Variable flow resistance system for use with subterranean wells

Abstract

A variable flow resistance system for use with a subterranean well includes a first flow path configured to receive a fluid; a sensor configured to measure a property of the fluid received into the first flow path; and an actuator configured to control an inflow amount of the fluid received into the first flow path based on the property of the fluid measured by the sensor.

Description

[0001] This application is a divisional application of the invention patent application with application number 2016800902065, invention name “Variable flow resistance system for use with underground wells” and application date of November 18, 2016. Background Art

[0002] This section is intended to introduce the reader to various aspects of the technology that may be related to various aspects of the presently described embodiments. 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 embodiments of the present invention. Therefore, it should be understood that these statements should be understood in this light and not as admissions of prior art.

[0003] The present disclosure relates generally to equipment used in conjunction with, and operations performed in conjunction with, subterranean wells and, in the examples described below, more particularly provides a selectively variable flow restrictor.

[0004] In hydrocarbon production wells, it is often beneficial to be able to regulate the flow of fluids from the formation into the wellbore, from the wellbore into the formation, and within the wellbore. Such regulation can be used for a variety of purposes, including preventing water or gas coning, minimizing sand production, minimizing water and / or gas production, maximizing oil production, balancing production between zones, transmitting signals, etc.

[0005] It will be appreciated, therefore, that advances in technology for variably restricting the flow of fluids in a well would be desirable in the circumstances noted above, and that such advances would also be beneficial in a wide variety of other circumstances. BRIEF DESCRIPTION OF THE DRAWINGS

[0006] Illustrative embodiments of the present disclosure are described in detail below with reference to the accompanying drawings, which are incorporated herein by reference and in which:

[0007] Figure 1 A schematic diagram illustrating a well system including a variable flow resistance system according to one or more embodiments of the present disclosure;

[0008] Figure 2 A schematic diagram illustrating a variable flow resistance system according to one or more embodiments of the present disclosure;

[0009] Figure 3 showing a detailed view of a variable flow resistance system according to one or more embodiments of the present disclosure; and

[0010] Figure 4 A flow chart illustrating a method of variably controlling resistance to flow in a well.

[0011] The shown figures are only exemplary and are not intended to assert or imply any limitation with regard to the environment, architecture, design, or process in which different embodiments may be implemented. DETAILED DESCRIPTION

[0012] The following discussion relates to various embodiments of the present disclosure. The accompanying drawings are not necessarily drawn to scale. Certain features of the embodiments may be shown in an enlarged scale or slightly schematic form, and some details of conventional elements may not be shown for the sake of clarity and simplicity. Although one or more of these embodiments may be preferred, the disclosed embodiments should not be interpreted or otherwise used to limit the scope of the present disclosure, including the claims. It should be fully recognized that the different teachings of the embodiments discussed below may be adopted individually or in any suitable combination to produce the desired results. In addition, those skilled in the art will understand that the following description has broad application, and the discussion of any embodiment is merely meant to illustrate the embodiment, and is not intended to imply that the scope of the present disclosure, including the claims, is limited to the embodiment.

[0013] Throughout the following description and claims, certain terms are used to refer to particular features or components. As those skilled in the art will appreciate, different people may refer to the same feature or component by different names. This document is not intended to distinguish between components or features that have different names but the same structure or function.

[0014] In the following discussion and in the claims, the terms "including" and "comprising" are used in an open-ended manner and, thus, should be interpreted to mean "including, but not limited to... ." Furthermore, the term "couple" or "couples" is intended to indicate an indirect or direct connection. Additionally, the terms "axial" and "axially" generally mean along or parallel to a central axis (e.g., the central axis of a body or port), while the terms "radial" and "radially" generally mean perpendicular to the central axis. For example, an axial distance refers to a distance measured along or parallel to the central axis, and a radial distance means a distance measured perpendicular to the central axis. For convenience, "top," "bottom," "above," "below," and variations of these terms are used, but do not require any particular orientation of the components.

[0015] Reference throughout this specification to "one embodiment," "an embodiment," or similar language means that a particular feature, structure, or characteristic described in connection with the embodiment can be included in at least one embodiment of the present disclosure. Thus, appearances of the phrases "in one embodiment," "in an embodiment," and similar language throughout this specification may, but do not necessarily, all refer to the same embodiment.

[0016] Turning now to the accompanying drawings of the present invention, Figure 1A well system 10 is shown that may embody the principles of the present disclosure. Figure 1 As depicted, wellbore 12 has a generally vertical uncased section 14 extending downwardly from casing 16 , and a generally horizontal uncased section 18 extending through formation 20 .

[0017] A tubular string 22, such as a production tubing string, is installed in the wellbore 12. A plurality of well screens 24, a variable flow resistance system 25, and packers 26 are interconnected in the tubular string 22. The packers 26 seal an annulus 28 formed radially between the tubular string 22 and the wellbore section 18. In this manner, fluids 30 can be produced from multiple compartments or zones of the formation 20 through the isolated portions of the annulus 28 between adjacent pairs of packers 26.

[0018] Well screens 24 and variable flow resistance systems 25 positioned between adjacent pairs of packers 26 are interconnected within the tubular string 22. The well screens 24 filter fluid 30 flowing from the annulus 28 into the tubular string 22. The variable flow resistance system 25 variably restricts the flow of fluid 30 into the tubular string 22 based on certain characteristics of the fluid 30.

[0019] At this point, it should be noted that well system 10 is shown in the figures and described herein as only one example of a wide variety of well systems that can utilize the principles of the present disclosure. It should be clearly understood that the principles of the present disclosure are in no way limited to any details of the well system 10 or its components depicted in the figures or described herein.

[0020] For example, in accordance with the principles of the present disclosure, the wellbore 12 need not include a substantially vertical wellbore section 14 or a substantially horizontal wellbore section 18, as the wellbore sections may be oriented in any direction and may be cased or uncased without departing from the scope of the present disclosure. The fluid 30 need not be produced solely from the formation 20, as in other examples, the fluid may be injected into the formation, or the fluid may be both injected into the formation and produced from the formation, etc. Additionally, each of the well screens 24 and variable flow resistance systems 25 need not be positioned between each adjacent pair of packers 26. A single variable flow resistance system 25 need not be used in conjunction with a single well screen 24. Any number, arrangement, and / or combination of these components may be used.

[0021] Any variable flow resistance system 25 need not be used with the well screen 24. For example, during an injection operation, the injected fluid may flow through the variable flow resistance system 25 without also flowing through the well screen 24.

[0022] The well screen 24, variable flow resistance system 25, packer 26, or any other component of the tubular string 22 need not be positioned in the uncased sections 14, 18 of the wellbore 12. In accordance with the principles of the present disclosure, any section of the wellbore 12 may be cased or uncased, and any portion of the tubular string 22 may be positioned in either an uncased or cased section of the wellbore.

[0023] Therefore, it should be clearly understood that the present disclosure describes how to make and use certain examples, but the principles of the present disclosure are not limited to any details of these examples. Instead, the knowledge gained from the present disclosure can be used to apply those principles to various other examples.

[0024] Those skilled in the art will appreciate that it would be beneficial to be able to regulate the flow of fluid 30 from each zone of the formation 20 into the tubular string 22, for example, to prevent water coning 32 or gas coning 34 in the formation. Other uses for flow regulation in a well include, but are not limited to, balancing production from (or injection into) multiple zones, minimizing production or injection of undesirable fluids, maximizing production or injection of desired fluids, etc.

[0025] Examples of the variable flow resistance system 25, described more fully below, can provide these benefits by increasing the resistance to flow if the fluid velocity increases above a selected level (e.g., thereby balancing flow between regions, preventing water coning or gas coning, etc.); or increasing the resistance to flow if the fluid viscosity drops below a selected level (e.g., thereby restricting the flow of undesirable fluids such as water or gas in a producing well).

[0026] Whether a fluid is a desired fluid or an undesired fluid depends on the purpose of the production or injection operation being performed. For example, if it is desired to produce oil from a well but not water or gas, then oil is a desired fluid and water and gas are undesired fluids.

[0027] It should be noted that at downhole temperatures and pressures, hydrocarbon gas may actually be completely or partially in the liquid phase. Therefore, it should be understood that when the term "gas" is used herein, supercritical phase, liquid phase and / or gas phase are included within the scope of this term.

[0028] Now refer to Figure 2 , shows a schematic diagram of a variable flow resistance system 25 according to one or more embodiments of the present disclosure. In this example, a fluid 36 (which may include one or more fluids such as oil and water, liquid water and steam, oil and gas, gas and water, oil, water and gas, etc.) may be formed by a well screen ( Figure 124) filtered and can then flow into the first flow path 38 (e.g., the inlet flow path) of the variable flow resistance system 25. The fluid may include one or more undesirable fluids or desired fluids. Steam and water can both be combined in the fluid. As another example, oil, water and / or gas can be combined in the fluid. The flow of fluid 36 through the variable flow resistance system 25 is suppressed based on one or more characteristics of the fluid (e.g., viscosity, velocity, etc.). The fluid 36 can then be discharged from the variable flow resistance system 25 to the interior of the tubular string 22 through the second flow path 40 (e.g., the outlet flow path). As used herein, the first flow path 38 and the second flow path 40 can be generally described as and used as the inlet flow path and the outlet flow path, respectively. However, the present disclosure is not limited to this, as the flow of the fluid 36 can be reversed in the variable flow resistance system 25, so that the first flow path 38 and the second flow path 40 can be generally described as and used as the outlet flow path and the inlet flow path, respectively.

[0029] In other examples, the well screen 24 may not be used in conjunction with the variable flow resistance system 25 (e.g., during injection operations), the fluid 36 may flow in opposite directions through various elements of the well system 10 (e.g., during injection operations), a single variable flow resistance system may be used with multiple well screens, multiple variable flow resistance systems may be used with one or more well screens, fluid may be received from or discharged into regions of the well other than the annulus or tubing string, fluid may flow through the variable flow resistance system before flowing through the well screen, any other components may be interconnected upstream or downstream of the well screen and / or variable flow resistance system, etc. It should be understood that the principles of the present disclosure are in no way limited to the details of the examples depicted in the figures and described herein. Furthermore, additional components (such as casings, shunts, lines, instruments, sensors, inflow control devices, etc.) may also be used in accordance with the present disclosure as desired.

[0030] Variable flow resistance system 25 Figure 2 2. Although depicted in simplified form in the preferred embodiment, the system may include various channels and devices for performing various functions, as described more fully below. Additionally, the system 25 preferably extends circumferentially at least partially around the tubular string 22, or the system may be formed in the wall of a tubular structure interconnected as part of the tubular string.

[0031] In other examples, the system 25 may not extend circumferentially around the tubular string or be formed in the wall of the tubular structure. For example, the system 25 may be formed in a flat structure, etc. The system 25 may be located in a separate housing attached to the tubular string 22, or the system 25 may be oriented such that the axis of the second flow path 40 is parallel to the axis of the tubular string. The system 25 may be located on a logging string or attached to a non-tubular device. Any orientation or configuration of the system 25 may be used in accordance with the principles of the present disclosure.

[0032] Still refer to Figure 2 Variable flow resistance system 25 includes a first flow path 38 for receiving fluid into system 25 and a second flow path 40 for delivering fluid out of system 25. When the fluid exits system 25, it may then, for example, enter the interior of a tool body that may be used in conjunction with variable flow resistance system 25. Variable flow resistance system 25 may also include a sensor 42 and an actuator 44. Sensor 42 may be positioned near or adjacent to first flow path 38 to measure a property of the fluid received into system 25 through first flow path 38. Actuator 44 may control or adjust the inflow of fluid received into system 25 and first flow path 38 based on the property of the fluid measured by sensor 42. For example, actuator 44 may be positioned or included within system 25 to extend into and retract from a fluid flow path extending through system 25 and formed therethrough. To increase the inflow of fluid, actuator 44 may retract to allow more fluid to flow through the fluid flow path of system 25. To reduce the inflow of fluid, the actuator 44 can be extended to restrict the flow of fluid through the fluid flow path of the system 25. Additionally, in one or more embodiments, the actuator 44 can be used to completely stop or inhibit the flow of fluid through the fluid flow path of the system 25. For example, if the system 25 is shut down or powered off, the actuator 44 can be fully extended to prevent the flow of fluid through the fluid flow path of the system 25.

[0033] In one or more embodiments, the sensor 42 can be used to measure the resistivity of the fluid, the flow rate of the fluid, the pressure of the fluid, the pressure differential of the fluid within the system 25, the density of the fluid, the viscosity of the fluid, and / or any other property or characteristic of the fluid known in the art. The sensor 42 can include a resistivity sensor, a conductivity sensor, a capacitance sensor, an inductance sensor, an acoustic sensor, a nuclear sensor, a temperature sensor, a flow sensor, an acoustic sensor, and / or any other type of sensor known in the art. For example, in embodiments where the sensor 42 includes an acoustic sensor, the acoustic sensor can be used to listen for, detect, and / or measure turbulence in the flow of the fluid to measure the flow rate of the fluid and / or determine whether sand is generated along with the fluid.

[0034] Additionally, the actuator 44 may include a mechanical actuator (e.g., a screw assembly), an electrical actuator (e.g., a piezoelectric actuator, an electric motor), a hydraulic actuator (e.g., a hydraulic cylinder and pump, a hydraulic pump), a pneumatic actuator, and / or any other type of actuator known in the art. For example, the actuator 44 may include a linear or axially driven actuator, wherein the actuator 44 interacts with an orifice included in the first flow path 38 to control the inflow of fluid.

[0035] In addition, despite Figure 2 Only one sensor and one actuator are shown in the figure, but the present disclosure is not limited thereto, as more than one sensor and / or more than one actuator may be used according to the present disclosure. In such an embodiment, if multiple sensors or actuators are used, the sensors and actuators used may be different from each other and / or may have different thresholds or tolerances. For example, multiple different sensors may be used to measure different properties of the fluid, and multiple different actuators may be used to control the inflow of the fluid using different techniques or at different thresholds.

[0036] The variable flow resistance system 25 may also include a controller and corresponding electronics 46 that control and manage the operation of the components of the system 25. In one embodiment, the controller may communicate or be coupled between the sensor 42 and the actuator 44 to control the actuator 44 based on the property of the fluid measured by the sensor 42. The controller may be configured to receive the property measured by the sensor 42 and compare the measured property to a predetermined value for the measured property. Based on the comparison of the measured property to the predetermined value, the controller may then move the actuator 44 to adjust the inflow of fluid received into the first flow path 38 of the system 25.

[0037] As an example, in one or more embodiments, the controller can receive the resistivity measured by the sensor 42 and compare the measured resistivity to a predetermined value for the resistivity of the fluid. The measured resistivity can be used to represent or indicate the type of fluid received into the system, such as whether the fluid contains brine, water, oil, and / or gas, as well as the possible proportions of these components. In one embodiment, based on the desired fluid to be received into the system, if the measured resistivity of the fluid is above the predetermined value for the resistivity of the fluid, the controller can be used to move the actuator 44 to increase the inflow of fluid received into the first flow path 38. If the measured resistivity of the fluid is below the predetermined value for the resistivity of the fluid, the controller can be used to move the actuator 44 to decrease the inflow of fluid received into the first flow path 38.

[0038] Still refer to Figure 2, the variable flow resistance system 25 may include a communication unit (e.g., a transmitter or receiver) that sends and / or receives communication signals. The communication unit may be included in the electronics 46, for example, and may be used to receive communication signals while the system 25 is located downhole in the well, and / or may be used to send communication signals up the well or between downhole devices. The actuator 44 may control the inflow of fluid received into the first flow path 38 based on the communication signals received by the communication unit. For example, one or more communication signals may be sent from the communication unit to the surface to report properties measured by the system 25 (e.g., telemetry) and / or characteristics of the system 25 (e.g., the inflow of fluid into the system 25). Additionally or alternatively, one or more communications may be received by the communication unit, such as to facilitate control of one or more components of the system 25.

[0039] The communication signal can be received by the communication unit to control the inflow of fluid received into the first flow path 38 of the system 25, such as to increase or decrease the inflow of fluid into or through the system 25. The communication signal can be used to indicate whether the well is in a preliminary stage, an intermediate stage, or a final stage, wherein different control parameters can be used for each of these different stages of the well. In addition, the communication signal can be used to confirm that the system 25 is operating and / or to confirm the downhole conditions of the well. The communication unit can include one or more sensors for telemetry, such as accelerometers, gyroscopes, and / or hydrophones. The communication unit can also be used in conjunction with mud pulse telemetry, pressure profile telemetry, flow rate telemetry, acoustic pulse telemetry, and / or pseudo-static pressure profile telemetry.

[0040] In one or more embodiments, the variable flow resistance system 25 may include a generator 48 and / or a power storage device. The generator 48 may be used to generate power for the system 25, and the power storage device may be used to store power for the system 25 and / or store power generated by the generator 48. For example, Figure 3 A detailed view of a variable flow resistance system 25 is shown, according to one or more embodiments of the present disclosure. Figure 3 The variable flow resistance system 25 in can be Figure 2 An alternative embodiment of the variable flow resistance system 25 in which like features have like reference numerals. Figure 3 , generator 48 may include a turbine and may be capable of generating electricity from the fluid received into first flow path 38 and flowing through system 25. Generator 48 may additionally or alternatively include other types of generators (such as a flow-induced vibration generator and / or a piezoelectric generator) to generate electricity from the fluid received into system 25 and / or from other energy sources present downhole (e.g., a temperature source and / or a pressure source).

[0041] The power storage device may be included within the electronics 46, for example, and may be used to store electricity, such as electricity generated by the generator 48. The power storage device may include a capacitor (e.g., a supercapacitor), a battery (e.g., a rechargeable battery), and / or any other type of power storage device known in the art. In one or more embodiments, because one or more sensors and / or one or more actuators of the system 25 may require more power than the generator 48 can generate, the power storage device may be used to store power and then supplement the generator 48 when operating the one or more sensors, one or more actuators, and / or other components of the system 25.

[0042] Now refer to Figure 4 , a flow chart illustrating a method 100 for variably controlling flow resistance in a well, according to one or more embodiments of the present disclosure, is shown. Method 100 includes receiving a fluid into a first flow path 102, such as into a first flow path of a variable flow resistance device, tool, or system. Method 100 may then measure a property of the fluid received into the first flow path 104, such as using a sensor of the variable flow resistance system; and then adjust an inflow of the fluid received into the first flow path 106 based on the measured property of the fluid, such as using an actuator of the variable flow resistance system. Adjusting the inflow of the fluid 106 may include comparing the measured property of the fluid to a predetermined value 108, such as a measured property including resistivity, flow rate, pressure, density, viscosity, conductivity, capacitance, inductance, radioactivity, temperature, and / or acoustic characteristics of the fluid. Adjusting the inflow of the fluid 106 may also include adjusting the inflow of the fluid received into the first flow path 110 based on the comparison of the measured property of the fluid with the predetermined value. Additionally or alternatively, method 100 may receive a communication / control signal 112 from a remote location after receiving fluid into the first flow path 102. Method 100 may then further include adjusting an inflow of fluid received into the first flow path based on the received communication / control signal 114.

[0043] In addition to the embodiments described above, many examples of specific combinations are within the scope of the present disclosure, some of which are described in detail below.

[0044] Example 1. A variable flow resistance system for use with a subterranean well, the system comprising:

[0045] a first flow path configured to receive a fluid;

[0046] a sensor configured to measure a property of the fluid received into the first flow path; and

[0047] An actuator is configured to control an inflow of the fluid received into the first flow path based on the property of the fluid measured by the sensor.

[0048] Example 2. A variable flow resistance system as described in Example 1, wherein the property of the fluid to be measured by the sensor includes at least one of the resistivity of the fluid, the flow rate of the fluid, the pressure of the fluid, the density of the fluid and the viscosity of the fluid.

[0049] Embodiment 3. The variable flow resistance system of embodiment 1, wherein the sensor comprises at least one of a resistivity sensor, a conductivity sensor, a capacitance sensor, an inductance sensor, a nuclear sensor, a temperature sensor, a flow sensor, and an acoustic sensor.

[0050] Embodiment 4. The variable flow resistance system of embodiment 1, further comprising a controller configured to control the actuator based on the property of the fluid measured by the sensor.

[0051] Embodiment 5. The variable flow resistance system of embodiment 1, further comprising a generator configured to generate electricity for the variable flow resistance system.

[0052] Embodiment 6. The variable flow resistance system of embodiment 5, wherein the generator comprises a turbine configured to generate electricity solely from fluid received into the first flow path.

[0053] Embodiment 7. The variable flow resistance system of embodiment 5, further comprising a power storage device configured to store the power generated by the generator.

[0054] Embodiment 8. The variable flow resistance system of embodiment 1, further comprising a communication unit configured to at least one of receive a communication signal and transmit a communication signal.

[0055] Embodiment 9. The variable flow resistance system of embodiment 8, wherein the actuator is configured to control the inflow amount of the fluid received into the first flow path based on the communication signal received by the communication unit.

[0056] Embodiment 10. The variable flow resistance system of embodiment 1, further comprising a tool body and a second flow path configured to deliver the fluid to an interior of the tool body.

[0057] Example 11. The variable flow resistance system of Example 1, further comprising a production tubing string, wherein the first flow path comprises a production bore of the production tubing string.

[0058] Embodiment 12. The variable flow resistance system of embodiment 1, wherein the actuator comprises at least one of a screw assembly, a piezoelectric actuator, a hydraulic cylinder, an electric motor, and a hydraulic pump.

[0059] Example 13. A method of variably controlling flow resistance in a well, the method comprising:

[0060] receiving a fluid into a first flow path;

[0061] measuring a property of the fluid received into the first flow path; and

[0062] An inflow of the fluid received into the first flow path is adjusted based on the measured property of the fluid.

[0063] Example 14. The method of Example 13, wherein adjusting the inflow comprises:

[0064] comparing the measured property of the fluid to a predetermined value; and

[0065] The inflow of the fluid received into the first flow path is adjusted based on a comparison of the measured property of the fluid with the predetermined value.

[0066] Embodiment 15. The method of embodiment 13, wherein measuring the property of the fluid comprises measuring at least one of resistivity, flow rate, pressure, density, and viscosity of the fluid.

[0067] Embodiment 16. The method of embodiment 13, wherein measuring the property of the fluid comprises measuring the resistivity of the fluid, and wherein adjusting the inflow comprises:

[0068] comparing the measured resistivity of the fluid to a predetermined value of the resistivity of the fluid;

[0069] increasing the inflow of the fluid received into the first flow path if the measured resistivity of the fluid is higher than the predetermined value of the resistivity of the fluid; and

[0070] If the measured resistivity of the fluid is lower than the predetermined value of the resistivity of the fluid, the inflow of the fluid received into the first flow path is reduced.

[0071] Embodiment 17. The method of Embodiment 13, further comprising generating electricity from the fluid received into the first flow path.

[0072] Example 18. The method of Example 13, wherein the first flow path comprises a production bore of a production tubing string.

[0073] Example 19. The method of Example 13, further comprising:

[0074] receiving a communication signal from a remote location; and

[0075] The inflow amount of the fluid received into the first flow path is adjusted based on the received communication signal.

[0076] Example 20. A method of variably controlling flow resistance in a well, the method comprising:

[0077] receiving a fluid into a first flow path;

[0078] receiving a communication signal from a remote location; and

[0079] An inflow of the fluid received into the first flow path is adjusted based on the received communication signal.

[0080] Although various aspects of the present disclosure are susceptible to various modifications and alternative forms, specific embodiments have been shown by way of example in the drawings and have been described in detail herein. It should be understood, however, that the invention is not intended to be limited to the particular forms disclosed. On the contrary, the invention is intended to cover all modifications, equivalents, and alternatives falling within the spirit and scope of the invention as defined by the following claims.

Claims

1. A variable flow resistance system for use with a subterranean well, the system comprising: a first flow path configured to receive a flow of fluid in a first direction when the fluid is produced from the subterranean well; a sensor configured to measure a property of the fluid received into the first flow path, wherein the measured property includes fluid flow rate and fluid viscosity; a communication unit configured to receive a communication signal from the surface indicating one of a plurality of production stages of the well, the plurality of production stages comprising a preliminary stage, an intermediate stage, and a final stage; an actuator configured to control a flow rate of the fluid received into the first flow path by moving axially in a direction of fluid flow in the first flow path; a generator located downstream of the actuator relative to the first direction and including a turbine configured to generate electricity for the variable flow resistance system; a power storage device configured to store at least a portion of the power generated by the generator; as well as a controller in communication with the communication unit and the actuator, the controller being configured to adjust the actuator based on a comparison of at least one property of the fluid measured by the sensor and a predetermined value of the property and a control parameter associated with the indicated production phase of the well, wherein the controller is further configured to variably adjust the actuator to increase resistance to fluid flow in response to determining that the measured fluid flow rate increases above a first predetermined level or the measured fluid viscosity decreases below a second predetermined level, The controller is further configured to regulate the actuator to completely stop or inhibit the flow of the fluid through the first flow path to shut down or de-energize the variable flow resistance system. 2 . The variable flow resistance system of claim 1 , wherein the property of the fluid measured further comprises resistivity of the fluid, pressure of the fluid, or density of the fluid.

3. The variable flow resistance system of claim 1, wherein the sensor comprises at least one of a resistivity sensor, a conductivity sensor, a capacitance sensor, an inductance sensor, a nuclear sensor, a temperature sensor, a flow sensor, or an acoustic sensor. 4 . The variable flow resistance system of claim 1 , wherein the communication unit is further configured to send a communication signal.

5. The variable flow resistance system of claim 1, further comprising a tool body and a second flow path configured to route the fluid to an interior of the tool body.

6. The variable flow resistance system of claim 1, further comprising a production tubing string, wherein the first flow path comprises a production bore of the production tubing string.

7. The variable flow resistance system of claim 1, wherein the actuator comprises at least one of a screw assembly, a piezoelectric actuator, a hydraulic cylinder, an electric motor, and a hydraulic pump.

8. The variable flow resistance system according to claim 1, wherein: When the variable flow resistance system is off or powered off, the controller is further configured to use the power stored in the power storage device to start or power the variable flow resistance system and variably adjust the actuator to allow the fluid to flow through the first flow path.

9. A method of variably controlling resistance to flow in a subterranean well, the method comprising: receiving a flow of fluid in a first direction into a first flow path when the fluid is produced from a subterranean well; measuring a property of the fluid received into the first flow path, wherein the measured property includes fluid flow rate and fluid viscosity; receiving a communication signal from the surface indicating one of a plurality of production stages of the well, the plurality of production stages comprising a preliminary stage, an intermediate stage, and a final stage; adjusting, using a controller of the variable flow resistance system, a flow rate of the fluid received into the first flow path based on a comparison of at least one measured property of the fluid and a predetermined value of the property and a control parameter associated with an indicated production stage of the well, wherein adjusting the flow rate includes axially moving an actuator in a direction of fluid flow into the first flow path; generating electricity from the fluid received into the first flow path with a generator located downstream of the actuator relative to the first direction; as well as storing at least some of the generated electricity in an electricity storage device, wherein regulating the flow rate further comprises increasing resistance to fluid flow in response to determining that the measured fluid flow rate increases above a first predetermined level or the measured fluid viscosity decreases below a second predetermined level, Wherein regulating the flow rate further comprises axially moving the actuator to completely stop or prohibit the fluid from flowing into the first flow path, thereby shutting down the variable flow resistance system or de-energizing the variable flow resistance system.

10. The method of claim 9, wherein said measuring the property of the fluid further comprises measuring the resistivity, pressure, or density of the fluid.

11. The method of claim 9, wherein said measuring said property of said fluid further comprises measuring resistivity of said fluid, and wherein said adjusting said flow rate comprises: increasing the flow rate of the fluid received into the first flow path if the measured resistivity of the fluid is above the predetermined value of the resistivity of the fluid; as well as If the measured resistivity of the fluid is below the predetermined value of the resistivity of the fluid, the flow rate of the fluid received into the first flow path is reduced.

12. The method of claim 9, wherein the first flow path comprises a production bore of a production tubing string.

13. The method according to claim 9, wherein When the variable flow resistance system is off or powered off, the method further includes using the power stored in the power storage device to activate or power the variable flow resistance system and variably adjust the actuator to allow flow of the fluid through the first flow path.

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