Methods and systems for a downhole tool

Abstract

A degradable insert positioned within a nozzle assemble. The degradable insert may have an entirety of its outer surface coated with a barrier that does not allow the degradable insert to degrade due to wellbore fluids. Upon activation, an inner surface of the degradable insert may be exposed, which may allow for the degradation of the insert.

Description

METHODS AND SYSTEMS FOR A DOWNHOLE TOOLBACKGROUND INFORMATIONField of the Disclosure

[0001] Examples of the present disclosure relate to downhole tools. More specifically, embodiments are directed towards a nozzle body assembly installed in a base pipe or a sub, the nozzle body assembly has a shearable insert formed of degradable material, wherein the shearable insert is coated with a barrier or inert material that doesn’t react to well fluid or conditions. Responsive to the shearable insert being activated, an interior - non-coated- surface of the shearable insert, i.e.: the sheared plane, may be exposed, which may allow the exposed portion of the shearable insert to begin degrading from contact to the well bore fluids.Background

[0002] Directional drilling is the practice of drilling non -vertical wells . Horizontal wells tend to be more productive than vertical wells because they allow a single well to reach multiple points across a horizontal axis and it cover more cross sections of the producing formation without the need for additional vertical wells. This makes each well more productive by being able to reach reservoirs across the horizontal axis. While horizontal wells are more productive than conventional wells, horizontal wells are costlier. The casing may be run through the drilled horizontal, vertical, or deviated wells to reach the reservoirs across the horizontal axis.

[0003] The casing may be blank so that the formation behind can be isolated and cemented, then later on a bottom hole assembly can be run to perforate the casing and create a conduit to allow hydrocarbon to flow from the formation to the well and up the surface, the bottom hole assembly may include tubing perforated gun, however, the length and depth of the horizontal well can be mechanically prohibitive due to buckling of the sting which may not allow the perforating guns to be conveyed to desired depth. Also, the cost may be too elevated that makes this operation non-economic.

[0004] In other embodiments, the casing will include nozzles that are configured to stimulate the wells. These nozzles may be filled with degradable inserts that degrade overtime allowing the casing to be conveyed as a blank casing, hence allowing circulation of cement and other operations to be conducted. After the degradable inserts have dissolved, the nozzles allow the formation to be accessible for production or injection. However, the clock for the degradable inserts becomes active as soon as the casing interacts with any downhole fluid. This means that as soon as the casing is positioned within the wellbore, the degradable inserts are on a timer before they fully dissolve and while the casing is been run in a hole.

[0005] Situations may arise where it takes longer than desired to position the casing downhole . This may cause the nozzles to be exposed before reaching their desired depths. Alternatively, situations arise where the casingis run in a hole quicker than planned. Due to the degradable inserts only being removable after a predetermined amount of time, this may cause unwanted downtime and / or activation of the nozzle taking place in undesired timing.

[0006] Accordingly, needs exist for systems and methods utilizing an on-demand degradable insert formed of degradable material that is coated with a barrier. Responsive to the degradable insert being activated, an interior - non-coated- surface of the shearable insert may be exposed, which may allow the degradable insert to degrade from exposure to the wellbore fluids. Further, certain applications may necessitate establishing a conduit with the formation after the casing being positioned and cemented in the lateral. Consequently, there arises a requirement for a sub equipped with a nozzle capable of facilitating cementing operations through the casing, setting the casing, conducting pressure tests, and subsequently enabling communication with the formation by opening the sub.SUMMARY

[0007] Embodiments disclosed herein describe systems and methods utilizing a degradable insert positioned within a nozzle assembly. The degradable insert may have an entirety of its outer surface coated with a barrier that does not allow any of the degradable insert to degrade due to exposure to wellbore fluids and making the degradable insert unsusceptible to downhole temperature. Upon activation, the inner surfaces of the degradable insert may be exposed, which may allow for the degradation of the insert. To this end, embodiments may allow for on-demand and selective activation of the degradable insert by exposing the internal surfaces of the degradable insert along a fracture plane, wherein the degradation of the degradable insert begins upon reaching sufficient pressure across the degradable insert. Furthermore, embodiments may include a plurality of nozzle assemblies, wherein each of the nozzle assemblies may be positioned within a circumference of the casing, tubing, etc. Each of the degradable inserts may be simultaneously activated while holding pressure within the tubing. Then at a later point, the degradable inserts may all be cleared from the nozzle assemblies due to their degradation, allowing the exposed conduit through the nozzle assemblies. This is different than conventional systems that utilize rupture discs within nozzle assemblies because after activating each rupture disc in conventional systems , the pressure within the tubing drops. This requires increasing the pressure within the tubing to activate further downhole rupture discs.

[0008] Moreover, many well operations in both production and injection wells use cement to seal portions of the well. Delivering the cement to the right location in the well without fouling other portions of the well is an important objective. Many such wells are cemented using liner hangers, sleeves, and screens to deliver the cement to the appropriate place, and the sleeves are used to prevent the cement from entering the screen. The nozzles currently available in the market are unable to meet the needs of the developing markets.

[0009] Accordingly, embodiments require a dissolvable insert that is configured to be positioned on a lip within the casing, a tubular, a loading element, etc. This may facilitate the mounting of the dissolvable insert within the casing, loading element, etc. After the dissolvable insert is mounted within an a nozzle assembly, the nozzle assembly may be coupled with the casing to secure the dissolvable insert within the opening.

[0010] Embodiments may include casing, casing sub, a nozzle assembly, a degradable insert, a seal, and a retaining ring. For simplicity casing, the terms housing, casing, and subs are used interchangeably.

[0011] The casing may be configured to be installed into a well before other tools or equipment is run into the well. The casing may be a pipe that is assembled and inserted into a recently drilled section of a borehole. The casing may include a hollow channel, passageway, or conduit extending from a proximal end of the casing to a distal end of the casing. This passageway may allow fluid to flow through the casing. In embodiments, the casing may be any pipe, tubular body, housing, or sub and it can be installed anywhere in the well or through the whole lateral, or just at the bottom. If used as a sub at the bottom then it could act as a wet shoe sub that allows for testing the casing after cement and later when the dissolvable material dissolves, the sub acts as a conduit that allows pumping of fluid downhole to covey different bottom hole assembly.

[0012] The nozzle assembly may be a device that is configured to emit fluid from the interior of the casing into the exterior of the casing, or vice versa. The nozzle assembly may be configured to emit different types of fluids at different stages of completion. In embodiments, the nozzle assembly may have a proximal end and a distal end relative to the center of the casing. The proximal end of the nozzle assembly may be closer to the central axis of the casing than the distal end of the nozzle assemble, wherein the diameter of the distal end of the nozzle assembly may be smaller than the diameter of the proximal end of the nozzle assembly. In embodiments, the nozzle assembly may be run in hole along with the casing, with the nozzle assembly being threaded or otherwise coupled to the casing. The nozzle assembly may include a first ledge with a first diameter, a second ledge with a second diameter, and a third ledge with a third diameter.

[0013] The first ledge may be configured to receive a distal end of the degradable insert after the degradable insert is activated. This may allow the degradable insert to continue to form a seal across the nozzle assembly after activating the degradable insert until the degradable insert degrades within the nozzle assembly. Furthermore, before activating the degradable insert there may be a gap, space, offset, etc. between the distal end of the degradable insert and the first ledge. This gap may allow a first portion of the degradable insert to move within the nozzle assembly relative to a second portion of the degradable insert, wherein the first portion of the degradable insert may move towards the distal end of the nozzle assembly.

[0014] The second ledge may be configured to receive a proximal end of the degradable insert when positioning the degradable insert within the nozzle assembly. The second ledge may also be configured to secure and hold the second portion of the degradable insert in place after the degradable insert is activated and the firstportion of the degradable insert travels to the first ledge. In embodiments, a diameter across the second ledge may be larger than a diameter across the first ledge.

[0015] The third ledge may be configured to receive and secure a retraining element or retaining ring in place. The retaining ring may be configured to secure the second portion of the degradable insert in place before and after activation of the degradable insert. Furthermore, by the retaining ring securing the degradable insert in place, and press first against the second ledge, a pressure applied across the degradable insert may allow for activation of the degradable insert.

[0016] The degradable insert may be a unitary and unitary plug, formed of a single piece, that is configured to selectively seal the nozzle assembly. The degradable insert may be uniformly formed of degradable material, which is configured to completely degrade after an inner surface of the degradable insert is exposed to wellbore fluid. In embodiments, an entirety of the outer surface the degradable insert may be coated with a barrier that protects and seals the outer surface of the degradable insert. The barrier may allow the exterior surfaces of the degradable insert to interact with wellbore fluids while not initiating the degradation of the degradable insert. However, after the degradable insert is split into two or more uneven pieces, the internal area of the degradable insert associated with a fracture plane may allow the degradable insert to degrade after being exposed to wellbore fluid.

[0017] In some embodiments, a seal, such as an o-ring seal which in some embodiments may be dissolvable O- ring, may be formed between the outer diameter of the degradable insert and the inner surface of the nozzle assembly, wherein the seal may be retained even after activating the degradable insert until the degradable insert degrades within the nozzle. The degradable insert may be configured to be run in the hole within the nozzle assembly, and block the passageway of the nozzle assembly. After sufficient pressure is applied across the degradable insert, the first portion of the degradable insert may be separated from a second portion of the degradable insert, and the first portion may travel to be positioned adjacent to the first ledge. This relative movement between the first portion and the second portion may activate the degradable insert by exposing inner or sheared surfaces of the degradable insert along a fracture plane, wherein the inner surfaces of the degradable insert associated with the fracture plane are not covered / coated by the barrier. Over time, the degradable insert may degrade and no longer block the nozzle assembly. In other embodiments, the O-ring may not be there, and the degradable material outer diameter can form a seal with the inner surface of the nozzle surface via weak threading or metal-to-metal seal that may allow it to seal but not impact shearing value.

[0018] In other words, sufficient pressure applied to the first side of the degradable insert shears or otherwise activates the degradable insert by shifting part of the degradable insert to a second position. Activating the degradable insert exposes the uncoated degradable material along the fracture surface of the degradable insert, allowing the material to degrade from exposure to the well bore fluids. The degradable insert stillblocks the flow path through the nozzle after activation and allows pressure to be maintained across the casing so the casing can be tested or other operations can be carried until the material eventually degrades. This method can allow a plurality of nozzles to be simultaneously activated all at the same time since after activating the first nozzle, pressure can still be held or increased to activate the second, and then third, and more, therefore, instead of only activating the weakest nozzle and immediately opening a flow path and not allowing pressure to be maintained to activate the others.

[0019] To this end, embodiments allow for an on-demand blocking device within a nozzle assembly by initially coating an entirety of the exterior surface of an insert, applying pressure across the insert to activate the insert, and exposing an inner - non-coated surface - of the insert. Subsequently, the insert may decompose, degrade, or disintegrate, while being positioned within the nozzle assembly.

[0020] Further embodiments may include a plurality of nozzle assemblies with degradable inserts that can be activated on demand at different times or simultaneously. Specifically, each of the nozzle assemblies with degradable inserts may be simultaneously activated at the same pressure within the tubing because the degradable inserts hold their seals after being activated. Because the degradable inserts hold their seals after being activated, the pressure within the tubing, casing, sub, etc. will not drop due to the activation of the degradable inserts. The pressure within the tubing may subsequently drop the degradable inserts are dissolved. However, in other embodiments, different degradable inserts may have different activation pressure differentials based on the thickness of the fracture plane of the degradable insert.

[0021] Specific embodiments may be utilized for horizontal multistage completions without utilizing balls or rupture discs. In specific embodiments, the degradable inserts may be initially activating during a first pumping operation while maintaining pressure within the horizontal multistage completion. This may allow for the first pumping operation to be performed in its entirety without any pressure drops across multiple degradable inserts. This may eliminate toe prep operations, and allow for casing pressure testing while providing a full-bore ID across the toe sub, casing, tubing, etc.

[0022] In further embodiments, the housing may be the casing. Specifically, an outer diameter of the casing may be milled to similar or the same geometric properties as the housing described herein. This may limit the number of parts, pieces, etc. needed. After the casing is milled, the degradable insert may be positioned on a ledge of the casing, and a cap may be positioned over the second portion of the degradable insert to retain the degradable insert in place while run in hole. Additionally, the cap may be directly and fixedly coupled to the casing.

[0023] These, and other, aspects of the invention will be better appreciated and understood when considered in conjunction with the following description and the accompanying drawings. The following description, while indicating various embodiments of the invention and numerous specific details thereof, is given by way of illustration and not of limitation. Many substitutions, modifications, additions, or rearrangementsmay be made within the scope of the invention, and the invention includes all such substitutions, modifications, additions, or rearrangements.BRIEF DESCRIPTION OF THE DRAWINGS

[0024] Non-limiting and non-exhaustive embodiments of the present invention are described concerning the following figures, wherein reference numerals refer to like parts throughout the various views unless otherwise specified.

[0025] FIGURE 1 depicts a system utilizing a degradable insert positioned within a nozzle assembly that allows for on-demand activation and subsequent dissolving of the degradable insert, according to an embodiment.

[0026] FIGURE 2 depicts a nozzle assembly after the degradable insert has been activated, according to an embodiment.

[0027] FIGURE 3 depicts a method of utilizing an on-demand seal within a nozzle assembly, according to an embodiment.

[0028] FIGURE 4 depicts a nozzle assembly, according to an embodiment.

[0029] FIGURE 5 depicts a nozzle assembly, according to an embodiment.

[0030] Corresponding reference characters indicate corresponding components throughout the several views of the drawings. Skilled artisans will appreciate that elements in the figures are illustrated for simplicity and clarity and have not necessarily been drawn to scale. For example, the dimensions of some of the elements in the figures may be exaggerated relative to other elements to help improve understanding of various embodiments of the present disclosure. Also, common but we 11 -understood elements that are useful or necessary in a commercially feasible embodiment are often not depicted to facilitate a less obstructed view of these various embodiments of the present disclosure.DETAILED DESCRIPTION

[0031] In the following description, numerous specific details are outlined in order to provide a thorough understanding of the present invention. It will be apparent, however, to one having ordinary skill in the art that the specific detail need not be employed to practice the present invention. In other instances, well- known materials or methods have not been described in detail to avoid obscuring the present invention.

[0032] Turning now to FIGURE 1, FIGURE 1 depicts a system 100 utilizing a degradable insert 120 positioned within a nozzle assembly 105 that allows for on -demand activation and subsequent dissolving of the degradable insert 120. The nozzle assembly 105 may be configured to be positioned downhole within the casing.

[0033] The casing may be configured to be installed into a well before other tools or equipment is run into the well. The casing may be a that is assembled and inserted into a recently drilled section of a borehole. The casing may include a hollow channel, passageway, or conduit extending from a proximal end of the casing to a distal end of the casing. This passageway may allow fluid to flow through the casing. In embodiments, the casing may be any pipe, tubular body, or housing. The hollow channel is used to mount / attach the nozzle assembly 105 to create a temporary barrier that is activated after reaching a certain pressure threshold.

[0034] The nozzle assembly 105 may be a device that is configured to allow fluid to be emitted from the interior of the casing into the exterior of the casing, or vice versa. The nozzle assembly 105 maybe radially installed within the casing, such that the nozzle assembly does not block fluid flow through a central axis of the casing. The nozzle assembly 105 may be configured to emit different types of fluids at different stages of completion. The nozzle assembly 105 may be positioned within the casing, to emit fluid in a radial, orthogonal, or tangential direction relative to a central axis of the casing. In specific embodiments, the nozzle assembly 105 may be directly formed within the casing by milling the casing. In embodiments, a plurality of nozzle assemblies 105 may be positioned within or directly formed on the casing at the same radial offset and / or at different positions along the central axis of the casing. The nozzle assembly 105 may include an emitter 110 and a loading element 112.

[0035] Emitter 110 may form a distal end of the nozzle assembly 105 , and the loading element 112 may form a proximal end of the assembly, such that emitter 110 is positioned further away from a central axis of the casing than loading element 112. Furthermore, the diameter of the distal end of the emitter 110 may be smaller than the diameter of the proximal end of the loading element 112. In embodiments, a size across different emitters 110 may be different. Emitter 110 and loading element 112 may include corresponding threads, which allow an outer diameter of emitter 110 to be threaded to an inner diameter of loading element 112.

[0036] The loading element 112 may be externally onto the casing threaded to allow the nozzle to mount on the casing or it can have other methods or grooves to allow coupling loading element 112 with the casing do so, i.e.: snap ring. Further, in other embodiments, the emitter 110 and loading element 115 may be one integrated, unitary, piece.

[0037] In specific embodiments, loading element 112 may be the casing, and emitter 110 may be a cap directly coupled with the casing. This may enable the cap to initially secure the degradable insert 120 in place, and later retain the degradable insert 120 within the casing. In further embodiments, an outer surface of the emitter 110, cap, etc. may be flush with, recessed within, or extend over an outer surface of the loading element 112, casing, etc.

[0038] Emitter 110 may include a first ledge 142 with a first diameter, a second ledge 144 with a second diameter, and a third ledge 146 with a third diameter.

[0039] The first ledge 142 may be configured to receive a distal end of the degradable insert 120 after the degradable insert 120 is activated. This may allow the degradable insert 120 to continue to form a seal across the nozzle assembly 105 after activating until the degradable insert 120 degrades within the nozzle assembly 105. Furthermore, before activating the degradable insert 120 there may be a gap, space, offset, etc. between the distal end of the degradable 120 insert and the first ledge 142, which may allow a first portion 122 of the degradable insert 120 to move within the nozzle assembly 105 relative to a second portion 124 of the degradable insert 120. In embodiments, a diameter across the first ledge 142 may be shorter than a diameter across the second ledge 144.

[0040] The second ledge 144 may be configured to receive a second portion 124 of the degradable insert 120 when positioning the degradable insert 120 within the nozzle assemble 105. The second ledge 144 may also be configured to secure and hold the second portion 124 of the degradable insert 120 in place after the degradable insert 120 is activated and the first portion 122 of the degradable insert 120 travels to the first ledge 142.

[0041] The third ledge 146 may be configured to secure the second portion 124 of the degradable insert 120 in place before after activation of the degradable insert 120. Furthermore, by securing the degradable insert 120 in place, and press fitted against the second ledge 144, a pressure applied across the degradable insert 120 may allow for activation of the degradable insert 120.

[0042] In specific embodiments, the third ledge 146 may be directly formed, milled, etc. within the casing, and the first ledge 142 and second ledge 144 may be a cap, wherein the cap is configured to sandwich, secure, etc. the degradable insert 120 in place. In other words, loading element 112 may be any barrel, tubing, casing, sleeve, etc. with a plurality of holes that are configured to receive a degradable insert 120. In embodiments, an outer circumference of the plurality of holes may be larger in size than an inner circumference of the plurality of holes. This difference in sizing of the inner and outer circumference may create a lip, ledge, etc. wherein the degradable insert 120 may be positioned on. Afterthe degradable insert 120 is positioned within the hole, the degradable insert 120 may be secured in place via the emitter 110, wherein the emitter 110 may be a cap, nozzle, retaining element, etc.

[0043] The degradable insert 120 may be a unitary plug formed of a single piece that is configured to selectively seal the nozzle assembly 105, wherein the degradable insert 120 may be pressure activated. In embodiments, degradable insert 120 may be press fit between loading element 112 and emitter 110, or be threaded to emitter 110. The degradable insert 120 may be formed of degradable material, which is configured to completely degrade after the surface or part of the surface of the degradable insert 120 is exposed to wellbore fluid. In embodiments, the degradable insert 120 may be coated with a barrier that protects and seals the outer surface of the degradable insert 120, such that the interaction of any of the surface area of the degradable insert 120 with wellbore fluids does not initiate the degradation of thedegradable insert 120. A seal 130, such as an o-ring seal, may be formed between the outer diameter of the degradable insert 120 and the inner surface of the emitter 110, wherein the seal may be retained even after activating the degradable insert 120 until the degradable insert 120 degrades within the emitter 110. The degradable insert 120 may be configured to be run in the hole within the nozzle assembly 105, and block the passageway of the nozzle assembly 105.

[0044] After sufficient pressure is applied across the degradable insert 120, the first portion 122 of the degradable insert 120 may be separated from the second portion 124 of the degradable insert 120. Further, the first portion 122 may move to be positioned adjacent to the first ledge 142. In embodiments where nozzle assembly 105 is positioned in the casing, first portion 122 may move radially away from the central axis of the casing. This relative movement between the first portion 122 and the second portion 124 may activate the degradable insert 120 by exposing an inner surface of the degradable insert along a fracture plane 126, wherein the inner surface of the degradable insert 120 is not covered by the barrier. Furthermore, after first portion 122 has moved radially to be positioned on a first ledge 142, the first portion 122 may retain the seal across the inner diameter of degradable insert 120. This may allow for the activation of degradable insert 120 without reducing the pressure within the casing, which may allow for a plurality of degradable inserts 120 to be activated at the same pressure. Over time, the degradable insert 120 may degrade and no longer block the nozzle assembly 105. In embodiments, the fracture plane 126 may be aligned with the third ledge 146, and may extend in an axis orthogonal to the central axis of the casing and in parallel with the central axis of the nozzle assembly 105.

[0045] One skilled in the art may appreciate that degradable insert 120 may be any shape, such as disc-shaped with a flat outer surface and a flat inner surface, or may be spherical. When degradable insert 120 is spherical, degradable insert 120 may be coupled to emitter 110 via shear screws, which when activated allow degradable insert 120 to be positioned adjacent to first ledge 142. Responsive to flowing fluid from the outer surface of emitter 110 towards the inner surface of emitter 110, the spherical degradable insert 120 may flow out of nozzle assembly 105.

[0046] FIGURE 2 depicts system 100 after degradable insert 120 has been activated. Elements depicted in FIGURE 2 may be described above, and for the sake of brevity, a further description of these elements may be omitted.

[0047] As depicted in FIGURE 2, after a pressure differential is applied across the degradable insert 120 in a first direction, from the inner surface of the casing to the outer surface of the casing, the first portion 122 of the degradable insert 120 may move away from the second portion 124 of the degradable insert 120. This may lead to the first inner surface 212 of the first portion 122 being exposed to wellbore fluid, and the second inner surface 214 of the second portion 124 being exposed. In other embodiments, the shape may be reversed and the pressure can be applied from outside.

[0048] This may create an on-demand degradable insert 120, wherein the degradable insert 120 remains intact within the nozzle assembly 105 until a predetermined pressure is applied across the degradable insert 120. In embodiments, different degradable inserts 120 may have different or the same predetermined pressure based on the thickness of the fracture plane 126.

[0049] In embodiments, when the first portion 122 lands on ledge 142, the entirety of the first inner surface 212 may be positioned away from an inner diameter of the nozzle assembly 105. This may expose the first inner surface 212, allowing for faster degradation of the first portion 122.

[0050] In embodiments, the inner diameter of nozzle assembly 105 may include a tapered sidewall 220. The tapered sidewall 220 may create a pocket 222, wherein the first inner surface 212 may be positioned within pocket 222 when the first portion 122 lands on ledge 142.

[0051] In further embodiments, the degradable inserts 120 may be activated by flow fluid from a reverse direction, from a distal end of the degradable insert 120 to a proximal end of the degradable insert 120 at a sufficient pressure. If degradable insert 120 is activated in this manner, the first portion 122 may enter the hollow chamber within the casing while the second portion 124 is retained to degrade within the nozzle assembly 105. Furthermore, if degradable insert 120 is activated by moving the first portion 122 inward, degradable insert 120 may instantly not hold pressure.

[0052] FIGURE 3 depicts a method 300 of utilizing an on -demand seal within a nozzle assembly, according to an embodiment. The operations of the method depicted in FIGURE 3 are intended to be illustrative. In some embodiments, the method may be accomplished with one or more additional operations not described, and / or without one or more of the operations discussed. Additionally, the order in which the operations of the method are illustrated in FIGURE 3 and described below is not intended to be limiting. Elements depicted in FIGURE 3 may be described above. For the sake of brevity, a further description of these elements is omitted.

[0053] At operation 310, the casing may be run in a hole to a desired depth. The casing may include a plurality of nozzle assemblies with degradable inserts. Each of the degradable inserts may be coated with a barrier that does not allow the degradable insert to be activated solely due to the interaction of downhole fluids.

[0054] At operation 320, fluid may flow within the casing and a pressure differential across a nozzle assembly may increase past a predetermined threshold.

[0055] At operation 330, the degradable insert may shear, break, etc. across a fracture plane across the degradable insert to activate the degradable insert due to the increase in pressure across the degradable insert.

[0056] At operation 340, after activating the degradable insert, the first portion of the degradable insert may move away from a second portion of the degradable insert and land on a first ledge within the nozzle assembly. This relative movement of the first portion and second portion may expose fresh - internal surfaces of thedegradable insert that are not covered by the barrier. In embodiments, the fresh internal surface may not have been previously exposed.

[0057] At operation 350, the first portion and the second portion of the degradable insert may begin to degrade.

[0058] At operation 360, the first portion and the second portion of the degradable insert may be removed from the nozzle assembly, allowing an unobstructed channel through the nozzle assembly. This may allow communication with the formation and the wellbore.

[0059] FIGURE 4 depicts a nozzle assembly, according to an embodiment. Elements depicted in FIGURE 4 may be similar to those described above, and for the sake of brevity, a further description of these elements may be omitted.

[0060] As depicted in FIGURE 4, system 400 may include a nozzle assembly 410 that is formed as a single piece. The nozzle assembly 410 may include a retaining ring 440 to secure a second portion 424 of degradable insert 420 in place.

[0061] As further depicted in FIGURE 4, degradable insert 420 may include a weak point 426 that forms a fracture point of degradable insert 420. The weak point 426 may have a smaller thickness than that of the first portion 422 or the second portion 424. Furthermore, weak point 426 may be a concave curve that faces away from the proximal end of degradable insert 420 and faces towards the distal end of degradable insert 420. This curvature may allow for some flexing of degradable insert 420 before activating degradable insert 420.

[0062] In embodiments, retaining ring 440 may be secured in place within nozzle assembly 410 and weld 450. Specifically, weld 450 may limit the radial movement of retaining ring 440 towards the inner diameter of the casing. This may secure the second portion 424 in place after activating degradable insert 420.

[0063] FIGURE 5 depicts a nozzle assembly, according to an embodiment. Elements depicted in FIGURE 5 may be similar to those described above, and for the sake of brevity, a further description of these elements may be omitted.

[0064] As depicted in FIGURE 5, a retaining ring 530 may be positioned between ledges 512, and 514 on a nozzle assemble 510. By creating an additional ledge within nozzle assembly 510 retaining ring 530 may be radially offset, and outside, of weak point 526 of degradable insert 520. This may allow more of a flat, proximal end 540 of degradable insert 520 to be exposed, which may assist in creating the pressure differential across weak point 526 to activate degradable insert 520.

[0065] In further embodiments, responsive to activating weak point 526 of degradable insert 520, the outer surface of degradable insert 520 may sit against an inner surface of nozzle assembly 510 to form a metal -to-metal seal.

[0066] Further embodiments may be utilized as a part of a toe sub, string, etc. wherein tools, wire lines, and equipment, may be pumped through the casing, tubing, sub, etc. Specifically, embodiments utilize degradable inserts that are activated by predetermined pressure, however, the conduits through the nozzle assemblies may not be opened until a later time. This may allow embodiments to hold pressure within the toe sub, casing, tubing, etc. This may allow for embodiments to be activated and subsequently pressure tested, without the need to drop balls or other blocking objects downhole to maintain a seal. However, after the degradable insert degrades, the sub may allow directional communication with the formation, which may allow establishing injectivity, which would allow tools, wireline, and equipment to be pumped downhole as needed

[0067] Reference throughout this specification to "one embodiment", "an embodiment", "one example" or "an example" means that a particular feature, structure, or characteristic described in connection with the embodiment or example is included in at least one embodiment of the present invention. Thus, appearances of the phrases "in one embodiment", "in an embodiment", "one example" or "an example" in various places throughout this specification are not necessarily all referring to the same embodiment or example. Furthermore, the particular features, structures, or characteristics may be combined in any suitable combinations and / or sub -combinations in one or more embodiments or examples. In addition, it is appreciated that the figures provided herewith are for explanation purposes to persons ordinarily skilled in the art and that the drawings are not necessarily drawn to scale.

[0068] Although the present technology has been described in detail for illustration based on what is currently considered to be the most practical and preferred implementations, it is to be understood that such detail is solely for that purpose and that the technology is not limited to the disclosed implementations, but, on the contrary, is intended to cover modifications and equivalent arrangements that are within the spirit and scope of the appended claims. For example, it is to be understood that the present technology contemplates that, to the extent possible, one or more features of any implementation can be combined with one or more features of any other implementation.

Claims

What is claimed is:

1. A downhole tool comprising: a housing with a conduit, the housing radially mounted within tubing; an insert configured to be activated to separate a first portion of the insert from a second portion of the insert, wherein the insert retains a seal across the housing before and after the insert is activated and the first portion of the insert moves radially outward, the seal restricting fluid flowing in a first direction through the housing, the first direction from an inner surface of the tubing to an outer surface of the tubing.

2. The downhole tool of claim 1, wherein an entirety of the outer surface of the insert is coated with a barrier, wherein surfaces of the insert along a fracture plane of the insert are exposed after separating the first portion and the second portion while the coated barrier remains intact.

3. The downhole tool of claim 2, wherein the first portion and the second portion are configured to degrade upon being exposed to wellbore fluid.

4. The downhole tool of claim 1, where the insert is equipped inside the housing.

5. The downhole tool of claim 1, wherein the insert is a unitary piece before separating the first portion and the second portion, the insert being uniformly formed of the same material.

6. The downhole tool of claim 1, wherein the housing is a nozzle assembly.

7. The downhole tool of claim 1, wherein the housing is a unitary piece.

8. The downhole tool of claim 1, wherein the housing is made of multiple pieces.

9. The downhole tool of claim 1 , wherein the insert does not degrade while the insert is intact.

10. The downhole tool of claim 1, wherein the seal across the housing is formed across a first plane associated with the first portion before activating the insert, and the seal across the housing is formed across a second plane associated with the second portion after activating the insert.

11. The downhole tool of claim 1, wherein the first portion is configured to radially move inward after activating the insert.

12. The downhole tool of claim 11, wherein the first portion is configured to not seal the conduit after the first portion moves radially inward.

13. The downhole tool of claim 1, further comprising: a plurality of housings positioned at different intervals along the tubing, wherein the housings are positioned within a circumference of the tubing; a plurality of inserts, wherein each of the plurality of housings includes a corresponding one of the inserts, each of the plurality of housings and the plurality of inserts being radially mounted on the tubing such that the plurality of housings and the plurality of inserts does not restrict fluid flowing through a central axis of the tubing.

14. The downhole tool of claim 13, wherein a pressure within the tubing does not drop whenthe plurality of inserts are simultaneously activated.

15. The downhole tool of claim 1, wherein the first portion is configured to radially move outward to be positioned on a first ledge of the housing after activating the insert.

16. The downhole tool of claim 15, wherein the second portion is configured to be positioned on a second ledge of the housing before and after activating the insert.

17. The downhole tool of claim 16, wherein the first portion forms a seal across the conduit before and after activating the insert.

18. The downhole tool of claim 1, further comprising: a retaining ring configured to secure the second portion of the insert in place before and after the second portion of the insert is separated from the first portion of the insert.

19. The downhole tool of claim 18, wherein the retaining ring is fixed to the conduit via welding.

20. The downhole tool of claim 1, further comprising: a weak point positioned within the insert.

21. The downhole tool of claim 20, where the weak point is positioned betw een the first portion and the second portion, the weak point being a recess compared to a planar proximal end of the insert.

22. The downhole tool of claim 1, wherein the first portion and the second portion are retained within the housing after the first portion and the second portion are separated from each other.

23. The downhole tool of claim 1, wherein the housing includes an angled sidewall to increase an inner diameter across the conduit.

24. The downhole tool of claim 1, wherein the tubing is a toe sub, and the nozzle assembly does not block the passageway of equipment being run through a lateral in a horizontal completion.

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