PRODUCTION SUB INCLUDING DEGRADABLE ORIFICE
The present disclosure, in at least one aspect, provides a production sub, a well system, and a method. The production sub, in one aspect, includes a tubular having a length (l), an inside diameter (ID), an outside diameter (OD), and a sidewall thickness (t), a plurality of production ports extending through the sidewall thickness (t) and coupling the inside diameter (ID) and the outside diameter (OD), and a fluid flow assembly positioned in each of the plurality of production ports. Each fluid flow assembly, in one aspect, includes a radially interior burst disc, as well as a degradable fluid flow orifice positioned radially outside of the radially interior burst disk, the degradable fluid flow orifice configured to degrade over time after the radially interior burst disc has burst to increase a flow volume through the production port.
In cementing casing or liners (both referred to hereinafter as “casing”) in wellbores (a process known as primary cementing), a cement slurry is pumped downwardly through the casing to be cemented and then upwardly into the annulus between the casing and the walls of the wellbore. Upon setting, the cement bonds the casing to the walls of the wellbore and restricts fluid movement between formations or zones penetrated by the wellbore. Such a cementing operation is particularly useful and/or necessary in the lateral wellbores of multilateral wells, and particularly at the junction between the lateral wellbores and the main wellbore.
Prior to a primary cementing operation, the casing is suspended in a wellbore (e.g., main wellbore or lateral wellbore) and both the casing and the wellbore are usually filled with drilling fluid. In order to reduce contamination of the cement slurry at the interface between it and the drilling fluid, a displacement plug for sealingly engaging the inner surfaces of the casing may be pumped ahead of the cement slurry whereby the cement slurry is separated from the drilling fluid as the cement slurry and drilling fluid ahead of it are displaced through the casing. The displacement plug wipes the drilling fluid from the walls of the casing and maintains a separation between the cement slurry and drilling fluid until the plug lands on a float collar attached near the bottom end of the casing.
The displacement plug, which precedes the cement slurry and separates it from drilling fluid is referred to herein as the “bottom plug.” When the predetermined required quantity of the cement slurry has been pumped into the casing, a second displacement plug, referred to herein as the “top plug”, may be released into the casing to separate the cement slurry from additional drilling fluid or other displacement fluid used to displace the cement slurry. In certain situations, the bottom plug is not used, but the top plug is.
When the bottom plug lands on the float collar attached to the casing, a valve mechanism opens which allows the cement slurry to proceed through the plug and the float collar upwardly into the annular space between the casing and the wellbore. The design of the top plug is such that when it lands on the bottom plug it shuts off fluid flow, which prevents the displacement fluid from entering the annulus. After the top plug lands on the bottom plug, the pumping of the displacement fluid into the casing is often continued whereby the casing is pressured up and the casing and associated equipment including the pump are pressure tested for leaks or other defects.
Reference is now made to the following descriptions taken in conjunction with the accompanying drawings, in which:
In the drawings and descriptions that follow, like parts are typically marked throughout the specification and drawings with the same reference numerals, respectively. The drawn figures are not necessarily to scale. Certain features of the disclosure may be shown exaggerated in scale or in somewhat schematic form and some details of certain elements may not be shown in the interest of clarity and conciseness. The present disclosure may be implemented in embodiments of different forms.
Specific embodiments are described in detail and are shown in the drawings, with the understanding that the present disclosure is to be considered an exemplification of the principles of the disclosure, and is not intended to limit the disclosure to that illustrated and described herein. It is to be fully recognized that the different teachings of the embodiments discussed herein may be employed separately or in any suitable combination to produce desired results.
Unless otherwise specified, use of the terms “connect,” “engage,” “couple,” “attach,” or any other like term describing an interaction between elements is not meant to limit the interaction to direct interaction between the elements and may also include indirect interaction between the elements described.
Unless otherwise specified, use of the terms “up,” “upper,” “upward,” “uphole,” “upstream,” or other like terms shall be construed as generally away from the bottom, terminal end of a well, regardless of wellbore orientation; likewise, use of the terms “down,” “lower,” “downward,” “downhole,” “downstream,” or other like terms shall be construed as generally toward the bottom, terminal end of a well, regardless of the wellbore orientation. Use of any one or more of the foregoing terms shall not be construed as denoting positions along a perfectly vertical axis. Unless otherwise specified, use of the term “subterranean formation” shall be construed as encompassing both areas below exposed earth and areas below earth covered by water such as ocean or fresh water.
The present disclosure has acknowledged that certain problems exist when using a production sub coupled to a wellbore liner. Typically, production subs include a plurality of production ports therein, for example to receive production fluid from surrounding subterranean formations. Often, the production ports will initially include a pressure barrier (e.g., such as a burst disc) therein, which allows the wellbore to be cemented prior to production. After completing the cementing process (e.g., days, months, years after completing the cementing process), the pressure barriers may be removed, such that the surrounding subterranean formation may be fractured and the production ports may receive production fluid.
The present disclosure has recognized, for the first time, that production subs employing the plurality of production ports may suffer from a pressure balance situation. Specifically, the present disclosure has recognized that the production sub may achieve a pressure balance situation prior to all of the pressure barriers breaking (e.g., bursting when the pressure barriers are burst discs). In such a situation, one or more of the pressure barriers may remain intact, thereby limiting the flow area when producing through the production ports at a later point in time.
Given this recognition, the present disclosure has devised an improved fluid flow assembly to be positioned in each of the production ports. In at least one embodiment, the fluid flow assembly includes a radially interior burst disc, a radially exterior burst disc, and a sealing member positioned in a chamber created between the radially interior burst disc and the radially exterior burst disc. In accordance with this embodiment, the fluid flow assembly further includes a sealing member seat located in the chamber proximate the radially exterior burst disc, the sealing member configured to engage with the sealing member seat as fluid is pushing the sealing member radially outward. Thus, each of the radially interior burst discs of each of the production ports may burst prior to the production sub achieving a pressure balance situation, for example as the sealing members and sealing member seats maintain the pressure differential during this time. In at least one embodiment, the sealing members unseat from the sealing member seats (e.g., fall from, dissolve, erode, etc.) at a later point in time, thereby increasing a flow volume through the production ports.
In at least one other embodiment, the fluid flow assembly includes a radially interior burst disc, and a degradable fluid flow orifice positioned radially outside of the radially interior burst disk. The degradable fluid flow orifice, in this embodiment, is configured to provide a restriction that maintains the pressure differential until all of the radially interior burst discs have burst. However, the degradable fluid flow orifice is configured to degrade over time (e.g., days, months, years, etc.), such as to increase a flow volume through the production port.
The present disclosure has further recognized that in certain circumstances after pumping cement into a liner, cement and/or debris (e.g., hardened cement) existing in an annulus between the wellbore and the liner may fall into the plurality of production ports of the production sub. In the first improved fluid flow assembly discussed above, the radially exterior burst disc keeps the cement and/or debris from the plurality of production ports until the cement may cure. In the second improved fluid flow assembly discussed above, a dissolvable plug may be positioned within each of the degradable fluid flow orifices to keep the cement and/or debris from the plurality of production ports until the cement may cure. In this embodiment, the dissolvable plug dissolves over time (e.g., days, months, etc.), thereby allowing the degradable fluid flow orifices to perform their intended function.
As shown, a main wellbore 140 has been drilled through the various earth strata, including the subterranean formation 110. The term “main” wellbore is used herein to designate a wellbore from which another wellbore is drilled. It is to be noted, however, that a main wellbore 140 does not necessarily extend directly to the earth's surface, but could instead be a branch of yet another wellbore. A casing string 150 may be at least partially cemented within the main wellbore 140. The term “casing” is used herein to designate a tubular string used to line a wellbore. Casing may actually be of the type known to those skilled in the art as a “liner” and may be made of any material, such as steel or composite material and may be segmented or continuous, such as coiled tubing.
In the illustrated embodiment, a lateral wellbore 160 extends from the main wellbore 140. The term “lateral” wellbore is used herein to designate a wellbore that is drilled outwardly from its intersection with another wellbore, such as a main wellbore. Moreover, a lateral wellbore may have another lateral wellbore drilled outwardly therefrom. In the illustrated embodiment, the lateral wellbore 160 includes a lateral wellbore liner 170. Accordingly, a junction 180 exists where the main wellbore 140 (e.g., the casing string 150) and the lateral wellbore 160 (e.g., the lateral wellbore liner 170) intersect. In accordance with at least one embodiment of the disclosure, cement surrounds the junction 180.
In accordance with another embodiment of the disclosure, a production sub 190 may be positioned in one or both of the casing string 150 or lateral wellbore liner 170. The production sub 190, in accordance with one embodiment, is configured to receive production fluid from a subterranean formation 110 surrounding one or both of the casing string 150 or lateral wellbore liner 170. The production subs 190, in one embodiment, each including a plurality of production ports, the plurality of production ports each having a plurality of fluid flow assembly designed, manufactured and/or operated according to one or more embodiments of the disclosure located therein.
Turning to
In the illustrated embodiment of
In the embodiment of
In the illustrated embodiment of
In the embodiment of
As the chamber 250 is a fluid tight chamber in one embodiment, the fluid tight chamber prevents the dissolvable sealing member from dissolving prior to the radially interior burst disc 240 bursting, or alternatively prior to the radially interior burst disc 240 and the radially exterior burst disc 245 bursting. In yet another embodiment, the sealing member 260 is not configured to dissolve, but may fall back into the ID of the tubular 210 at a later point in time, for example after the radially interior burst disc 240 and the radially exterior burst disc 245 are no longer intact.
In the illustrated embodiment, the sealing member seat 270 is part of housing 275 located within the production port 210. In one or more embodiments, the fluid flow assembly 230 may include one or more one or more sealing elements 280 positioned between the housing 275 and the production port 210. The one or more sealing elements 280 may be any known or subsequently discovered sealing element and remain within the scope of the disclosure.
The fluid flow assembly 230 may be assembled within the production port 220 using a variety of different methods. In at least one embodiment, however, the radially interior burst disc 240 is first placed within the production port 220. Thereafter, the sealing member 260 may be dropped within the production port 220 upon the radially interior burst disc 240, followed by the housing 275 and radially exterior burst disc 245. Thereafter, a coupling member 285 may be secured within the production port 220, thereby holding the other features of the fluid flow assembly 230 therein. In at least one embodiment, the coupling member 285 is threadingly engaged with the production port 220. In yet another embodiment, the coupling member 285 is press fit within the production port 220, held with a screw within the production port 220, etc., among other mechanisms for coupling the two. In yet another embodiment, the radially interior burst disc 240, the sealing member 260, the housing 275 and the radially exterior burst disc 245 are a single premanufactured assembly. Accordingly, the single premanufactured assembly could be insert within the production port 220, and then held in place using the coupling member 285 or another similar feature.
Turning to
With initial reference to
With continued reference to
With continued reference to
With continued reference to
With continued reference to
With continued reference to
With continued reference to
With continued reference to
With continued reference to
With continued reference to
Turning to
Turning to
In the illustrated embodiment of
In the embodiment of
In the embodiment of
In at least one embodiment, the degradable fluid flow orifice 550 is an erodible fluid flow orifice having a hardness less than a hardness of the tubular 510. Accordingly, over time, the erodible fluid flow orifice would erode away, in doing so increasing a flow volume through the production ports 520 of the production sub 500. The erosion may occur, in one embodiment, during a fracturing phase, or in an alternative embodiment, during the production phase. In at least one embodiment, a time that it takes for the erodible fluid flow orifice to fully erode after the radially interior burst discs 540 have burst may be tailored, for example changing the size and/or material properties of the erodible fluid flow orifice. Accordingly, the erodible fluid flow orifice, in at least one embodiment, has a hardness at least 20% less than a hardness of the tubular 510. The erodible fluid flow orifice, in at least one other embodiment, has a hardness at least 50% less than a hardness of the tubular 510, and in yet another embodiment at least 80% less than a hardness of the tubular 510. Furthermore, in at least one embodiment, the erodible fluid flow orifice comprises a low alloy steel, an Aluminum alloy, a Brass alloy, a Copper alloy, a Magnesium alloy, an Iron-Carbon alloy, among others.
In yet another embodiment, the degradable fluid flow orifice 550 is a dissolvable fluid flow orifice. Accordingly, over time, the dissolvable fluid flow orifice would dissolve away, in doing so increasing a flow volume through the production ports 520 of the production sub 500. In at least one embodiment, a time that it takes for the dissolvable fluid flow orifice to fully dissolve after the radially interior burst discs 540 have burst may be tailored, for example changing the size and/or material properties of the dissolvable fluid flow orifice. In at least one other embodiment, a protective layer may be positioned about the dissolvable fluid flow orifice to increase an amount of time that passes prior to dissolving. Those skilled in the art understand the various different materials and/or protective layers that might be used to achieve the desired purpose of the dissolvable fluid flow orifice.
In the embodiment of
The degradable fluid flow orifice 550, and the dissolvable plug 560 in the illustrated embodiment, may form part of a housing 570 located within the production port 520. In accordance with this embodiment, one or more sealing elements 580 may be positioned between the degradable fluid flow orifice 550 and the production port 520, or alternatively between the housing 570 and the production port 520. The one or more sealing elements 580 may be any known or subsequently discovered sealing element and remain within the scope of the disclosure.
The fluid flow assembly 530 may be assembled within the production port 520 using a variety of different methods. In at least one embodiment, however, the radially interior burst disc 540 is first placed within the production port 520. Thereafter, the housing 570 may be dropped within the production port 520 upon the radially interior burst disc 540, followed by the degradable fluid flow orifice 550 having the dissolvable plug 560 therein. In at least one embodiment, the degradable fluid flow orifice 550 is threadingly engaged with the production port 220, thereby holding the entire fluid flow assembly 530 within the production port 520. In yet another embodiment, the degradable fluid flow orifice 550 is press fit within the production port 220, held with a screw within the production port 520, etc., among other mechanisms for coupling the two. In yet another embodiment, a coupling member (now shown, but similar to the coupling member 285 of
Turning to
With initial reference to
With continued reference to
With continued reference to
With continued reference to
With continued reference to
With continued reference to
With continued reference to
With continued reference to
With continued reference to
With continued reference to
With continued reference to
The embodiment of
Aspects Disclosed Herein Include:
-
- A. A production sub, the production sub including: 1) a tubular having a length (l), an inside diameter (ID), an outside diameter (OD), and a sidewall thickness (t); 2) a plurality of production ports extending through the sidewall thickness (t) and coupling the inside diameter (ID) and the outside diameter (OD); and 3) a fluid flow assembly positioned in each of the plurality of production ports, each fluid flow assembly including: a) a radially interior burst disc; b) a radially exterior burst disc; c) a sealing member positioned in a chamber created between the radially interior burst disc and the radially exterior burst disc; and d) a sealing member seat located in the chamber proximate the radially exterior burst disc, the sealing member configured to engage with the sealing member seat as fluid is pushing the sealing member radially outward.
- B. A well system, the well system including: 1) a wellbore extending through one or more subterranean formations; 2) production tubing located within the wellbore; 3) a production sub coupled to the production tubing, the production sub including: a) a tubular having a length (l), an inside diameter (ID), an outside diameter (OD), and a sidewall thickness (t); b) a plurality of production ports extending through the sidewall thickness (t) and coupling the inside diameter (ID) and the outside diameter (OD); and c) a fluid flow assembly positioned in each of the plurality of production ports, each fluid flow assembly including: i) a radially interior burst disc; ii) a radially exterior burst disc; iii) a sealing member positioned in a chamber created between the radially interior burst disc and the radially exterior burst disc; and iv) a sealing member seat located in the chamber proximate the radially exterior burst disc, the sealing member configured to engage with the sealing member seat as fluid is pushing the sealing member radially outward.
- C. A method, the method including: 1) forming a wellbore through one or more subterranean formations; and 2) positioning production tubing having a production sub coupled thereto within the wellbore, the production sub including: a) a tubular having a length (l), an inside diameter (ID), an outside diameter (OD), and a sidewall thickness (t); b) a plurality of production ports extending through the sidewall thickness (t) and coupling the inside diameter (ID) and the outside diameter (OD); and c) a fluid flow assembly positioned in each of the plurality of production ports, each fluid flow assembly including: i) a radially interior burst disc; ii) a radially exterior burst disc; iii) a sealing member positioned in a chamber created between the radially interior burst disc and the radially exterior burst disc; and iv) a sealing member seat located in the chamber proximate the radially exterior burst disc, the sealing member configured to engage with the sealing member seat as fluid is pushing the sealing member radially outward.
- D. A production sub, the production sub including: 1) a tubular having a length (l), an inside diameter (ID), an outside diameter (OD), and a sidewall thickness (t); 2) a plurality of production ports extending through the sidewall thickness (t) and coupling the inside diameter (ID) and the outside diameter (OD); and 3) a fluid flow assembly positioned in each of the plurality of production ports, each fluid flow assembly including: a) a radially interior burst disc; and b) a degradable fluid flow orifice positioned radially outside of the radially interior burst disk, the degradable fluid flow orifice configured to degrade over time after the radially interior burst disc has burst to increase a flow volume through the production port.
- E. A well system, the well system including: 1) a wellbore extending through one or more subterranean formations; 2) production tubing located within the wellbore; 3) a production sub coupled to the production tubing, the production sub including: a) a tubular having a length (l), an inside diameter (ID), an outside diameter (OD), and a sidewall thickness (t); b) a plurality of production ports extending through the sidewall thickness (t) and coupling the inside diameter (ID) and the outside diameter (OD); and c) a fluid flow assembly positioned in each of the plurality of production ports, each fluid flow assembly including: i) a radially interior burst disc; and ii) a degradable fluid flow orifice positioned radially outside of the radially interior burst disk, the degradable fluid flow orifice configured to degrade over time after the radially interior burst disc has burst to increase a flow volume through the production port.
- F. A method, the method including: 1) forming a wellbore through one or more subterranean formations; and 2) positioning production tubing having a production sub coupled thereto within the wellbore, the production sub including: a) a tubular having a length (l), an inside diameter (ID), an outside diameter (OD), and a sidewall thickness (t); b) a plurality of production ports extending through the sidewall thickness (t) and coupling the inside diameter (ID) and the outside diameter (OD); and c) a fluid flow assembly positioned in each of the plurality of production ports, each fluid flow assembly including: i) a radially interior burst disc; and ii) a degradable fluid flow orifice positioned radially outside of the radially interior burst disk, the degradable fluid flow orifice configured to degrade over time after the radially interior burst disc has burst to increase a flow volume through the production port.
Aspects A, B, C, D, E and F may have one or more of the following additional elements in combination: Element 1: wherein the sealing member is a dissolvable sealing member. Element 2: wherein the dissolvable sealing member comprises a Magnesium based alloy, an Aluminum based alloy, a (PGA) Polyglycolic acid polymer, a (PLA) Polylactic acid polymer, or a (PHBV) Poly hydroxybutyrate-co-Hydroxy valerate polymer. Element 3: wherein the chamber is a fluid tight chamber, the fluid tight chamber preventing the dissolvable sealing member from dissolving prior to the radially interior burst disc bursting. Element 4: wherein the radially interior burst disc is configured to have a higher ID burst rating and a lower OD burst rating. Element 5: wherein the radially exterior burst disc is configured to have a higher OD burst rating and a lower ID burst rating. Element 6: wherein the fluid flow assembly further includes a sealing member trap located in the chamber proximate the radially interior burst disc, the sealing member trap configured to prevent the sealing member from falling back into the tubular during one or more pressure cycles. Element 7: wherein the sealing member seat is part of housing located within the production port. Element 8: further including one or more sealing elements positioned between the housing and the production port. Element 9: wherein the plurality of production ports include a first set of radially spaced apart production ports and a second set of radially spaced apart production ports, the first and second sets axially offset from one another along the length (l). Element 10: wherein the production sub includes a first production port having a first fluid flow assembly therein and a second production port having a second fluid flow assembly therein. Element 11: further including applying a first pressure to the production sub, the first pressure bursting a first radially interior burst disc and a first radially exterior burst disc of the first fluid flow assembly, and then applying a second pressure to the production sub, the second pressure bursting a second radially interior burst disc and a second radially exterior burst disc of the second fluid flow assembly while a first sealing member of the first fluid flow assembly is seat against a first sealing member seat of the first fluid flow assembly. Element 12: wherein the first sealing member is a first dissolvable sealing member, and further including a second dissolvable sealing member located between the second radially interior burst disc and the second radially exterior burst disc. Element 13: further including dissolving the first dissolvable sealing member and the second dissolvable sealing member after bursting the second radially interior burst disc and the second radially exterior burst disc. Element 14: further including producing hydrocarbons from the subterranean formation, through the first and second production ports having the dissolved first and second sealing members, and into the tubular. Element 15: wherein the degradable fluid flow orifice is an erodible fluid flow orifice having a hardness less than a hardness of the tubular. Element 16: wherein the erodible fluid flow orifice comprises a low alloy steel, an Aluminum alloy, a Brass alloy, a Copper alloy, a Magnesium alloy, or an Iron-Carbon alloy. Element 17: wherein the degradable fluid flow orifice is an erodible fluid flow orifice having a hardness at least 20% less than a hardness of the tubular. Element 18: wherein the degradable fluid flow orifice is a dissolvable fluid flow orifice. Element 19: further including a dissolvable plug sealing the degradable fluid flow orifice. Element 20: wherein the dissolvable plug comprises a Magnesium based alloy, an Aluminum based alloy, a (PGA) Polyglycolic acid polymer, a (PLA) Polylactic acid polymer, or a (PHBV) Poly hydroxybutyrate-co-Hydroxy valerate polymer. Element 21: wherein the degradable fluid flow orifice is part of housing located within the production port. Element 22: further including one or more sealing elements positioned between the housing and the production port. Element 23: wherein the plurality of production ports include a first set of radially spaced apart production ports and a second set of radially spaced apart production ports, the first and second sets axially offset from one another along the length (l). Element 24: wherein the production sub includes a first production port having a first fluid flow assembly therein and a second production port having a second fluid flow assembly therein. Element 25: further including applying a first pressure to the production sub, the first pressure bursting a first radially interior burst disc of the first fluid flow assembly, and then applying a second pressure to the production sub, the second pressure bursting a second radially interior burst disc of the second fluid flow assembly while a first degradable fluid flow orifice of the first fluid flow assembly maintains a pressure differential across the inside diameter (ID) and the outside diameter (OD) of the tubular. Element 26: wherein the first degradable fluid flow orifice is a first erodible fluid flow orifice, and further including a second erodible fluid flow orifice located in the second production port. Element 27: further including fully eroding the first and second erodible fluid flow orifices after bursting the second radially interior burst disc. Element 28: further including producing hydrocarbons from the subterranean formation, through the first and second production ports having the eroded first and second erodible fluid flow orifices.
Those skilled in the art to which this application relates will appreciate that other and further additions, deletions, substitutions and modifications may be made to the described embodiments.
Claims
1. A production sub, comprising:
- a tubular having a length (l), an inside diameter (ID), an outside diameter (OD), and a sidewall thickness (t);
- a plurality of production ports extending through the sidewall thickness (t) and coupling the inside diameter (ID) and the outside diameter (OD); and
- a fluid flow assembly positioned in each of the plurality of production ports, each fluid flow assembly including: a radially interior burst disc; and a degradable fluid flow orifice positioned radially outside of the radially interior burst disk, the degradable fluid flow orifice configured to degrade over time after the radially interior burst disc has burst to increase a flow volume through the production port.
2. The production sub as recited in claim 1, wherein the degradable fluid flow orifice is an erodible fluid flow orifice having a hardness less than a hardness of the tubular.
3. The production sub as recited in claim 2, wherein the erodible fluid flow orifice comprises a low alloy steel, an Aluminum alloy, a Brass alloy, a Copper alloy, a Magnesium alloy, or an Iron-Carbon alloy.
4. The production sub as recited in claim 1, wherein the degradable fluid flow orifice is an erodible fluid flow orifice having a hardness at least 20% less than a hardness of the tubular.
5. The production sub as recited in claim 1, wherein the degradable fluid flow orifice is a dissolvable fluid flow orifice.
6. The production sub as recited in claim 1, further including a dissolvable plug sealing the degradable fluid flow orifice.
7. The production sub as recited in claim 6, wherein the dissolvable plug comprises a Magnesium based alloy, an Aluminum based alloy, a (PGA) Polyglycolic acid polymer, a (PLA) Polylactic acid polymer, or a (PHBV) Poly hydroxybutyrate-co-Hydroxy valerate polymer.
8. The production sub as recited in claim 1, wherein the degradable fluid flow orifice is part of housing located within the production port.
9. The production sub as recited in claim 8, further including one or more sealing elements positioned between the housing and the production port.
10. The production sub as recited in claim 1, wherein the plurality of production ports include a first set of radially spaced apart production ports and a second set of radially spaced apart production ports, the first and second sets axially offset from one another along the length (l).
11. A well system, comprising:
- a wellbore extending through one or more subterranean formations;
- production tubing located within the wellbore;
- a production sub coupled to the production tubing, the production sub including: a tubular having a length (l), an inside diameter (ID), an outside diameter (OD), and a sidewall thickness (t); a plurality of production ports extending through the sidewall thickness (t) and coupling the inside diameter (ID) and the outside diameter (OD); and a fluid flow assembly positioned in each of the plurality of production ports, each fluid flow assembly including: a radially interior burst disc; and a degradable fluid flow orifice positioned radially outside of the radially interior burst disk, the degradable fluid flow orifice configured to degrade over time after the radially interior burst disc has burst to increase a flow volume through the production port.
12. The well system as recited in claim 11, wherein the degradable fluid flow orifice is an erodible fluid flow orifice having a hardness less than a hardness of the tubular.
13. The well system as recited in claim 12, wherein the erodible fluid flow orifice comprises a low alloy steel, an Aluminum alloy, a Brass alloy, a Copper alloy, a Magnesium alloy, or an Iron-Carbon alloy.
14. The well system as recited in claim 11, wherein the degradable fluid flow orifice is an erodible fluid flow orifice having a hardness at least 20% less than a hardness of the tubular.
15. The well system as recited in claim 11, wherein the degradable fluid flow orifice is a dissolvable fluid flow orifice.
16. The well system as recited in claim 11, further including a dissolvable plug sealing the degradable fluid flow orifice.
17. The well system as recited in claim 16, wherein the dissolvable plug comprises a Magnesium based alloy, an Aluminum based alloy, a (PGA) Polyglycolic acid polymer, a (PLA) Polylactic acid polymer, or a (PHBV) Poly hydroxybutyrate-co-Hydroxy valerate polymer.
18. The well system as recited in claim 11, wherein the degradable fluid flow orifice is part of housing located within the production port.
19. The well system as recited in claim 18, further including one or more sealing elements positioned between the housing and the production port.
20. The well system as recited in claim 11, wherein the plurality of production ports include a first set of radially spaced apart production ports and a second set of radially spaced apart production ports, the first and second sets axially offset from one another along the length (l).
21. A method, comprising:
- forming a wellbore through one or more subterranean formations; and
- positioning production tubing having a production sub coupled thereto within the wellbore, the production sub including: a tubular having a length (l), an inside diameter (ID), an outside diameter (OD), and a sidewall thickness (t); a plurality of production ports extending through the sidewall thickness (t) and coupling the inside diameter (ID) and the outside diameter (OD); and a fluid flow assembly positioned in each of the plurality of production ports, each fluid flow assembly including: a radially interior burst disc; and a degradable fluid flow orifice positioned radially outside of the radially interior burst disk, the degradable fluid flow orifice configured to degrade over time after the radially interior burst disc has burst to increase a flow volume through the production port.
22. The method as recited in claim 21, wherein the production sub includes a first production port having a first fluid flow assembly therein and a second production port having a second fluid flow assembly therein.
23. The method as recited in claim 22, further including applying a first pressure to the production sub, the first pressure bursting a first radially interior burst disc of the first fluid flow assembly, and then applying a second pressure to the production sub, the second pressure bursting a second radially interior burst disc of the second fluid flow assembly while a first degradable fluid flow orifice of the first fluid flow assembly maintains a pressure differential across the inside diameter (ID) and the outside diameter (OD) of the tubular.
24. The method as recited in claim 23, wherein the first degradable fluid flow orifice is a first erodible fluid flow orifice, and further including a second erodible fluid flow orifice located in the second production port.
25. The method as recited in claim 24, further including fully eroding the first and second erodible fluid flow orifices after bursting the second radially interior burst disc.
26. The method as recited in claim 25, further including producing hydrocarbons from the subterranean formation, through the first and second production ports having the eroded first and second erodible fluid flow orifices.
Type: Application
Filed: Oct 6, 2022
Publication Date: Apr 11, 2024
Inventors: Ibrahim El Mallawany (Al-Khobar), Sean Canning (Carrollton, TX), Joseph Ray Collins (Carrollton, TX)
Application Number: 17/961,019