims appended to the end of this specification contain one or more elements designated as “means for [perform]ing [a function]…” or “step for [perform]ing [a function]…”, it is intended that such elements are to be interpreted under 35 U.S.C.112(f). However, for any claims containing elements designated in any other manner, it is intended that such elements are not to be interpreted under 35 U.S.C.112(f).

Claims

IS23.0163-WO-PCT CLAIMS 1. A method for valve actuation, the method comprising: detecting, via a sensor, a subterranean fluid property at a location proximate to the sensor; sending a first signal to a controller, wherein the first signal is indicative of the subterranean fluid property at the location proximate to the sensor; converting the first signal into a second signal, wherein the second signal is indicative of a subterranean fluid property at a location proximate a valve; determining a downhole condition based on the second signal; and actuating the valve based on the downhole condition.

2. The method of claim 1, wherein the valve is an electronic flow control valve comprising a sleeve and a choke, wherein actuating the valve comprises linearly translating the sleeve to move between an open position and a closed position of the choke.

3. The method of claim 1, wherein converting the first signal to the second signal comprises inputting the first signal into a conversion algorithm of the controller, wherein the conversion algorithm is configured to produce the second signal based at least on the first signal.

4. The method of claim 3, wherein converting the first signal to the second signal comprises inputting a distance into the conversion algorithm, wherein the distance is a distance between the sensor and the valve.

5. The method of claim 1, wherein the sensor is a vibration sensor and the subterranean fluid property is a vibration.

6. The method of claim 1, wherein determining the downhole condition comprises inputting the second signal into a predictive algorithm of the controller.IS23.0163-WO-PCT 7. The method of claim 6, comprising inputting historical subterranean fluid property data, historical downhole condition data, or a combination therefore, into the predictive algorithm.

8. The method of claim 1, wherein the downhole condition is a flow rate of the subterranean fluid, gas slugging, flow rate of one or more solids through the valve, turbulent flow of the subterranean fluid, or fracturing of a subterranean formation.

9. The method of claim 1, wherein the downhole condition is a damaging condition to the controller.

10. The method of claim 1, comprising sending a notification to an above ground operator based on the downhole condition.

11. The method of claim 10, wherein the notification comprises displaying an alert on a graphical display or displaying one or more actuation options of the valve on the graphical display.

12. A system for fluid flow regulation, the system comprising: a wellbore system configured to be inserted into a wellbore to extract fluid from the wellbore; a valve disposed at a first location on the wellbore system, wherein the valve is configured to regulate fluid flow from the wellbore into the wellbore system; a sensor disposed at a second location on the wellbore system, wherein the second location is downstream of the first location relative to a direction of fluid flow, wherein the sensor is configured to detect a fluid property at the second location; and a controller configured to: receive a first signal indicative of the fluid property at the second location;IS23.0163-WO-PCT convert the first signal to a second signal indicative of a fluid property at the first location; determine a downhole condition based on the second signal; and actuate the valve based on the downhole condition.

13. The system of claim 12, wherein the valve is an electronic flow control valve comprising: a choke configured to enable fluid communication between the wellbore and the wellbore system; a sleeve configured to be positioned relative to the choke to regulate a flow of fluid into the wellbore system from the wellbore; and an actuator comprising and electric drive configured to linearly translate the sleeve in a first direction to cover the choke and a second direction to uncover the choke.

14. The system of claim 12, wherein converting the first signal to the second signal comprises inputting the first signal into a conversion algorithm, wherein the conversion algorithm is based at least partially on the first location and the second location.

15. The system of claim 12, wherein determining the downhole condition comprises inputting the second signal into a predictive algorithm, wherein the predictive algorithm is at least partially based on historical fluid property data.

16. The system of claim 12, wherein the sensor is a microelectromechanical systems (“MEMS”) based sensor, wherein the sensor is positioned on a printed circuit board with the controller.

17. A method for valve actuation, the method comprising: detecting, via a sensor, a first subterranean fluid property at a location proximate to the sensor;IS23.0163-WO-PCT sending a first signal to a controller, wherein the first signal is indicative of the first subterranean fluid property at the location proximate to the sensor; converting the first signal into a second signal, wherein the second signal is indicative of the first subterranean fluid property at a location proximate an electronic flow control valve, wherein the electronic flow control valve comprises a choke configured to enable fluid communication between a wellbore and a wellbore system, wherein the electronic flow control valve comprises a sleeve configured to cover and uncover the choke; and actuating the sleeve of the electronic flow control valve to cover and uncover the choke based on the second signal.

18. The method of claim 17, wherein the sensor is a first sensor, wherein the method comprises: detecting, via a second sensor, a second subterranean fluid property at the location proximate the sensor; sending a third signal to the controller, wherein the third signal is indicative of the second subterranean fluid property at the location proximate the sensor; converting the third signal into a fourth signal, wherein the fourth signal is indicative of the second subterranean fluid property at the location proximate the electronic flow control valve; and actuating the sleeve of the electronic flow control valve to cover and uncover the choke based on the second signal and the fourth signal.

19. The method of claim 18, wherein the first sensor is a vibration sensor, the second sensor is a temperature sensor, the first subterranean fluid property is a vibration and the second subterranean fluid property is a temperature.

20. The method of claim 17, wherein converting the first signal into the second signal comprises inputting the first signal into a predictive algorithm.

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