US20180106129A1

US20180106129A1 - Method and Apparatus for Hydraulic Fracturing

Info

Publication number: US20180106129A1
Application number: US15/297,934
Authority: US
Inventors: Tristan Reed WISE
Original assignee: Baker Hughes Inc
Current assignee: Baker Hughes Holdings LLC
Priority date: 2016-10-19
Filing date: 2016-10-19
Publication date: 2018-04-19

Abstract

A plug having a valve that permits fluid flow in both directions through the plug, but impedes or resists the flow in one direction with respect to the other direction. The plug includes a body and at least one sealing element positioned on an exterior of the body to create a seal between the body and a portion of a wellbore. The plug includes an internal flow path and a valve positioned along the internal flow path. The valve permits fluid to flow in both directions through the flow path, but inhibits the flow in one direction with respect to the other direction. The plug may include a setting element configured to engage a wellbore. The valve permits the fracturing of a portion of a wellbore without the need to pump a plug, such as a ball, down the wellbore to block fluid flow to increase pressure within the wellbore.

Description

FIELD OF THE DISCLOSURE

The embodiments described herein relate to a plug having a valve that permits fluid flow in both directions through the plug, but impedes or resists the flow in one direction with respect to the flow in the other direction. The valve permits the fracturing of a portion of a wellbore without the need to pump a plug, such as a ball, down the wellbore to block fluid flow to increase pressure within the wellbore.

BACKGROUND

Description of the Related Art

Natural resources such as gas and oil may be recovered from subterranean formations using well-known techniques. Wellbores, both vertical and horizontal, may be drilled into a formation. After formation of the wellbore, a string of pipe, e.g., casing, may be run or cemented into the wellbore. Hydrocarbons may then be produced from the wellbore.
In an attempt to increase the production of hydrocarbons from the wellbore, the casing is often perforated and fracturing fluid is pumped into the wellbore to fracture the subterranean formation. Hydraulic fracturing of a wellbore has been used for more than 60 years to increase the flow capacity of hydrocarbons from a wellbore. Hydraulic fracturing pumps fluids into the wellbore at high pressures and pumping rates so that the rock formation of the wellbore fails and forms a fracture to increase the hydrocarbon production from the formation by providing additional pathways through which reservoir fluids being produced can flow into the wellbore.
One method of fracturing multiple zones in a wellbore is to use multiple ported collars in combination with sliding sleeve assemblies. The sliding sleeves are installed on the inner diameter of the casing and/or sleeves and can be held in place by shear pins. In some designs, the bottom most sleeve is capable of being opened hydraulically by applying a differential pressure to the sleeve assembly. After the casing with ported collars is installed, a fracturing process is performed on the bottom most zone of the well. This process may include hydraulically sliding sleeves in the first zone to open ports and then pumping the fracturing fluid into the formation through the open ports of the first zone. After fracturing the first zone, a plug, which may be a ball, is dropped and/or pumped down the well. The ball hits the next sleeve up from the first fractured zone in the well and thereby opens ports for fracturing the second zone. After fracturing the second zone, a second ball, which is slightly larger than the first ball, is dropped to open the ports for fracturing the third zone. This process is repeated using incrementally larger balls to open the ports in each consecutively higher zone in the well until all the zones have been fractured. However, because the well diameter is limited in size and the ball sizes are typically increased in quarter inch increments, this process is limited to fracturing only about 11 or 12 zones in a well before ball sizes run out. In addition, the use of the sliding sleeve assemblies and the packers to set the well casing in this method can be costly. Further, the sliding sleeve assemblies and balls can significantly reduce the inner diameter of the casing, which is often undesirable. After the fracture stimulation treatment is complete, it is often necessary to mill out the balls and ball seats from the casing.
Additional disadvantages of the current system may exist. For example, it may take a considerable amount of time to pumping a ball to down the wellbore to open the sliding sleeve of each production zone to be fractured. A system that may be used to fracture a production zone without the use of a ball may be beneficial.

SUMMARY

The present disclosure is directed to plug having a valve that permits fluid flow in both directions through the plug, but inhibits the flow in one direction with respect the flow in the other direction and method of use that overcomes some of the problems and disadvantages discussed above.
One embodiment is a plug comprising a body and at least one sealing element positioned on an exterior of the body, the sealing element being configured to create a seal between the body and a portion of a wellbore. The plug comprises a flow path through an interior of the body and a valve positioned along the flow path. The valve permits fluid to fluid in a first direction through the flow path and permits fluid to flow in a second direction through the flow path, wherein the valve inhibits the flow of the fluid in the second direction with respect to the flow of fluid in the first direction.
The plug may comprise at least one setting element positioned on the exterior of the body configured to engage a portion of a wellbore. The first direction may be from below the body to above the body and the second direction may be from above the body to below the body. The valve may be a solid state device. The valve may be a Tesla valve. The valve may comprises a main flow path in communication with the flow through the interior of the body, a plurality of projections along the main flow path, and a plurality of secondary flow paths in communication with the main flow path. Fluid flowing in the first direction may flow substantially along the main flow path and the plurality of projections may divert fluid flowing in the second direction to flow through the plurality of secondary flow paths.
The valve may comprise a flow path through the valve having a plurality of chambers, the chambers being in communication with each other via a plurality of openings, wherein the openings are configured to permits substantially smooth fluid flow through the flow path in the first direction and the openings are configured to create turbulent flow within the chambers in the second direction. The valve may comprises a main flow path through the valve, the main flow path including a plurality of branches, wherein fluid flowing in the second direction through the main flow path through the valve is diverted to flow through the plurality of branches to impede the flow of fluid in comparison to fluid flowing in the first direction through the main flow path through the valve. The valve may comprise an insert that may be inserted into the body of the plug. The valve may be an integral part of the flow path of the body of the plug.
One embodiment is a method comprising providing a body having an internal flow path that may be positioned within a bore of the wellbore and providing a sealing element on an exterior portion of the body, wherein the sealing element selectively creates a seal between a portion of the wellbore and the body. The method comprises providing a valve in communication with the internal flow path of the body, the valve permitting fluid to flow in a first direction through the internal flow path and permitting fluid to flow in a second direction through the internal flow path, wherein the valve inhibits the flow of fluid in the second direction with respect to the flow of fluid in the first direction.
The method may comprise providing a main flow path through the valve in communication with the internal flow path and providing a plurality of projections along the main flow path. The method may comprise providing a plurality of secondary flow paths in communication with the main flow path, wherein fluid flowing in the first direction flow substantially along the main flow path and wherein the plurality of projections divert fluid flowing in the second direction to flow through the plurality of the secondary flow paths.
The method may comprise inserting an insert into the body, wherein the valve is formed in the insert. The method may comprise manufacturing the insert on a 3D printer. The method may comprise positioning the body within a wellbore, creating a seal between the body and a tubular within the wellbore, and pumping fluid down the wellbore, wherein the valve increases a pressure within the wellbore above the body. The method may comprise hydraulically fracturing a formation of the wellbore positioned above the body by continuing to pump fluid down the wellbore.
One embodiment is a valve for a plug comprising an inserted to be inserted into a plug body, the insert having a flow path in communication with a flow path through the body, wherein the insert flow path permits fluid to flow in a first direction through the insert flow path and permits fluid to flow in a second direction through the insert flow path, wherein the insert flow path inhibits the flow of fluid in the second direction with respect to the flow of fluid in the first direction.
The insert flow path may comprise a main flow path, a plurality of projections along the main flow path, and a plurality of secondary flow paths in communication with the main flow path. Fluid flowing in the first direction may flow substantially along the main flow path and the plurality of projections may divert fluid flowing in the second direction to flow through the plurality of the secondary flow paths. The insert may be a 3D printed part. The insert may comprise a flow path having a plurality of chambers, the chambers being in communication within each other via a plurality of openings, wherein the openings are configured to permit substantially smooth fluid flow through the flow path in the first direction and the openings are configured to create turbulent flow within the chambers in the second direction.

BRIEF DESCRIPTION OF THE DRAWINGS

FIG. 1 shows an embodiment of a plug having a valve positioned along a flow path through the frac plug.

FIG. 2 shows a perspective close up view of one embodiment of a plug having a valve positioned along a flow path through the plug.

FIG. 3 shows an embodiment of an insert for a plug.

FIG. 4A is an embodiment of an insert for a plug showing fluid flow through the insert from a first direction of the insert.

FIG. 4B is an embodiment of the insert of FIG. 4A showing fluid flow through the insert from a second direction of the insert.

FIG. 5 shows an embodiment of an insert for a plug.

FIG. 6 one embodiment of frac plugs positioned within a wellbore.

FIG. 7 shows a flow chart of one embodiment of a method of the present disclosure.

While the disclosure is susceptible to various modifications and alternative forms, specific embodiments have been shown by way of example in the drawings and will be described in detail herein. However, it should be understood that the disclosure is not intended to be limited to the particular forms disclosed. Rather, the intention is to cover all modifications, equivalents and alternatives falling within the scope of the invention as defined by the appended claims.

DETAILED DESCRIPTION

FIG. 1 shows a cross-section view of one embodiment of a plug 100. The plug 100 may be any plug or packer used to create a seal within a wellbore that permits fluid flow through the plug or packer as described herein. For example, the plug 100 may be an open wellbore packer that includes a valve 200 described herein that permits fluid flow in both direction through the packer, but impedes one direction of flow with respect to the other direction of flow.
The plug 100 may be, but is not limited to, a frac plug used to hydraulically fracture a wellbore formation. The plug 100, hereinafter referred to as a frac plug, includes a body 110 with a bore, internal flow path, or inner flow path 120, hereinafter referred to an internal flow path, which permits fluid to flow through the body 110 of the frac plug 100. The frac plug 100 includes a valve 200 having a main flow path 220 that is in fluid communication with the internal flow path 120 to permit fluid to flow through the frac plug 100 in a first direction, indicated by arrow A on FIG. 1. The main flow path 220 also permits fluid to flow through the frac plug 100 in a second direction, indicated by arrow B on FIG. 1. The valve 200 of the frac plug 100 is a solid state device. As used herein, solid state device means that there are no moving parts. A moving part of a valve may fail and/or wear out due to repeated movement as the valve is repeatedly actuated. Further, debris and/or particulates within a wellbore may prevent the moving part of a valve from actuating properly, which may require the premature replacement of the valve. Thus, a solid state valve 200 may be preferred.
The frac plug 100 may include a slips 130 and cones 140 used to secure the frac plug 100 at a desired location within the wellbore. The slips 130 may be configured to engage a tubular, such as casing or a production tubular, positioned within a wellbore. As discussed above, the plug 100 may also be a packer configured to be positioned in an openhole wellbore. The frac plug 100 may include a sealing element 150 connected to the exterior of the body 110. The sealing element 150 may be actuated to create a seal between the exterior of the body 110 and a portion of the wellbore. When set within a wellbore with the sealing element 150 actuated, fluid may pass the frac plug 100 only through the internal flow path 120 of the frac plug 100 and the main flow path 220 of the valve 200. The number, configuration, and location of the slips 130, cones 140, and sealing element 150 are shown for illustrative purposes and may be varied depending on the application as would be appreciated by one of ordinary skill in the art having the benefit of this disclosure.
The valve 200 of the frac plug 100 is configured to impede or provide higher resistance for the fluid flowing in one direction through the main bore 220 with respect to fluid flowing in the other direction through the main bore 220. For example, the valve 200 may be a Tesla valve that is configured to provide an increase flow resistance in one direction. As shown in FIG. 1, the valve 200 may include a plurality of projections 230 positioned along the main flow path 220 through the valve 200. Each projection 230 may be configured to divert at least a portion of the fluid flowing in one direction to flow into a secondary flow path 240 as shown in FIG. 2.
FIG. 2 shows that the leading edge 231 of each projection may be configured to divert at least a portion of fluid flowing in the second direction, indicated by arrow B, to flow into a second flow path 240 around the projection 230. The projections 230 may divert the majority of fluid flow, a substantial amount of fluid flow, or a portion of fluid flow into the secondary flow path 240 as would be appreciated by one of ordinary skill in the art having the benefit of this disclosure. The secondary flow paths 240 positioned along the main flow path 220 through the valve 200 increases the overall distance fluid flowing in the second direction B must travel to exit the valve 200 with respect to the total distance traveled by fluid flowing in the first direction A. A substantial portion of the fluid flowing in the first direction A may travel along the main flow path 220 along the entire length of the valve 200. The projections 230 may be configured to point in the same direction as the first direction A and thus, the projections may not divert the fluid flowing in the first direction A as it does to fluid flowing in the second direction B. As discussed herein, the first direction A may be fluid flowing from beneath the frac plug 100 and the second direction B may be fluid flowing from above the frac plug 100. The direction of the projections 230 within the valve 200 could be reversed if an application required increased fluid flow from below the frac plug 100 in comparison to flow from above the frac plug 100 as would be appreciated by one of ordinary skill in the art having the benefit of this disclosure.
The increase in total distance traveled by fluid to exit the plug 100 in the second direction B may not be the only factor for having an increased flow resistance. For example, the secondary flow paths 240 may be designed so that the return portion 241 of the secondary flow path 240 creates turbulent flow within the main flow path 220. The return portion 241 may be designed to return the fluid to the main flow path 220 at an orientation opposing the direction of flow as shown in FIG. 2. In other words, the return portions 241 may be configured to turn the fluid flow against itself. The number, configuration, and location of the projections 230, secondary flow paths 240, and return portions 241 are for illustrative purposes only and may be varied within the scope of the disclosure as would be appreciated by one of ordinary skill in the art having the benefit of this disclosure.
The valve 200 may be an integral part of the frac plug 100. Alternatively, the valve 200 may be manufactured as an insert that may be inserted into the internal flow path 120 of the frac plug 100. FIG. 3 shows an embodiment of a valve 200 as an insert. The body 210 of the valve 200 includes a main flow path 220 that extends the length of the body 210. The valve 200 includes a plurality of projections 230 positioned along the main flow path 220. As discussed above, the leading edges 231 of the projections 230 may divert a portion of fluid flowing in direction B to flow along a secondary flow path 240 around the projection 230, which will reenter the main flow path 220 via return paths 240. The return paths 240 may be configured to divert the flow fluid at an angle that opposes flow in the direction B through the main flow path 220, which may create turbulent flow within the main flow path 220. Fluid flowing in direction A may substantially flow through the main flow path 220 along the entire length of the valve 200. The valve 200 may be made up of various materials as would be appreciated by one of ordinary skill in the art having the benefit of this disclosure. For example, the valve 200 may be manufactured using a 3D printer.
FIG. 4A shows an embodiment of a valve 300 as an insert with arrows indicating the flow of fluid from the first direction from opening 321 to opening 322. The body 310 of the valve 300 includes a main flow path 320 that extends the length of the body 310. The valve 300 includes a plurality of projections 330 positioned along the main flow path 320. The valve 300 also includes a plurality of branches 340 that are connected to the main flow path 320. The leading edges 331 of each projections 330 may be configured to divert a portion of fluid flowing from opening 322 to opening 321 away from the main flow path 230, but not divert fluid flowing from opening 321 to opening 322. As indicated by the arrows on FIG. 4A, fluid flowing from opening 321 to opening 322 may take the shortest path through the valve 300.
FIG. 4B shows the valve 300 of FIG. 4A, but with fluid flowing from opening 322 to opening 321. The arrows on FIG. 4B indicate that the leading edges 331 or projections 330 divert a portion of the fluid flow into the branches 340. The return paths 341 of each branch 340 may be configured to change the direction of the fluid flow, which may create turbulent flow within the valve 300. The projections 330 and return flow paths 341 of the valve 300 may be designed to impede fluid flow through the valve 300 when flowing from opening 322 to opening 321 with respect to fluid flowing in the opposite direction. Fluid flowing from opening 321 to opening 322 may be in a first or uphole direction and fluid flowing from opening 322 to 321 may be in a second or downhole direction, as discussed herein. The valve 300 may be made up of various materials as would be appreciated by one of ordinary skill in the art having the benefit of this disclosure. For example, the insert may be manufactured using a 3D printer. FIG. 4A and FIG. 4B show the valve 300 as an insert, but the valve 300 could be integral to a frac plug 100 as would be appreciated by one of ordinary skill in the art having the benefit of this disclosure.
FIG. 5 shows on embodiment of a valve 400 configured as an insert for a frac plug 100. The valve 400 is shown as an insert for illustrative purposes only and may be formed as an integral part of a frac plug 100 as would be appreciated by one of ordinary skill in the art having the benefit of this disclosure. The valve 400 includes a plurality of chambers or cavities 450A, 450B, 450C, and 450D in communication with a main flow bore 420. The chambers 450A, 450B, 450C, and 450D and the main flow bore 420 are in communication within a first opening 421 and a second opening 422 in the body 410. The chambers 450A, 450B, 450C, and 450D, main flow bore 420, first opening 421, and second opening 422 may be configured to increase fluid flow resistance for fluid flowing in one direction through the valve 400 with respect to fluid flowing through the valve 400 in the other direction. For example, the valve 400 may impede the fluid flowing from the second opening 422 to the first opening 421 with respect to the fluid flowing from the first opening 421 to the second opening 422 as discussed herein.
The second opening 422 may be configured to be larger in comparison to the first opening 421. The larger opening 422 in combination with the sloped interface with the first chamber 450A may cause the fluid flow to expand outward as it enters the chamber 450A. The outer recessed portions 452A of the chamber 450A in combination with the opening 455A may create turbulent flow within the valve 400 thus increasing the fluid flow resistance. The opening 455A between chamber 450A and chamber 450B may include an edge or protrusion 451A that diverts fluid flowing towards the first opening 421, but does not divert fluid flowing toward the second opening 422. Likewise, the other chambers 450B, 450C, and 450D may include recess portions 452B, 452C, and 452D also configured to cause turbulent flow. The leading edges 452B, 452C, and 452D may also divert a portion of fluid flowing towards the first opening 421, but not divert fluid flowing towards the second opening 422. The narrow main flow path 420 in combination with the smaller diameter of the first opening 421 may tend to form a smooth narrow flow of fluid flowing towards the second opening 422 as it enters the valve the valve 400 from the first opening 421. The smooth narrow flow of fluid may pass through the openings 455A, 455B, 455C, and 455D without substantial turbulence. Thus, the valve 400 may provide for fluid flow in both directions through the valve 400, but with one direction having a higher fluid flow resistance.
FIG. 6 shows a horizontal wellbore 1 with three frac plugs 100A, 100B, and 100C positioned at different locations along the wellbore 1. Each frac plug 100A, 100B, and 100C has created a seal between the frac plug 100A, 100B, and 100C and the casing 6 of the wellbore 1. As discussed herein, the frac plugs 100A, 100B, and 100C each include a valve 200 that permits fluid to flow through a bore 120 of the frac plug 100A, 100B, and 100C and through a main flow path 220 of the valve 200 of the 100A, 100B, and 100C. The valve 200 is configured to permit fluid to flow down through the frac plug, but the flow in the downward direction will have a great resistance in the flow in the upward direction through the frac plug as discussed herein.
A first frac plug 100A is positioned below a first set of perforations 10A in the casing 6. Likewise, a second frac plug 100B is positioned below a second set of perforations 10B in the casing 6 and a third frac plug 100C is positioned below a third set of perforations 10C in the casing 6. Fluid may be pumped down the wellbore with the frac plugs 100A, 100B, and 100C in place to hydraulically fracture the wellbore formation 5 adjacent each of the perforations 10A, 10B, and 10C.
The higher resistance of fluid flow down of the third or upper frac plug 100C permits the pumping of fluid down the wellbore 1 to create a pressure increase above the frac plug 100C. Fluid can continue to be pumped down the wellbore 1 until the pressure is adequate to hydraulically fracture the formation 5 though the perforations 10C in the casing 6. Thus, the formation 5 may be hydraulically fractured without the need to pump a plug, such as a ball or dart, down the wellbore to be seated to create a seal or inhibit fluid flow, which potentially reduces the time required to fracture each zone. Further, the valve 200 of the frac plug 100C does permit the fluid to flow down through the frac plug 100C so that the formation 5 at second zone may be fractured through perforations 10B in the casing 6 due to the placement of the second frac plug 100B. Likewise, the placement of the first frac plug 10A permits the fracturing of the formation 5 via the perforations 10A. As discussed herein, the valves 200 in each of the frac plugs 100A, 100B, and 100C permits the flow of fluid upwards through the frac plugs 100A, 100B, and 100C. Thus, production of fluids from zones beneath each of the frac plugs 100A, 100B, and 100C may flow up the wellbore 1. The frac plug of the present disclosure may also be used to re-fracture a location that has been previously hydraulically fractured, if necessary.
The frac plug 100 having a valve 200, 300, or 400 of the present disclosure provides a solid state device that may permit the fracturing of a wellbore formation 5 without the need to drop a plug, such as a ball, down the wellbore or actuate a valve. The frac plug 100 having a valve 200, 300, or 400 of the present disclosure permits the production of fluids while positioned within the wellbore. Further, the pressure of a zone below a frac plug 100 having the valve 200, 300, or 400 of the present disclosure will not build up as the pressure will be release due to the upward flow of fluid through the frac plug 100. The number, location, and configuration of the frac plugs 100A, 100B, and 100C of FIG. 6 is for illustrative purposes only and may be varied as would be appreciated by one of ordinary skill in the art having the benefit of this disclosure. For example, as single frac plug 100 may be positioned below a zone to be fractured or any number of frac plugs 100 may be positioned along a wellbore 1. The horizontal wellbore 1 of FIG. 6 is shown for illustrative purposes only as the frac plug 100 of the present disclosure may be used in vertical, horizontal, and/or deviated wellbores as would be appreciated by one of ordinary skill in the art having the benefit of this disclosure.
FIG. 7 shows one embodiment of a method 500 of the present disclosure. Step 510 of the method 500 comprises providing a body having an internal flow path that may be positioned within a wellbore. The method 500 includes providing a sealing element on an exterior portion of the body wherein the sealing element creates a seal within the wellbore at step 520. At step 530, the method 500 comprises providing a valve in communication with the internal flow path of the body, the valve inhibiting fluid to flow in a second direction through the valve with respect to fluid flow in a first direction through the valve. As discussed herein, the valve may be integral to the body or may be comprised of an insert that is positioned into a portion of the body. The method 500 optionally includes step 540 of providing a central flow path through the valve that is in communication with the internal flow path of the body and step 550 of providing a plurality of projections along the central flow path. Option step 560 provide a plurality of secondary flow paths in communication with the central flow path, wherein fluid flowing in the first direction flows along the central flow path and the projections divert fluid flowing in the second direction through the secondary flow paths.
Although this disclosure has been described in terms of certain preferred embodiments, other embodiments that are apparent to those of ordinary skill in the art, including embodiments that do not provide all of the features and advantages set forth herein, are also within the scope of this disclosure. Accordingly, the scope of the present disclosure is defined only by reference to the appended claims and equivalents thereof.

Claims

What is claimed is:

1. A plug comprising:

a body;

at least one sealing element positioned on an exterior of the body, the sealing element configured to create a seal between the body and a portion of a wellbore;

a flow path through an interior of the body; and

a valve positioned along the flow path, the valve permits fluid to flow in a first direction through the flow path and permits fluid to flow in a second direction through the flow path, wherein the valve inhibits the flow of fluid in the second direction with respect to the flow of fluid in the first direction.

2. The plug of claim 1, further comprising at least one setting element positioned on the exterior of the body, the setting element configured to engage a portion of a wellbore.

3. The plug of claim 1, wherein the first direction is from below the body to above the body and wherein the second direction is from above the body to below the body.

4. The plug of claim 1, wherein the valve is a solid state device.

5. The plug of claim 1, wherein the valve further comprises a Tesla valve.

6. The plug of claim 1, wherein the valve further comprises:

a main flow path in communication with the flow path through the interior of the body;

a plurality of projections along the main flow path;

a plurality of secondary flow paths in communication with the main flow path,

wherein fluid flowing in the first direction flows substantially along the main flow path, and

wherein the plurality of projections divert fluid flowing in the second direction to flow through the plurality of the secondary flow paths.

7. The plug of claim 1, wherein the valve further comprises a flow path through the valve having a plurality of chambers, the chambers in communication with each other via a plurality of openings, wherein the openings are configured to permit substantially smooth fluid flow through the flow path in the first direction and the openings are configured to create turbulent flow within the chambers in the second direction.

8. The plug of claim 1, wherein the valve further comprises a main flow path through the valve, the main flow path including a plurality of branches, wherein fluid flowing in the second direction through the main flow path through the valve is diverted to flow through the plurality of branches to impede the flow of fluid in comparison to fluid flowing in the first direction through the main flow path through the valve.

9. The plug of claim 1, wherein the valve further comprises an insert that may be inserted into the body.

10. The plug of claim 1, wherein the valve is an integral part of the flow path of the body.

11. A method comprising:

providing a body having an internal flow path that may be positioned within a bore of a wellbore;

providing a sealing element on an exterior portion of the body, wherein the sealing element selectively creates a seal between a portion of the wellbore and the body; and

providing a valve in communication with the internal flow path of the body, the valve permitting fluid to flow in a first direction through the internal flow path and permitting fluid to flow in a second direction through the internal flow path, wherein the valve inhibits the flow of fluid in the second direction with respect to the flow of fluid in the first direction.

12. The method of claim 11, further comprising:

providing a main flow path through the valve in communication with the internal flow path;

providing a plurality of projections along the main flow path; and

providing a plurality of secondary flow paths in communication with the main flow path,

13. The method of claim 12, wherein providing the valve further comprises inserting an insert into the body, wherein the valve is formed in the insert.

14. The method of claim 13, further comprising manufacturing the insert on a 3D printer.

15. The method of claim 11, further comprising:

positioning the body within a wellbore;

creating a seal between the body and a tubular within the wellbore; and

pumping fluid down the wellbore, wherein the valve increases a pressure within the wellbore above the body.

16. The method of claim 15, further comprising hydraulically fracturing a formation of the wellbore positioned above the body by continuing to pump fluid down the wellbore.

17. A valve for a plug comprising:

an insert to be inserted into a plug body, the insert having flow path in communication with a flow path through the body, wherein the insert flow path permits fluid to flow in a first direction through the insert flow path and permits fluid to flow in a second direction through the insert flow path, wherein the insert flow path inhibits the flow of fluid in the second direction with respect to the flow of fluid in the first direction.

18. The valve of claim 17, wherein the insert flow path further comprises:

a main flow path;

a plurality of projections along the main flow path; and

a plurality of secondary flow paths in communication with the main flow path,

19. The valve of claim 14, wherein the insert is a 3D printed part.

20. The valve of claim 14, wherein the insert further comprises a flow path having a plurality of chambers, the chambers in communication with each other via a plurality of openings, wherein the openings are configured to permit substantially smooth fluid flow through the flow path in the first direction and the openings are configured to create turbulent flow within the chambers in the second direction.