US20180171752A1

US20180171752A1 - Systems and Methods for Controlling Mud Flow Across A Down-Hole Power Generation Device

Info

Publication number: US20180171752A1
Application number: US15/576,576
Authority: US
Inventors: Meredith Marie Cherny
Original assignee: Halliburton Energy Services Inc
Current assignee: Halliburton Energy Services Inc
Priority date: 2015-06-26
Filing date: 2015-06-26
Publication date: 2018-06-21
Also published as: AU2015399513A1; GB2555286B; NO20171847A1; CA2986372A1; WO2016209252A1; GB201719297D0; GB2555286A

Abstract

A flow control device comprising a body, a main flow path formed through the body, and a bypass flow path formed through the body. The flow control device also includes a valve associated with the bypass flow path and configured to control opening and closing of the bypass flow path, wherein the valve opens the bypass valve when a sufficient pressure is exerted on the body. The main flow path delivers drilling fluid to a hydraulic power generation device and the bypass flow path diverts a portion of the drilling fluid away from the hydraulic power generation device.

Description

BACKGROUND

This section is intended to introduce the reader to various aspects of art 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 present embodiments. Accordingly, it should be understood that these statements are to be read in this light, and not as admissions of prior art.
Many oil and gas well drilling systems utilize mud-driven power generation units such as mud motors or mud turbines as a means of generating power or turning the drill bit. In such systems, mud, or drilling fluid, is pumped into the drill string and through the power generation unit. The power generation unit, which may be a turbine or progressive cavity positive displacement (PCPD) pump, utilizes the hydraulic energy from the injected drilling fluid to rotate the drill bit. Typically, the power generation unit is configured to operate most efficiently when the drilling fluid flows across the power generation unit at a certain stable flow rate or window of flow rates. If the flow rate fluctuates excessively, the power generation unit may produce unpredictable power output. If the flow rate of the drilling fluid is too high, the power generation may experience excess wear and decreased operational life.
Typically, to mitigate the effects of unstable drilling fluid flow rate, and to maintain operation within a certain RPM envelope, certain parts of the drilling tool, such as flow gears, may be changed out during a drilling operation to regulate the flow rate. This requires stopping the operation and pulling the tool out of hole to make the part change. This slows down the drilling operation and adds to the cost of the operation. Therefore, a more efficient means of regulating drilling fluid flow rate across the power generation unit is needed.

BRIEF DESCRIPTION OF THE DRAWINGS

Illustrative embodiments of the present disclosure are described in detail below with reference to the attached drawing figures, which are incorporated by reference herein and wherein:

FIG. 1 illustrates a diagrammatical view of a well being drilled by a drilling system, in accordance with example embodiments of the present disclosure;

FIG. 2 illustrates a top perspective view of a flow control device, in accordance with example embodiments of the present disclosure;

FIG. 3 illustrates a bottom perspective view of the flow control device, in accordance with example embodiments of the present disclosure;

FIG. 4 illustrates a perspective cross-sectional view of the flow control device, in accordance with example embodiments of the present disclosure;

FIG. 5 illustrates a cross-sectional view of the flow control device with closed valves, in accordance with example embodiments of the present disclosure; and

FIG. 6 illustrates a cross-sectional view of the flow control device with open valves, in accordance with example embodiments of the present disclosure.

The illustrated 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 OF ILLUSTRATIVE EMBODIMENTS

The present disclosure is directed towards a flow control device for autonomously regulating the flow rate of drilling fluid entering the power generation unit (e.g., mud motor or mud turbine) of a down-hole drilling tool. The flow control device can be place between the drilling fluid source and the power generation unit such that drilling fluid is delivered to the power generation unit via the flow control device. The flow control device includes a main flow path and one or more bypass flow paths. The main flow path is coupled with the power generation unit such that drilling fluid flows through the main flow path and into the power generation unit. The one or more bypass flow paths are separate from the main flow path and power generation unit. Thus, drilling fluid entering the bypass flow paths is diverted from and does not enter the power generation unit. The one or more bypass flow paths include valves which open the bypass flow paths in response to the drilling fluid pressure reaching a certain threshold, thereby limiting flow rate across the power generation unit.
Turning to the figures, FIG. 1 illustrates a schematic view of a well 114 being drilled by a drilling system 100, in accordance with example embodiments of the present disclosure. Various types of drilling equipment such as a rotary table, drilling fluid pumps and drilling fluid tanks (not expressly shown) may be located at a well site 106. For example, the well site 106 may include a drilling rig 102 that has various characteristics and features associated with a “land drilling rig.” However, downhole drilling tools incorporating teachings of the present disclosure may be satisfactorily used with drilling equipment located on offshore platforms, drill ships, semi-submersibles and drilling barges (not expressly shown).
The well 114 formed by the drilling system 100 may be a vertical well, such as that illustrated in FIG. 1. In some embodiments, the well 114 may be a horizontal well or a directional well having a range of angles. Thus, the well system 100 can be a vertical drilling system or a directional drilling system. The well 114 may be defined at least in part by a casing string 110 that may extend from the surface of the well site 106 to a selected downhole location. Portions of the well 114 that do not include the casing string 110 may be described as “open hole.”
The drilling system 100 may include a drill string 103 suspended down-hole from the well site 106. The drill string 103 includes a drill pipe 112 and a bottom hole assembly (BHA) 120. The drill pipe 112 may include a plurality of segments, each of which are added to the drill pipe 112 as the well 114 is drilled and increasing length of drill pipe 112 is required. The drill pipe 112 provides the length required for the BHA 120 to reach well bottom and drill further into the formation. The drill pipe 112 may also deliver drilling fluid from surface facilities at the well site 106 to the BHA 120.
The BHA 120 may include a wide variety of components configured to form the wellbore 114. For example, the BHA may include components 122 a and 122 b. Such components 122 a and 122 b may include, but are not limited to, drill bits (e.g., the drill bit 101), coring bits, drill collars, rotary steering tools (e.g., the rotary steerable drilling system 123), directional drilling tools, downhole drilling motors, reamers, hole enlargers or stabilizers, logging while drilling (LWD) or measurement while drilling (MWD) tools, among others. The number and types of components 122 included in the BHA 120 may depend on anticipated downhole drilling conditions and the type of wellbore that is to be formed.
The BHA 120 further includes a motor 123, such as a mud motor, which drives a drill bit 101. In some embodiments, drilling fluid is delivered to the motor 123 through the drill pipe 112. In some embodiments, the motor 123 includes a power generation unit 125 such as a turbine which rotates when traversed by drilling fluid, thereby turning to drill bit 101. In some embodiments, power generation unit 125 includes a progressive cavity positive displacement (PCPD) pump which includes a rotor and a stator such that drilling fluid traversing the motor between the rotor and the stator causes the motor 123 to turn, thereby turning the bit 101.
The well system 100 also includes a flow control device 130 disposed along or within the BHA 120. In certain embodiments, the flow control device 130 is disposed between a drilling fluid source and the motor 123 such that drilling fluid flows through the flow control device 130 before reaching the motor 123. Thus, the flow control device 130 is in a position to control the flow of drilling fluid into and through the motor 123. In some embodiments, the drilling fluid source is located at the well site 106. During certain applications, if the pressure of the drilling fluid at the flow control device 130 is below a certain threshold pressure, the flow control device 130 permits substantially all of the drilling fluid to flow through to the motor 123. If the pressure of the drilling fluid exceeds the threshold pressure, the flow control device 130 diverts a portion of the drilling fluid away from entering the motor 123. Thus, the flow rate of drilling fluid across the motor can be held substantially constant, or at least within an acceptable range.
In some embodiments, the flow control device 130 is disposed within the motor 123 or as a component of the motor 123. In such embodiments, the flow control device 130 is positioned above the power generation unit 125, in which “above” refers to a relative position which is upstream from the bit 101 or uphole thereof. Specifically, in such embodiments, the flow control device 130 is disposed between the drilling fluid source and the power generation unit 125 of the motor 123 such that the drilling fluid flowing into the motor 123 flows through the flow control device 130 before flowing across the power generation unit 125. Thus, the flow control device 130 can control the drilling fluid flowing across the power generation unit 125.
The flow control device 130 can be disposed at any position uphole of the motor 123 or power generation unit 125 such that the drilling fluid flows through the flow control device before flowing across the motor 123 or power generation unit 125.
FIG. 2 illustrates a top perspective view of a flow control device 200, such as the flow control device 130 of FIG. 1, in accordance with example embodiments of the present disclosure. FIG. 3 illustrates a bottom perspective view of the flow control device 200, in accordance with example embodiments of the present disclosure. Referring to FIGS. 2 and 3, in some embodiments, the flow control device 200 comprises a body 202 having a first end 204 and a second end 206. The flow control device 200 may be positioned such that the first end 204 is uphole of the second end 206. Specifically, drilling fluid enters the flow control device 200 via the first end 204 and exits the flow control device 200 via the second end 206 before entering the motor 123. In some embodiments, the first end 204 and second end 206 each include a surface. In some embodiments, the body 202 includes a wall 212 extending from the entrance end 204 to the exit end 206. The body 202 of the flow control device 200 may have a cylindrical shape as shown. However, the flow control device 200 can have any shape.
The flow control device 200 further includes a main flow path 210 formed through the body 202 extending between a first main opening 210 a formed in the first end 204 to a second main opening 210 b formed in the second end 206. Thus, the main flow path 210 traverses the entire length of the body 202, “length” being measured between the first end 204 and the second end 206. The main flow path 210 provides an open path for the drilling fluid to traverse the flow control device 200. The main flow path 210 may be a straight path or have curves and bends.
The flow control device 200 also includes one or more bypass flow paths 208 formed through the body 202 and extending between a first bypass opening 208 a formed in the first end 204 to a second bypass opening 208 b formed in the second end 206. Similar to the main flow path 210, the one or more bypass flow paths 208 can generally have any shape that traverses the body 202 of the flow control device 200 and allows drilling fluid to flow through the flow control device 200. However, the bypass flow paths 208 are normally closed off, forcing all drilling fluid to flow through the main flow path 201, unless the flow of drilling fluid exerts a high enough force on the flow control device 200, which indicates a higher than desirable fluid pressure. When such a condition occurs, the bypass flow paths 208 open and the fluid pressure is regulated. In some embodiments, each of the bypass flow paths 208 includes a valve 212 which controls opening and closing of the respective bypass flow path 208.
FIG. 4 illustrates a perspective cross-sectional view of the flow control device 200, showing the internal structures of the flow control device 200 in more detail. The valve 212 is configured to move between a closed configuration and an open configuration. FIG. 4 shows the flow control device 200 in the closed configuration. When the valve 212 is in the closed configuration, the respective bypass flow path 208 is effectively closed off and drilling fluid cannot flow through the bypass flow path 208.
The valve 212 can be is disposed within the respective bypass flow path 208. The valve 212 may form a barrier in the bypass flow path 208 when in the closed configuration which substantially prevents drilling fluid from flowing therethrough. In some embodiments, the valve 212 includes a valve body 402 and a valve member 406 moveable in relation to the valve body 402. In certain such embodiments, the valve 212 further comprises a spring 408 disposed between the valve body 402 and the valve member 406 such that the valve member 406 is supported by the spring 408.
The valve 212 can be positioned within the bypass flow path 208 such that the valve member 406 plugs the first bypass opening 208 a in the closed configuration. Specifically, the spring force of the spring 408 keeps the valve member 406 in such a position. In some embodiments, the spring 408 pushes the valve member 406 against a portion of the first end 204 around the first bypass opening 208 a, thereby closing off the first bypass opening 208 a. Thus, the bypass flow path 208 is closed by default, as illustrated in the cross-sectional view of FIG. 5. Referring to FIG. 5, the force exerted on the valve member 406 by the spring 408 is in the opposite direction as the force exerted on the valve member 406 applied by the injected drilling fluid. Thus, the valve 212 remains closed unless the force of the drilling fluid overcomes the force of the spring 408. When the force of the drilling fluid overcomes the force of the spring 408, the valve member 406 is pushed away from the entrance end 204 by the drilling fluid, opening a space between the entrance end 204 and the valve member 406, through which drilling fluid enters the bypass flow path 208. The drilling fluid is thereby diverted from main flow path 210.
During operation, the valve 212 may exhibit various degrees of openness, increasing with fluid pressure until the valve 212 is fully open. For example, a fluid pressure at or just above the threshold pressure may cause the valve 212 to open minimally, and a fluid pressure substantially greater than the threshold pressure may cause the valve 212 to open to a greater degree. In some embodiments, the valve is a mechanically operated valve and is directly opened by the force of the fluid pressure. Depending on the specific configuration and mechanisms of the valve, the valve may have discrete degrees of openness or continuous degrees of opening. In some embodiments, the valve is an electrically operated valve, in which the valve includes a sensor which senses the fluid pressure or flow rate in the main flow path 210 and controls the openness of the valve electronically based on the sensed parameter.
FIG. 6 illustrates a cross-sectional view of the flow control device 200 in which the valves 208 are in the open configuration. The closed configuration is the neutral state of the valve 212, and the valve 212 moves into the open configuration when a fluid pressure greater than a certain threshold pressure is exerted on the entrance end 204 of the body. If the pressure of the drilling fluid is not above a certain threshold, the valve 212 and bypass flow path 208 remain closed. Thus, under such conditions, substantially all of the drilling fluid flows through the main flow path 210 and into the motor 123 or power generation unit 125.
In some embodiments, when the pressure exerted by the drilling fluid is above the threshold, the valve 212 is configured to open the bypass flow path 208, allowing a portion of the drilling fluid to flow therethrough. Typically, the threshold pressure is indicative of a flow rate of the drilling fluid which is higher than selected for the motor 123 or power generation unit 125. The drilling fluid flowing through the bypass flow path 208 is routed through an auxiliary pathway separate from the motor 123 or power generation unit 125. Thus, the amount of drilling fluid flowing through the main flow path 210 and subsequently through the motor 123 or power generation unit 125 decreases. This decreases the flow rate of drilling fluid across the power generation unit 125 to a more selected level, such as for optimizing performance for example.
In some embodiments, the one or more valves 212 are poppet style valves. In other embodiments, the one or more valves 212 can be any type of valve configured to respond to the pressure, force, or flow rate, of the injected drilling fluid. Specifically, the one or more valves 212 may be pressure actuated valves or relief valves. In some embodiments, the valves 212 include flow rate detection means. One or more valves 212 can be mechanically actuated such that the force of the drilling fluid physically opens the valves 212, such as the example described above and in the figures. In some embodiments, the one or more valves 212 can be actuated (i.e., opened) electronically when it is sensed that the pressure, force, or flow rate of the drilling fluid exceeds a threshold.
The flow control device 200 can include any number of bypass flow paths 208 and valves 212. In some embodiments, the valves 212 can be configured to open at different pressure thresholds such that a portion of the valves 212 open at a first pressure threshold and another portion of the valves 212 open at a second pressure threshold.
In some embodiments, there may be more than one main flow path 210. The main flow 210 may expand or contract in size at various positions. The main flow path 210 may be cylindrical in shape as shown in the figures. The main flow path 210 may be tubular such that it is bound by an outer wall and an inner wall. In general, the main flow path 210 may be any shape or configuration that puts the entrance end 204 and the exit end 206 in fluid communication such that a drilling fluid can traverse the flow control device 200 through the main flow path 210. In some embodiments, there may be a plurality of main flow paths 210 formed within the body 202 of the flow control device 200
In addition to the embodiments described above, many examples of specific combinations are within the scope of the disclosure, some of which are detailed below:

EXAMPLE 1

A flow control device, comprising:

- a body comprising a first end and a second end;
- a main flow path formed through the body from the first end to the second end;
- a bypass flow path formed through the body from the first end to the second end and separate from the main flow path; and
- a valve fluidly coupled to the bypass flow path,
- wherein the valve is movable from a closed configuration, in which the bypass flow path is closed, to an open configuration, in which the bypass flow path is open, in response to a first threshold pressure exerted on the first end of the body.

EXAMPLE 2

The flow control device of claim 1, wherein the valve is mechanically or electronically actuated.

EXAMPLE 3

The flow control device of claim 1, wherein the valve comprises:

- a valve body; and
- a valve member moveable in relation to the valve body, putting the valve into the closed configuration or the open configuration,
- wherein the valve member moves in response to a sufficient increase in the fluid pressure or a sufficient decrease in the fluid pressure, wherein sufficiency of the increase or decrease is determined by a parameter of the valve.

EXAMPLE 4

The flow control device of claim 3, where the valve further comprises:

- a spring disposed between the valve body and the valve member,
- wherein the spring holds the valve in the closed configuration unless the fluid pressure overcomes the spring force of the spring.

EXAMPLE 5

The flow control device of claim 1, wherein the valve is at least one of a pressure activated valve or a relief valve.

EXAMPLE 6

The flow control device of claim 1, further comprising:

- a second bypass flow path formed through the body; and
- a second valve coupled to the second bypass flow path, the second valve movable between a closed configuration and an open configuration,
- wherein the second valve allows fluid to flow through the second bypass flow path in the open configuration and prevents fluid from flowing through the second bypass flow path in the closed position; and
- wherein the second valve moves from the closed position to the open position in response to a second fluid pressure being exerted on the first end of the body, the second fluid pressure being above a second threshold pressure.

EXAMPLE 7

The flow control device of claim 1, wherein:

- a fluid flow rate through the main flow path decreases in response to the bypass flow path moving from the closed configuration to the open configuration.

EXAMPLE 8

The flow control device of claim 6, wherein the second threshold pressure is different from the first threshold pressure.

EXAMPLE 9

A down-hole drilling tool, comprising:

- a hydraulic power generation device comprising an actuation flow path, wherein the hydraulic power generation device is actuated in response to a fluid flowing through the actuation flow path;
- an auxiliary flow path separate from the actuation flow path; and
- a flow control device in fluid communication with the hydraulic power generation device, comprising:
  - a body comprising a first end and a second end;
  - a main flow path formed through the body and in fluid communication with the actuation flow path, wherein fluid flowing through the main flow path flows into the actuation flow path;
  - a bypass flow path formed through the body separate from the main flow path and in fluid communication with the auxiliary flow path, wherein fluid flowing through the bypass flow path flows into the auxiliary path; and
  - a valve coupled to the bypass flow path and configured to control fluid flow through the bypass flow path,
  - wherein the valve moves from a closed position to an open position in response to a fluid pressure exerted on the first end of the body, the fluid pressure being above a first threshold pressure.

EXAMPLE 10

The down-hole drilling tool of claim 9, wherein the hydraulic power generation device comprises a progressive cavity positive displacement pump.

EXAMPLE 11

The down-hole drilling tool of claim 9, wherein the valve is integral with the body.

EXAMPLE 12

The down-hole drilling tool of claim 9, wherein the hydraulic power generation device is configured to receive a drilling fluid via the flow control device.

EXAMPLE 13

The down-hole drilling tool of claim 9, wherein the valve is a poppet valve, a pressure activated valve, or a relief valve.

EXAMPLE 14

The down-hole drilling tool of claim 9, where a fluid flow rate through the main flow path decreases in response to the valve moving from the closed configuration to the open configuration.

EXAMPLE 15

The down-hole drilling tool of claim 9, wherein the hydraulic power generation device comprises a turbine.

EXAMPLE 16

The flow control device of claim 9, further comprising:

- a second bypass flow path formed through the body and in fluid communication with the auxiliary path; and
- a second valve coupled to the second bypass flow path, the second valve movable between a closed configuration and an open configuration,
- wherein the second valve allows fluid to flow through the second bypass flow path in the open configuration and prevents fluid from flowing through the second bypass flow path in the closed position;
- wherein the second valve is moved from the closed position to the open position when a second fluid pressure is exerted on the first end of the body, the second fluid pressure being greater than a second threshold pressure; and
- wherein the second threshold pressure is different than the first threshold pressure or the same as the first threshold pressure.

EXAMPLE 17

A method of controlling flow through a downhole drilling tool, comprising:

- transmitting a drilling fluid through a main flow path, wherein the main flow path is coupled to an actuation path of a hydraulic power generation device;
- opening a bypass flow path when a pressure exerted by the drilling fluid surpasses a first threshold pressure, wherein the bypass flow path is coupled to an auxiliary path separate from the actuation path; and
- transmitting a portion of the drilling fluid through the bypass flow path when the bypass flow path is open.

EXAMPLE 18

The method of claim 17, wherein the bypass flow path comprises a valve; wherein the valve controls opening and closing of the bypass flow path; and wherein the valve opens the bypass flow path in response to a fluid pressure above the first threshold pressure.

EXAMPLE 19

The method of claim 17, further comprising:

- transmitting a second portion of the drilling fluid through a second bypass flow path when a pressure exerted by the drilling fluid surpasses a second threshold pressure, wherein the second portion of drilling fluid transmitted through the second bypass flow path flows into the auxiliary path.

EXAMPLE 20

The method of claim 17, further comprising:

- limiting the flow rate of drilling fluid flowing across the hydraulic power generation device.

This discussion is directed to various embodiments of the present disclosure. The drawing figures are not necessarily to scale. Certain features of the embodiments may be shown exaggerated in scale or in somewhat schematic form and some details of conventional elements may not be shown in the interest of clarity and conciseness. Although one or more of these embodiments may be preferred, the embodiments disclosed should not be interpreted, or otherwise used, as limiting the scope of the disclosure, including the claims. It is to be fully recognized that the different teachings of the embodiments discussed below may be employed separately or in any suitable combination to produce desired results. In addition, one skilled in the art will understand that the following description has broad application, and the discussion of any embodiment is meant only to be exemplary of that embodiment, and not intended to suggest that the scope of the disclosure, including the claims, is limited to that embodiment.
Certain terms are used throughout the following description and claims to refer to particular features or components. As one skilled in the art will appreciate, different persons may refer to the same feature or component by different names. This document does not intend to distinguish between components or features that differ in name but are the same structure or function.
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 may 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.
While the aspects of the present disclosure may be 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. But it should be understood that the invention is not intended to be limited to the particular forms disclosed. Rather, the invention is to cover all modifications, equivalents, and alternatives falling within the spirit and scope of the invention as defined by the following appended claims.

Claims

We claim:

1. A flow control device, comprising:

a body comprising a first end and a second end;

a main flow path formed through the body from the first end to the second end;

a bypass flow path formed through the body from the first end to the second end and separate from the main flow path; and

a valve fluidly coupled to the bypass flow path,

wherein the valve is movable from a closed configuration, in which the bypass flow path is closed, to an open configuration, in which the bypass flow path is open, in response to a first threshold pressure exerted on the first end of the body.

2. The flow control device of claim 1, wherein the valve is mechanically or electronically actuated.

3. The flow control device of claim 1, wherein the valve comprises:

a valve body; and

a valve member moveable in relation to the valve body, putting the valve into the closed configuration or the open configuration,

wherein the valve member moves in response to a sufficient increase in the fluid pressure or a sufficient decrease in the fluid pressure, wherein sufficiency of the increase or decrease is determined by a parameter of the valve.

4. The flow control device of claim 3, where the valve further comprises:

a spring disposed between the valve body and the valve member,

wherein the spring holds the valve in the closed configuration unless the fluid pressure overcomes the spring force of the spring.

5. The flow control device of claim 1, wherein the valve is at least one of a pressure activated valve or a relief valve.

6. The flow control device of claim 1, further comprising:

a second bypass flow path formed through the body; and

a second valve coupled to the second bypass flow path, the second valve movable between a closed configuration and an open configuration,

wherein the second valve allows fluid to flow through the second bypass flow path in the open configuration and prevents fluid from flowing through the second bypass flow path in the closed position; and

wherein the second valve moves from the closed position to the open position in response to a second fluid pressure being exerted on the first end of the body, the second fluid pressure being above a second threshold pressure.

7. The flow control device of claim 1, wherein:

a fluid flow rate through the main flow path decreases in response to the bypass flow path moving from the closed configuration to the open configuration.

8. The flow control device of claim 6, wherein the second threshold pressure is different from the first threshold pressure.

9. A down-hole drilling tool, comprising:

a hydraulic power generation device comprising an actuation flow path, wherein the hydraulic power generation device is actuated in response to a fluid flowing through the actuation flow path;

an auxiliary flow path separate from the actuation flow path; and

a flow control device in fluid communication with the hydraulic power generation device, comprising:

a body comprising a first end and a second end;

a main flow path formed through the body and in fluid communication with the actuation flow path, wherein fluid flowing through the main flow path flows into the actuation flow path;

a bypass flow path formed through the body separate from the main flow path and in fluid communication with the auxiliary flow path, wherein fluid flowing through the bypass flow path flows into the auxiliary path; and

a valve coupled to the bypass flow path and configured to control fluid flow through the bypass flow path,

wherein the valve moves from a closed position to an open position in response to a fluid pressure exerted on the first end of the body, the fluid pressure being above a first threshold pressure.

10. The down-hole drilling tool of claim 9, wherein the hydraulic power generation device comprises a progressive cavity positive displacement pump.

11. The down-hole drilling tool of claim 9, wherein the valve is integral with the body.

12. The down-hole drilling tool of claim 9, wherein the hydraulic power generation device is configured to receive a drilling fluid via the flow control device.

13. The down-hole drilling tool of claim 9, wherein the valve is a poppet valve, a pressure activated valve, or a relief valve.

14. The down-hole drilling tool of claim 9, where a fluid flow rate through the main flow path decreases in response to the valve moving from the closed configuration to the open configuration.

15. The down-hole drilling tool of claim 9, wherein the hydraulic power generation device comprises a turbine.

16. The flow control device of claim 9, further comprising:

a second bypass flow path formed through the body and in fluid communication with the auxiliary path; and

wherein the second valve allows fluid to flow through the second bypass flow path in the open configuration and prevents fluid from flowing through the second bypass flow path in the closed position;

wherein the second valve is moved from the closed position to the open position when a second fluid pressure is exerted on the first end of the body, the second fluid pressure being greater than a second threshold pressure; and

wherein the second threshold pressure is different than the first threshold pressure or the same as the first threshold pressure.

17. A method of controlling flow through a downhole drilling tool, comprising:

transmitting a drilling fluid through a main flow path, wherein the main flow path is coupled to an actuation path of a hydraulic power generation device;

opening a bypass flow path when a pressure exerted by the drilling fluid surpasses a first threshold pressure, wherein the bypass flow path is coupled to an auxiliary path separate from the actuation path; and

transmitting a portion of the drilling fluid through the bypass flow path when the bypass flow path is open.

18. The method of claim 17, wherein the bypass flow path comprises a valve; wherein the valve controls opening and closing of the bypass flow path; and wherein the valve opens the bypass flow path in response to a fluid pressure above the first threshold pressure.

19. The method of claim 17, further comprising:

transmitting a second portion of the drilling fluid through a second bypass flow path when a pressure exerted by the drilling fluid surpasses a second threshold pressure, wherein the second portion of drilling fluid transmitted through the second bypass flow path flows into the auxiliary path.

20. The method of claim 17, further comprising:

limiting the flow rate of drilling fluid flowing across the hydraulic power generation device.