WO2024238034A1 - Liner with temporary acid-resistant nozzle plugs for a hydrocarbon well - Google Patents

Abstract

Techniques described herein relate to a well completion including a liner extending into a reservoir. The liner includes a number of nozzles arranged along the liner and configured to open at different times to optimize stimulation of a well without decreasing well productivity. Each of a subset of the number of nozzles includes a nozzle insert including an acid-resistant material that delays an opening of the subset of number of nozzles during stimulation.

Description

LINER WITH TEMPORARY ACID-RESISTANT NOZZLE PLUGS FOR A HYDROCARBON WELL CROSS-REFERENCE TO RELATED APPLICATION [0001] This application claims the benefit of U.S. Provisional Application Serial No 63/502,795, entitled “LINER WITH TEMPORARY ACID-RESISTANT NOZZLE PLUGS FOR A HYDROCARBON WELL,” filed May 17, 2023, the disclosure of which is hereby incorporated by reference in its entirety. FIELD [0002] The techniques described herein relate to the field of well completions and downhole operations. More particularly, the techniques described herein relate to a liner for a hydrocarbon well and method for enhancing acid stimulation and improving production performance within a well. The liner includes holes or nozzles of few millimeters in diameter that may be unevenly spaced. BACKGROUND [0003] This section is intended to introduce various aspects of the art, which may be associated with embodiments of the present techniques. This discussion is believed to assist in providing a framework to facilitate a better understanding of particular aspects of the present techniques. Accordingly, it should be understood that this section should be read in this light, and not necessarily as admissions of prior art. [0004] Modern society is greatly dependent on the use of hydrocarbons for fuels and chemical feedstocks. Hydrocarbons are generally found in subsurface rock formations known as “reservoirs.” Removing hydrocarbons from reservoirs depends on numerous physical properties of the rock formations, such as the permeability of the rock containing the hydrocarbons, the ability of the hydrocarbons to flow through the rock formations, and the proportion of hydrocarbons present, among others. [0005] Because many newly-discovered reservoirs are located in challenging environments, a relatively new drilling technique, referred to as extended reach drilling (ERD), is often used to drill wells with very long horizontal (or highly-deviated) sections, i.e., on the order of 3,000- 10,000 meters long. These wells are sometimes referred to as “extended-reach wells” or “ultra- extended-reach wells,” depending on the length of the horizontal sections. Extended-reach and ultra-extended-reach wells can present unique challenges associated with construction, completion, and production of the wells. Such challenges may vary based on the length of the well, variations in the subterranean formations that may be experienced along the length of the well, and variations in the reservoir fluids that may be encountered along the length of the well. Because of these and other factors, various techniques have been developed to assist with flow control issues associated with the construction, completion, and production of such wells. [0006] One technique that helps with flow control issues is known as “stimulation.” Stimulation is a process by which the flow of hydrocarbons between a formation and a wellbore is improved. This can be performed by any number of techniques, such as fracturing a rock surrounding the wellbore with a high-pressure fluid, injecting a surfactant into a reservoir, or injecting steam into the reservoir to lower the viscosity of the hydrocarbons. One technique involves injecting acid through the wellbore into the surrounding formation. This helps to remove debris from the wellbore and increases the flow from the formation, for example, by forming wormholes in the carbonate formation. Wormholes are small channels formed by acid attack on carbonate rock. [0007] A relatively new type of completion, referred to as a limited-entry liner (LEL) completion, is designed to provide enhanced acid stimulation and even production profiles along the length of the well. LEL completions are particularly useful for complex extended-reach and ultra-extended-reach wells, such as wells developed for tight, thin carbonate reservoirs. An LEL completion includes a string of blank pipes with small holes or nozzles, i.e., about 3 to 4 millimeters in diameter, placed approximately every 30 meters. The LEL nozzles serve two purposes. First, the LEL nozzles create a high-velocity jet of acid into the formation during stimulation. Second, the LEL nozzles provide a mechanical diversion to help create a relatively even distribution of inflow and outflow along the wellbore. In LEL type completions, the horizontal sections, also referred to as laterals, are compartmentalized using open hole external isolation packers and the injection and production takes place through the specified number of small, sparsely spaced nozzles. Nozzle distribution is dictated by the reservoir properties and may be designed to optimize injection and production by achieving a uniform flow profile and enabling an aggressive stimulation with minimal restriction during production. Stimulation of LEL wells is performed by bullheading acid through the liner into the formation. SUMMARY [0008] An embodiment described herein provides a well completion including a liner extending into a reservoir. The liner includes a number of nozzles arranged along the liner and configured to optimize stimulation of a well without decreasing well productivity. Each of a subset of the number of nozzles includes a nozzle insert including an acid-resistant material that delays an opening of the subset of number of nozzles during stimulation. [0009] Another embodiment described herein provides a method for enhancing acid stimulation and improving production performance within a well using a liner. The method includes plugging a first set of nozzles with a non-acid-resistant material and a second set of nozzles with an acid-resistant material. The first set of nozzles and second set of nozzles are arranged to optimize stimulation of a well. The method includes installing the liner downhole and displacing drilling mud to brine in the wellbore. The method includes initiating dissolution or degradation of the non-acid-resistant material to open the first set of nozzles and pumping acid through the first set of nozzles. The method includes initiating dissolution or degradation of the acid-resistant material to open the second set of nozzles, and pumping acid through the entire lateral. The method includes performing a well flowback. [0010] Another embodiment described herein provides a method for enhancing acid stimulation and improving production performance within a well using a liner. The method includes plugging a first set of nozzles with a non-acid-resistant material and a second set of nozzles with an acid-resistant material. The first set of nozzles are arranged to optimize stimulation of a well and the second set of nozzles arranged to optimize production. The method includes installing the liner downhole and displacing drilling mud to brine in the wellbore. The method also includes initiating dissolution or degradation of the non-acid-resistant material to open the first set of nozzles and pump acid through the first set of nozzles. The method further includes initiating dissolution or degradation of the acid-resistant material to open the second set of nozzles for production of hydrocarbon fluids. The method includes performing a well flowback. DESCRIPTION OF THE DRAWINGS [0011] The foregoing and other advantages of the present techniques may become apparent upon reviewing the following detailed description and drawings of non-limiting examples in which: [0012] FIG.1 is a cross-sectional schematic view of a well that includes a liner for enhanced acid stimulation and improved production performance; [0013] FIG.2 is a cross-sectional schematic view of a horizontal portion of the well showing the function of the liner during a first stage of an acid stimulation process, when nozzles in high permeability compartments are temporarily plugged; [0014] FIG.3 is a graph showing product of formation permeability and producing formation interval of the reservoir portions surrounding respective horizontal compartments of the horizontal portion of the well; [0015] FIG.4 is a cross-sectional schematic view of a horizontal portion of the well showing the function of the liner during a second stage of a two-stage acid stimulation process, when all the nozzles are open for acid injection; [0016] FIG.5 is a cross-sectional schematic view of a horizontal portion of the well showing the function of the liner during a single stage acid stimulation process, when selected nozzles are temporarily plugged; [0017] FIG.6 is a cross-sectional schematic view of the horizontal portion of the well showing the function of the liner when the well is put into production with all nozzles open for inflow; [0018] FIG.7 is a process flow diagram of a method for enhancing acid stimulation and improving production performance within a well in a two-stage stimulation using a liner with acid-resistant temporarily plugged nozzles; [0019] FIG.8 is a process flow diagram of a method for enhancing acid stimulation and improving production performance within a well using a liner with acid-resistant temporarily plugged nozzles; and [0020] FIG.9 is a process flow diagram of a method for enhancing acid stimulation and improving production performance within a well in an enhanced two-stage stimulation using a liner with acid-resistant temporarily plugged nozzles. [0021] It should be noted that the figures are merely examples of the present techniques, and no limitations on the scope of the present techniques are intended thereby. Further, the figures are generally not drawn to scale, but are drafted for purposes of convenience and clarity in illustrating various aspects of the techniques. DETAILED DESCRIPTION [0022] In the following detailed description section, the specific examples of the present techniques are described in connection with preferred embodiments. However, to the extent that the following description is specific to a particular embodiment or a particular use of the present techniques, this is intended to be for example purposes only and simply provides a description of the embodiments. Accordingly, the techniques are not limited to the specific embodiments described below, but rather, include all alternatives, modifications, and equivalents falling within the true spirit and scope of the appended claims. [0023] At the outset, and for ease of reference, certain terms used in this application and their meanings as used in this context are set forth. To the extent a term used herein is not defined below, it should be given the broadest definition persons in the pertinent art have given that term as reflected in at least one printed publication or issued patent. Further, the present techniques are not limited by the usage of the terms shown below, as all equivalents, synonyms, new developments, and terms or techniques that serve the same or a similar purpose are considered to be within the scope of the present claims. [0024] As used herein, the terms “a” and “an” mean one or more when applied to any embodiment described herein. The use of “a” and “an” does not limit the meaning to a single feature unless such a limit is specifically stated. [0025] The terms “about,” “approximately,” and “around” mean a relative amount of a material or characteristic that is sufficient to provide the intended effect. The exact degree of deviation allowable in some cases may depend on the specific context, e.g., ±1%, ±5%, ±10%, ±15%, etc. It should be understood by those of skill in the art that these terms are intended to allow a description of certain features described and claimed without restricting the scope of these features to the precise numerical ranges provided. Accordingly, these terms should be interpreted as indicating that insubstantial or inconsequential modifications or alterations of the subject matter described are considered to be within the scope of the disclosure. Moreover, all numerical values within the detailed description herein are modified by “about” the indicated value, and take into account experimental error and variations that would be expected by a person having ordinary skill in the art. [0026] As used herein, an “activator” or an “activation fluid” refers to the chemical that initiates and accelerates the dissolution or degradation of a material. [0027] As used herein, “bullheading” refers to pumping stimulation fluids into formation during well completion. [0028] The term “casing” refers to a protective lining for a wellbore. Any type of protective lining may be used, including those known to persons skilled in the art as liner, casing, tubing, etc. Casing may be segmented or continuous, jointed or unjointed, made of any material (such as steel, aluminum, polymers, composite materials, etc.), and may be expanded or unexpanded. [0029] As used herein, “degradable” refers to a mechanism of breaking down solid material in which the chemical structure of the material is modified. [0030] As used herein, “dissolution” and “dissolving” refers to a mechanism of breaking down solid material. During dissolution, the chemical structure of the material is preserved. [0031] As used herein, the terms “example,” exemplary,” and “embodiment,” when used with reference to one or more components, features, structures, or methods according to the present techniques, are intended to convey that the described component, feature, structure, or method is an illustrative, non-exclusive example of components, features, structures, or methods according to the present techniques. Thus, the described component, feature, structure or method is not intended to be limiting, required, or exclusive/exhaustive; and other components, features, structures, or methods, including structurally and/or functionally similar and/or equivalent components, features, structures, or methods, are also within the scope of the present techniques. [0032] As used herein, the term “fluid” refers to gases, liquids, and combinations of gases and liquids, as well as to combinations of gases and solids, and combinations of liquids and solids. [0033] “Formation” refers to a subsurface region including an aggregation of subsurface sedimentary, metamorphic and/or igneous matter, whether consolidated or unconsolidated, and other subsurface matter, whether in a solid, semi-solid, liquid and/or gaseous state, related to the geological development of the subsurface region. A formation can be a body of geologic strata of predominantly one type of rock or a combination of types of rock, or a fraction of strata having substantially common sets of characteristics. A formation can contain one or more hydrocarbon-bearing subterranean formations. Note that the terms “formation,” “reservoir,” and “interval” may be used interchangeably, but may generally be used to denote progressively smaller subsurface regions, zones, or volumes. More specifically, a “formation” may generally be the largest subsurface region, while a “reservoir” may generally be a hydrocarbon-bearing zone or interval within the geologic formation that includes a relatively high percentage of oil and gas. Moreover, an “interval” may generally be a sub-region or portion of a reservoir. In some cases, a hydrocarbon-bearing zone, or reservoir, may be separated from other hydrocarbon- bearing zones by zones of lower permeability, such as mudstones, shales, or shale-like (i.e., highly-compacted) sands. [0034] A “hydrocarbon” is an organic compound that primarily includes the elements hydrogen and carbon, although nitrogen, sulfur, oxygen, metals, or any number of other elements may be present in small amounts. As used herein, the term “hydrocarbon” generally refers to components found in oil and natural gas, such as CH4, C2H2, C2H4, C2H6, C3 isomers, C4 isomers, benzene, and the like. [0035] As used herein, a “joint” refers to a single unitary length of pipe. Tubing joints are generally around 6-12 meters long with a thread connection on each end. [0036] The term “liner” refers to a casing string that does not extend back to the wellhead or surface but is, instead, anchored or suspended from inside the bottom of the previous casing string using a liner hanger, for example. [0037] As used herein, the term “nozzle” refers to an engineered assembly with an opening of a given size that is screwed in into a liner body. [0038] As used herein, the term “packer” refers to a type of sealing mechanism used to block the flow of fluids through a well or an annulus within a well. Packers can include, for example, open-hole packers, such as swelling elastomers, mechanical packers, or external casing packers, which can provide zonal segregation and isolation. [0039] The term “substantially,” when used in reference to a quantity or amount of a material, or a specific characteristic thereof, refers to an amount that is sufficient to provide an effect that the material or characteristic was intended to provide. The exact degree of deviation allowable may depend, in some cases, on the specific context. [0040] The terms "well" and “wellbore” refer to holes drilled vertically, at least in part, and may also refer to holes drilled with deviated, highly-deviated, and/or horizontal sections. The term also includes wellhead equipment, surface casing, intermediate casing, and the like, typically associated with oil and gas wells. [0041] As used herein, a “well completion” is a group of equipment and operations that may be installed and performed to produce hydrocarbons from a subsurface reservoir. The well completion may include the casing, production liner, completion fluid, gas lift valves, and other equipment used to prepare the well to produce hydrocarbons. [0042] The term “wormhole” refers to a high permeability channel that starts from a wellbore and propagates into an interval within a formation. In addition to forming naturally in some types of formations, wormholes can be generated during well stimulation processes by any number of techniques. For example, a corrosive fluid such as an acid may be used to generate wormholes in a carbonate reservoir. The development of wormholes may substantially enhance production in intervals within a reservoir. Overview [0043] As describe above, stimulation of a well equipped with a liner, such as a limited-entry liner (LEL) wells is done by bullheading acid through a liner into a formation. However, with increasing lateral length, acid distribution along the lateral is more challenging to control. In particular, injection rate and acid volume per compartment is reduced, leading to sub-optimal stimulation results. These limitations could be overcome by stimulating the well in stages. However, the conventional method of performing multi-stage stimulation may require setting a mechanical plug to isolate the stages and may add operational complexity and cost. Moreover, during production at high flow rates, the optimal nozzle distribution designed for effective stimulation may cause high completion pressure drop, restricting total well productivity. Adding more nozzles could resolve this issue, but may decrease stimulation effectiveness. [0044] Techniques that help with flow control issues employ nozzle inserts to temporarily plug nozzles during the liner installation downhole and displacement of a drilling mud by a completion fluid. For example, polymer-based dissolvable plug nozzle inserts are sometimes used to temporarily plug nozzles during running in hole the liner to enable displacement of drilling mud with completion brine through a liner without running an inner string. These nozzle inserts dissolve in contact with brine in a controlled time and allow pressure communication and acid injection through the nozzles. Materials used to fabricate these nozzle inserts have a low resistance to acid. [0045] The present techniques improve performance of nozzle inserts by providing systems and methods for the use of acid-resistant, degradable or dissolvable materials to manufacture nozzle inserts with controlled degradation time at given downhole conditions of a well with liner completions. In particular, the present techniques relate to a liner for a hydrocarbon well. The liner includes nozzles with acid-resistant nozzle plugs. During the acid stimulation process, nozzles in the liner are configured with non-acid-resistant dissolvable plugs to enable such nozzles to allow a jet of acid to flow from the well into the surrounding formation. In some embodiments, additional nozzles are plugged with acid-resistant plugs to enable additional nozzles to open at a later stage. For example, the additional nozzles may be opened for a second stage of stimulation. The acid-resistant plugs may also be configured to enable additional nozzles to be open during production, to increase production flow. Having the flexibility to open additional nozzles during the stimulation and/or production of LEL completions enables achieving an effective stimulation without decreasing well productivity. [0046] FIG.1 is a cross-sectional schematic view of a well 100 that includes a liner 102 for enhanced acid stimulation and improved production performance. The well 100 defines a bore 104 that extends from a surface 106 into a formation 108 within the Earth’s subsurface. The formation 108 may include several subsurface intervals, such as a hydrocarbon-bearing interval that is referred to herein as a reservoir 110. In some embodiments, the reservoir 110 includes mostly carbonate rock layers. However, the reservoir 110 may also include any other types of rock layers, such as cemented sand layers. [0047] The well 100 includes a wellhead 112. The wellhead 112 includes a shut-in valve 114 that controls the flow of production fluid from the well 100. In addition, a subsurface safety valve 116, sometimes referred to as a “shut-in valve,” is provided to block the flow of production fluid from the well 100 in the event of a rupture or a catastrophic event at the surface 106 or above the subsurface safety valve 116. The wellhead 112 couples the well 100 to other equipment (not shown), such as a pump and a tank holding acid or other aggressive fluids for a stimulation process. Furthermore, artificial lift equipment, such as a pump (not shown) or a gas lift system (not shown), may optionally be included in the well 100 to aid the movement of the production fluid from the reservoir 110 to the surface 106. [0048] The well 100 is completed by setting a series of tubulars into the formation 108. These tubulars include several strings of casing, such as a surface casing string 118, an intermediate casing string 120, and a production casing string, which is referred to as the liner 102 according to embodiments described herein. In some embodiments, additional intermediate casing strings (not shown) are also included to provide support for the walls of the well 100. According to the embodiment shown in FIG.1, the surface casing string 118 and the intermediate casing string 120 are hung from the surface 106, while the liner 102 is hung from the bottom of the intermediate casing string 120 using a liner hanger 122. [0049] The surface casing string 118 and the intermediate casing string 120 are set in place using cement 124. The cement 124 isolates the intervals of the formation 108 from the well 100 and each other. Referring specifically to the liner 102, the liner 102 may also be set in place using a cement sheath. However, in the embodiment shown in FIG.1, the well 100 is set as an open-hole completion, meaning that the production casing string, i.e., the liner 102, is not set in place using cement. [0050] The exemplary well 100 shown in FIG.1 is completed horizontally. A horizontal portion is shown at 126. The horizontal portion 126 has a heel 128 and a toe 130 that extends through the reservoir 110 within the formation 108. In some embodiments, the distance between the heel 128 and the toe 130 is on the order of around 3,000 meters, in which case the well 100 may be referred to as an extended-reach well. In other embodiments, the distance between the heel 128 and the toe 130 is on the order of around 10,000 meters, in which case the well 100 may be referred to as an ultra-extended-reach well. [0051] The well 100 also includes a number of packers 132. The packers 132 are placed along the outer diameter of the liner 102. The packers 132 may be any suitable type of packer, such as, for example, a swellable packer fabricated from a swelling elastomeric material. [0052] According to some embodiments described herein, the liner 102 is a limited-entry liner (LEL). The limited-entry portion of the liner 102 begins at the heel 128 of the horizontal portion 126 and extends to the toe 130 of the horizontal portion 126. While typical LELs include small LEL holes, i.e., in a range between about 3 millimeters and 4 millimeters in diameter, drilled approximately every 40 feet to 100 feet or approximately every 12.2 meters to 30.5 meters, the liner 102 described herein instead uses a temporarily plugged nozzle generally referred to herein as nozzles 134. Each nozzle 134 may be designed such that the fluid outlet is in a range between about 3 millimeters and 4 millimeters in diameter when the nozzle 134 is open. In addition, the nozzles 134 may be spaced approximately 15 meters to 30 meters apart along the length of the liner 102. In various embodiments, the spacing between the nozzles 134 may vary considerably depending on the details of the specific implementation. [0053] The nozzles 134 may be plugged using any suitable type of plug to temporarily prevent fluid from flowing. In various embodiments, the nozzles 134 are plugged using plugs made of either non-acid-resistant or acid-resistant material. The first type of non-acid-resistant temporary plugs can be manufactured from any degradable or dissolvable material that is not resistant to acid. Dissolvable materials may include, for example, certain metals, such as iron, copper, aluminum readily dissolve in a concentrated acid. Dissolvable materials may also be made from stone, such as calcium carbonate, which also dissolves in acid. In addition, the temporary plugs may be alternatively made from a polylactic acid polymer material, which may also readily dissolve in acid. In various examples, the plugs can be inserted into each of the nozzle openings to temporarily plug the nozzles. Alternatively, in some embodiments, temporary nozzle plugs can be manufactured as an integral part of a screw-in nozzle. In these embodiments, the nozzle insert can be manufactured from a composite alloy, where the plugged portion of the insert is manufactured from a non-acid-resistant dissolvable or degradable alloy. Upon degradation or dissolution, the material does not leave an undesired residue that can cause formation damage. In various embodiments, the acid dissolvable or acid degradable material may include, but is not limited to, multilayered or monolithic composite alloys or polymers with high mechanical strength and high glass transition temperature. [0054] In various embodiments, a second set of acid-resistant temporary plugged nozzles can be manufactured from any acid-resistant degradable or dissolvable material including, but not limited to, multilayered or monolithic composite alloys or polymers with high mechanical strength and high glass transition temperature. In one embodiment, the glass transition temperature is above 250 °F or above 121 °C. In some embodiments, the nozzle plug can also be coated by polymeric or elastomeric material that delays degradation or dissolution in acid. In various embodiments, the material composition of the acid-resistant plugs can be tuned to achieve the required degradation time at given downhole conditions. Alternatively, in some embodiments, the material dissolution can be initiated by pumping a solvent or an activator. In various embodiments, the material is insoluble in brine and drilling mud both at surface and downhole conditions. Upon degradation or dissolution, the material for the second set of plugs also does not leave an undesired residue that can cause formation damage. In various embodiments, temporary nozzle plugs can be manufactured as an integral part of a screw-in nozzle. In these embodiments, the nozzle insert can be manufactured from a composite alloy, where the plugged portion of the insert is manufactured from an acid-resistant dissolvable or degradable alloy. Alternatively, in some embodiments, a plug can be inserted into a nozzle opening to temporarily plug the nozzle. The plug can be manufactured from any acid-resistant degradable or dissolvable material. In various embodiments, the nozzle plug is able to preserve its integrity and mechanical properties for the duration of the treatment and can withstand the differential pressure present during the injection of the stimulation fluids. For example, the differential pressure may be up to 5000 pound-force per square inch (psi) or 138 Bar. [0055] In one embodiment, the nozzles 134 are temporarily plugged with different types of acid-resistant and non-acid-resistant plugs in order to enable a two stage stimulation. As one example, the two stage stimulation includes a first stimulation stage across low permeability zones and a second stimulation stage across the entire lateral. In some embodiments, the nozzles 134 are temporarily plugged with different types of acid-resistant and non-acid-resistant plugs so that the nozzles are opened at different times depending on the type of fluid that is present. In various embodiments, the times at which the nozzles 134 unplug may be specifically tailored based on the details of the specific implementation, as described further herein. [0056] FIG.2 is a cross-sectional schematic view of a horizontal portion 126 of the well 100 showing the function of the limited-entry liner 102 during a first stage 200 of an acid stimulation process. The acid stimulation process may improve the flow of hydrocarbon fluids, generally referred to herein as “production fluid,” from the reservoir 110 into the limited-entry liner 102. This may be particularly beneficial for embodiments in which the well 100 is an extended-reach or ultra-extended-reach well and the reservoir 110 includes mostly carbonate rock layers. In operation, the acid stimulation process involves injecting an acid solution 204, such as a concentrated hydrochloric acid solution, for example, into the reservoir 110 via the limited-entry liner 102. This is known as “acidizing.” Acidizing helps to dissolve carbonate material, for example, within the reservoir 110, thereby opening up high-permeability channels, generally referred to as “wormholes,” through which production fluid may flow into the well 100. In addition, the acid solution 204 helps to dissolve drilling mud (and other drilling debris) that may have invaded the reservoir 110. [0057] In various embodiments, the distribution of the plugged nozzles 134 is configured to optimize stimulation of the well. In particular, compartments have been selected to be stimulated during the first 200 and second acid stages. In the example of FIG.2, nozzles 202 have been selected to be open during the first stage 200 and remaining plugged nozzles 134 are to be opened during a second stimulation stage 400, as shown in FIG.4. The nozzles 202 may be distributed to be placed across low permeability zones of a reservoir. Thus, nozzles 202 in compartments selected for the first stimulation stage may have been plugged with non-acid- resistant degradable or dissolvable material. Similarly, nozzles 134 may be distributed to be placed across high permeability zones of the reservoir and may have been plugged with an acid- resistant degradable or dissolvable material. [0058] A preliminary step of the two-stage acid stimulation process involves degradation or dissolution of non-acid-resistant plugged nozzle material to open the nozzles 202 for the first stimulation stage. In some embodiments, dissolution of the nozzle plugs in nozzles 202 starts after an exposure to the brine in the wellbore. Alternatively, in other embodiments, an activator is pumped downhole to initiate dissolution or degradation of the nozzle plugs in nozzles 202. [0059] The next step in the acid stimulation process involves pumping the acid solution 204 through the surface and intermediate casing strings 118 and 120 and into the limited-entry liner 102. The injection of the acid solution 204 into the limited-entry liner 102 causes jets of the acid solution 204 to be injected into the reservoir 110, as shown at 206. In various embodiments, this results in the formation of wormholes within the reservoir 110. The wormholes may substantially increase the amount of hydrocarbon fluids produced from the reservoir 110 by increasing the permeability of the reservoir 110 proximate to the limited-entry liner 102. [0060] In various embodiments, the formulation of the plugs used in nozzles 134 is of an acid-resistant material such that nozzles 134 remain plugged during the first stimulation stage, as shown in FIG.2. [0061] FIG.3 is a graph 300 showing product of formation permeability, k, and producing formation interval, h, in a producing well, referred to as kh, of the reservoir portions surrounding respective horizontal compartments of the horizontal portion of the well. The product kh is the primary finding of buildup and drawdown tests and is a useful factor in the flow potential of a well. As shown in FIG.3, compartments 302, 304, 306, and 308 show a pattern that corresponds to the types of plugged nozzles 134 of FIG.2. In particular, compartments 302 and 306 indicate a high kh and therefore associated with a high permeability zone. Compartments 304 and 308 similarly indicate a relatively lower kh and therefore associated with a low permeability zone. For example, a set of experimental compartments 302 and 306 were shown to have a kh of 5 mD-m (millidarcy-meters) and compartments 304 and 308 had a kh of 300 mD- m (millidarcy-meters). [0062] FIG.4 is a cross-sectional schematic view of a horizontal portion 126 of the well 100 showing the function of the limited-entry liner 102 during a second stage of a two-stage acid stimulation process. As described above, acid distribution along longer laterals may be challenging to control. Therefore, in various embodiments, at the end of the first stage acid stimulation treatment of FIG.2, a solvent or an activator may be pumped to initiate degradation or dissolution of acid-resistant plugged nozzle material to result in additional open nozzles 402 for a second injection of acid solution 404, as shown at 206 and 406. Alternatively, in some embodiments, if the degradation process is temperature-dependent, then the well is allowed to warm up to reservoir temperature to initiate degradation of the nozzle material to result in additional opened nozzles 402. [0063] FIG.5 is a cross-sectional schematic view of a horizontal portion 126 of the well 100 showing the function of the limited-entry liner during a single stage acid stimulation process 500. In various embodiments, similarly to FIG.2, the distribution of the plugged nozzles 134 is configured to optimize stimulation of the well via injected acid 504. However, rather than selecting compartments to be used in stimulating via different stages, a pair of open nozzles 506 has been initiated for each compartment in the single stimulation stage. In some wells 100, a relatively uniform permeability zone may exist across the portion of the reservoir surrounding the horizontal portion 126. Therefore, in some embodiments, the distribution of nozzles 506 may similarly be in a uniform pattern across the horizontal portion 126. In the examples of FIG. 5, a pattern of two open nozzles 506 with one plugged nozzle in between is shown with two open nozzles 506 at the end of the horizontal portion 126. In various embodiments, the open nozzles 506 may have been plugged using non-acid-resistant material. Before the acid stimulation stage, the open nozzles 506 may have been opened after exposure to the brine in the wellbore or by pumping a solvent or an activator into the liner. During the acid stimulation stage 500, the acid 504 may be pumped through the open nozzles 506 as indicated by arrow 508. [0064] FIG.6 is a cross-sectional schematic view of the horizontal portion 126 of the well 100 showing the function of the limited-entry liner when the well is put into production 600. Once the well is put into production, the pressure within the reservoir exceeds the pressure within the well. As a result, the production fluid 602 flows through the open nozzles 506 and 604 to enter the limited-entry liner. As noted above, the optimal nozzle distribution designed for effective stimulation in FIG.5 may result in high completion pressure drop. Therefore, in various embodiments, at the end of the stimulation treatment of FIG.5, a solvent or an activator may be pumped to initiate degradation or dissolution of acid-resistant plugged nozzle material to result in additional opened nozzles 604. Alternatively, in some embodiments, if the degradation process is temperature-dependent, then the well is allowed to warm up to reservoir temperature to initiate degradation of the nozzle material to result in additional opened nozzles 604. In this manner, the limited-entry liner may reduce completion pressure drop with the well during production by increasing the number of open nozzles available during production as compared to stimulation via the acid-resistant nozzle plugs 604, resulting in improved production flow 606. [0065] The cross-sectional schematic views of FIGS.1, 2, and 4-6 are not intended to indicate that the well 100 is to include all of the components shown in FIGS.1, 2, and 4-6. Moreover, the well 100 may also include any number of additional components not shown in FIGS.1, 2, and 4-6 depending on the details of the specific implementation. For example, while the well 100 is depicted as including the horizontal portion 126, it is to be understood that the well 100 may also be described as including additional horizontal portions, one or more vertical portions, and/or one or more deviated or highly-deviated portions that extend through multiple reservoirs or zones of interest. Furthermore, while the well 100 is described as an open-hole completion, in other embodiments, the well 100 may be a cased-hole completion in which the limited-entry liner 102 is set in place using a cement sheath. Moreover, in some embodiments, the limited-entry liner 102 is replaced with an engineered casing string that is hung from the surface rather than the bottom of the previous casing string. [0066] While only fifteen and eleven total nozzles 134 are shown in FIGS.1, 2, and 4-6, respectively, this is for ease of discussion only, since a typical well may likely include a much larger number of nozzles 134, 202, 402, 506, 604. In practice, the exact number of nozzles 134 may vary based on a number of factors, such as the length of the horizontal portion 126. For example, in some embodiments, the liner 102 includes around one nozzle every 40 feet to 60 feet, or about one nozzle every 12 meters to 18 meters. In other embodiments, the liner 102 may have lower hole density, such as one nozzle every 100 feet, or one nozzle every 30.5 meters. Thus, in various embodiments, depending on hole density and length of the lateral section, the total number of nozzles may be within the range between 200 nozzles and 400 nozzles. [0067] The following section includes exemplary embodiments describing possible scenarios for utilizing the engineered production liner described herein to enhance acid stimulation and improve production performance within a well. [0068] FIG.7 is a process flow diagram of a method 700 for enhancing acid stimulation and improving production performance within a well in a two-stage stimulation using a limited-entry liner with acid-resistant plugs. The method 700 is implemented by a limited-entry liner that extends along a portion, such as a horizontal or highly-deviated portion, of a well that is proximate to a reservoir. In some embodiments, the well is an extended-reach or ultra-extended- reach well. [0069] The method 700 begins at block 702, at which a nozzle distribution including a first set of nozzles and second set of nozzles is designed to optimize stimulation for a liner of a well. In some embodiments, the distribution includes compartments to be stimulated in first and second stimulation stages. [0070] At block 704, a first set of nozzles of compartments to be stimulated in the first stimulation stage are plugged with non-acid-resistant material. For example, the non-acid- resistant material may be a dissolvable or degradable material. At block 706, a second set of nozzles of compartments to be stimulated in the second stimulation stage are plugged with acid- resistant material. For example, the acid-resistant material may be a dissolvable or degradable material. [0071] At block 708, the liner is installed downhole and the well is displaced from drilling mud to brine in the wellbore. For example, a sodium chloride, sodium bromide, or other type of brine is circulated through the liner and annulus to remove drilling mud from the wellbore. [0072] At block 710, dissolution or degradation of the non-acid-resistant material is initiated to open the first set of nozzles for the first stimulation stage. For example, the non-acid-resistant material may be dissolved after exposure to brine. Alternatively, an activator is pumped to initiate dissolution or degradation of the non-acid-resistant material. In various embodiments, the activator may include but not limited to an acidic solution or a solvent that accelerate the dissolution process. The first stimulation stage is then pumped. For example, acid is pumped through the first set of nozzles. In various embodiments, pumping the first stimulation stage may include pumping any acid system including, but not limited to, hydrochloric acid, hydrofluoric acid, hydrochloric acid based alternative/retarded acid, hydrofluoric acid based retarded acids, gelled acid, emulsified acid, viscoelastic surfactant-based acid, cross-linked acid, organic acid, or any other low pH acidic fluids. [0073] At block 712, dissolution or degradation of the acid-resistant material is initiated to open the second set of nozzles for the second stimulation. In some embodiments, an activation fluid is pumped to initiate dissolution of the acid-resistant material. In some embodiments, a solvent is pumped to initiate dissolution of the acid-resistant material. Alternatively, in some embodiments, if a degradation process is temperature-dependent, adequate time is allowed for the well to warm up to reservoir temperature to initiate degradation. As one example, the acid- resistance material may be wax-based and the wax-based insert may be degraded by melting the wax with the increased temperature. The second stage stimulation is then pumped. For example, acid may be pumped through the entire lateral in the second state stimulation. In various embodiments, pumping the second stimulation stage may similarly include pumping any acid system, which may be the same as or differ from the acid system used in the first stimulation stage. [0074] At block 714, a well flowback is performed. In various examples, the well flowback may be performed in preparation for a production stage. For example, the well flowback allows fluids to flow from the well following the stimulation stages. In some examples, a cleanup may then be performed. For example, the cleanup may include a period of controlled production, during which time any treatment fluids return from the reservoir formation. A production stage may then be executed, in which hydrocarbons are produced from the well. For example, the production state may be executed using the opened first and second set of nozzles. [0075] The process flow diagram of FIG.7 is not intended to indicate that the steps of the method 700 are to be executed in any particular order, or that all of the steps of the method 700 are to be included in every case. Further, any number of additional steps not shown in FIG.7 may be included within the method 700, depending on the details of the specific implementation. For example, additional treatments or additional stages of stimulation with additional sets of nozzles may be included before, in between, or after the two stimulation stages. [0076] FIG.8 is a process flow diagram of a method 800 for enhancing acid stimulation and improving production performance within a well using a limited-entry liner with acid-resistant plugs. The method 800 is implemented by a limited-entry liner that extends along a portion, such as a horizontal or highly-deviated portion, of a well that is proximate to a reservoir. In some embodiments, the well is an extended-reach or ultra-extended-reach well. [0077] The method 800 begins at block 802, at which a nozzle distribution is designed with a first set of to optimize stimulation for a liner of a well. The nozzle distribution includes a second set of nozzles to minimize production loss for an expected well productivity index (PI). [0078] At block 804, the first set of nozzles are plugged with non-acid-resistant material. In various embodiments, the non-acid-resistant material may be dissolvable or degradable. For example, the non-acid-resistant material may be any suitable material that is dissolvable or degradable using an acid solution. [0079] At block 806, the second set of nozzles are plugged using acid-resistant material. In various embodiments, the acid-resistant material may be dissolvable or degradable and may include, but is not limited to, multilayered or monolithic composite alloys or polymers with high mechanical strength and high glass transition temperature. [0080] At block 808, a liner is installed downhole and the well is displaced from drilling mud to brine in a wellbore. In various embodiments, the liner is a limited-entry liner. [0081] At block 810, dissolution or degradation of non-acid-resistant material is initiated to open first set of nozzles. For example, the first set of nozzles may be opened for a stimulation stage in which acid is pumped through the first set of nozzles. In some embodiments, the non- acid-resistant material dissolves after exposure to brine. Alternatively, in some embodiments, an activator is pumped to initiate dissolution or degradation of the non-acid-resistant material to open nozzles for the first stimulation stage. In various embodiments, the activation fluid breaker may be an acidic solution that reduces the viscosity of a fluid by breaking long-chain molecules into shorter segments. In some embodiments, the activator may include, but is not limited to, an acidic solution or a solvent that accelerates the dissolution process. [0082] At block 812, a dissolution or degradation of the acid-resistant material in the second set of nozzles is initiated. In various embodiments, the dissolution of acid-resistant material is initiated by pumping a solvent or other activation fluid. In some embodiments, a degradation of the acid-resistant material may be initiated by allowing the well to warm up to a temperature of the reservoir. As one example, the acid-resistant material may be wax-based and the wax-based insert may be degraded by melting the wax with the increased temperature. [0083] At block 814, well flowback is performed. For example, the well flowback may be performed in preparation for a production stage. After pumping acid, the wellbore and reservoir rock may be full of water and high salinity spent acid. This mixture may be flowed back to surface in order for the well to produce at a stable rate. [0084] The process flow diagram of FIG.8 is not intended to indicate that the steps of the method 800 are to be executed in any particular order, or that all of the steps of the method 800 are to be included in every case. Further, any number of additional steps not shown in FIG.8 may be included within the method 800, depending on the details of the specific implementation. [0085] FIG.9 is a process flow diagram of a method 900 for enhancing acid stimulation and improving production performance within a well in an enhanced two-stage stimulation using a limited-entry liner with acid-resistant plugs. The method 900 is implemented by a limited-entry liner that extends along a portion, such as a horizontal or highly-deviated portion, of a well that is proximate to a reservoir. In some embodiments, the well is an extended-reach or ultra- extended-reach well. [0086] The method 900 begins at block 902, at which a nozzle distribution including a first set of nozzles, a second set of nozzles, and a third set of nozzles is designed to optimize stimulation and production for a liner of a well. In some embodiments, the distribution includes compartments including the first and second set of nozzles to be stimulated in first and second stimulation stages, and the third set of nozzles to be opened during a production stage. The distribution also includes a third set of nozzles distributed among different compartments to be opened during a production stage to enable increased production through additional open nozzles. [0087] At block 904, a first set of nozzles of compartments to be stimulated in the first stimulation stage are plugged with non-acid-resistant material. At block 906, a second set of nozzles of compartments to be stimulated in the second stimulation stage are plugged with a first acid-resistant material. For example, the first acid-resistant material may be any suitable dissolvable or degradable material as discussed herein. At block 908, a third set of nozzles of compartments to be stimulated during a production stage are plugged with a second acid- resistant material. For example, the second acid-resistant material may be a dissolvable or degradable material that is different from the first acid-resistant material. In various examples, the second acid-resistant material may have delayed degradation or dissolution compared to the first acid-resistant material. In some embodiments, the first acid-resistant material degrades or dissolves at downhole conditions earlier than the second acid-resistance material. For example, the degradation or dissolution rates are defined by material properties. In some embodiments, the degradation or dissolution of the first and second acid resistant materials is triggered by different activation fluids. In some embodiments, the first acid-resistant material starts dissolving or degrading at downhole conditions and the other acid-resistant material starts dissolving or degrading after pumping activation fluid. [0088] At block 910, the liner is installed downhole and the well is displaced from drilling mud to brine. For example, a sodium chloride, sodium bromide, or other type of brine is circulated through the liner and annulus to remove drilling mud from the wellbore. [0089] At block 912, dissolution or degradation of the non-acid-resistant material is initiated to open the first set of nozzles for the first stimulation stage. For example, the non-acid-resistant material may be dissolved after exposure to brine. Alternatively, an activator is pumped to initiate dissolution or degradation of the non-acid-resistant material. In various embodiments, the activator may include but not limited to an acidic solution or a solvent that accelerate the dissolution process. The first stimulation stage is then pumped. For example, acid is pumped through the first set of nozzles. In various embodiments, pumping the first stimulation stage may include pumping any acid system including, but not limited to, hydrochloric acid, hydrofluoric acid, hydrochloric acid based alternative/retarded acid, hydrofluoric acid based retarded acids, gelled acid, emulsified acid, viscoelastic surfactant-based acid, cross-linked acid, organic acid, or any other low pH acidic fluids. [0090] At block 914, dissolution or degradation of the first acid-resistant material is initiated to open the second set of nozzles for the second stimulation stage. In some embodiments, an activation fluid is pumped to initiate dissolution of the first acid-resistant material. In some embodiments, a solvent is pumped to initiate dissolution of the acid-resistant material. Alternatively, in some embodiments, if a degradation process is temperature-dependent, adequate time is allowed for the well to warm up to reservoir temperature to initiate degradation. As one example, the acid-resistance material may be wax-based, and the wax-based insert may be degraded by melting the wax with the increased temperature. The second stage stimulation is then pumped. For example, acid may be pumped through the entire lateral in the second state stimulation. In various embodiments, pumping the second stimulation stage may similarly include pumping any acid system, which may be the same as or differ from the acid system used in the first stimulation stage. [0091] At block 916, dissolution or degradation of the second acid-resistant material is initiated to open the third set of nozzles for the production stage. The dissolution or degradation of the acid-resistant material of block 916 is similar to the operation described above herein at block 812. In some embodiments, one difference from block 812 is that the operation at block 916 is that the second acid-resistant material has delayed dissolution or degradation compared to the first acid-resistant material. For example, the second acid-resistant material can sustain integrity for a longer time when exposed to acid. [0092] At block 918, a well flowback is performed. For example, the well flowback may be performed in preparation for a production stage. After pumping acid, the wellbore and reservoir rock may be full of water and high salinity spent acid. This mixture may be flowed back to surface in order for the well to produce at a stable rate. [0093] The process flow diagram of FIG.9 is not intended to indicate that the steps of the method 900 are to be executed in any particular order, or that all of the steps of the method 900 are to be included in every case. Further, any number of additional steps not shown in FIG.9 may be included within the method 900, depending on the details of the specific implementation. Exemplary Embodiment 1 [0094] In this exemplary embodiment, each of a number of nozzles in a liner are plugged with either an acid-resistant nozzle material or a non-acid-resistant nozzle material. A distribution of the nozzles is designed to optimize stimulation of a well without negatively affecting well productivity. Each of a subset of the number of nozzles includes a nozzle insert including an acid-resistant material that delays an opening of the subset of a number of nozzles during stimulation. When the well is stimulated, a subset of the nozzles are plugged with the acid-resistant nozzle material. Specifically, nozzles corresponding to particular portions of the reservoir are dissolved or degraded, so that stimulation is directed at these portions of the reservoir. The temporarily plugged nozzles may thus improve injection conformance. Once the first set of nozzles have been used for stimulation, the second set of nozzles are opened for additional activity by initiating a degradation or dissolving of the acid-resistant plugs. Exemplary Embodiment 2 [0095] This exemplary embodiment is the same as Exemplary Embodiment 1, except that the liner further includes a second subset of nozzles that include the nozzle inserts made of a non- acid-resistant material. The non-acid-resistant material is dissolvable or degradable using a breaker fluid to enable stimulation or production via the second subset of nozzles. Exemplary Embodiment 3 [0096] This exemplary embodiment is the same as Exemplary Embodiment 1 and 2, except that the second subset of the number of nozzles including the non-acid-resistant material are configured in compartments to be stimulated during the first stage of a two-stage well stimulation when the liner is placed into the well. Exemplary Embodiment 4 [0097] This exemplary embodiment is the same as Exemplary Embodiments 1 and 2, except that the subset of the number of nozzles including the non-acid-resistant material are configured to minimize pressure drop during production in a single stage well stimulation. Exemplary Embodiment 5 [0098] This exemplary embodiment is the same as Exemplary Embodiments 1-3, except that the subset of the number of nozzles including the acid-resistant material are configured in compartments to be stimulated during the second stage of a two-stage well stimulation when the liner is placed into the well. Exemplary Embodiment 6 [0099] This exemplary embodiment is the same as Exemplary Embodiments 1-3, except that the subset of the number of nozzles including the acid-resistant material are configured to achieve an effective stimulation after a single stage well stimulation. Exemplary Embodiment 7 [00100] This exemplary embodiment is the same as Exemplary Embodiments 1-3, except that the nozzles include screw-in nozzles, and the nozzles inserts are molded as part of the nozzle assembly using an alloy of a different composition than that of the screw-in nozzles. Exemplary Embodiment 8 [0101] This exemplary embodiment is the same as Exemplary Embodiments 1-3, except that the nozzles inserts include a non-metallic material that is inserted into the nozzles. Exemplary Embodiment 9 [0102] This exemplary embodiment is the same as Exemplary Embodiments 1-3, except that the acid-resistant material is degradable or dissolvable under ambient reservoir temperature. Exemplary Embodiment 10 [0103] This exemplary embodiment is the same as Exemplary Embodiments 1-3, except that the acid-resistant material is degradable or dissolvable using an activation fluid. Exemplary embodiment 11 [0104] In this exemplary embodiment, a method for enhancing acid stimulation within a well using a liner includes plugging a first set of nozzles with a non-acid-resistant material and a second set of nozzles with an acid-resistant material. The first set of nozzles and second set of nozzles are arranged to optimize stimulation of a well. The method includes installing the liner downhole and displacing drilling mud to brine in the wellbore. The method includes initiating dissolution or degradation of the non-acid-resistant material to open the first set of nozzles and pumping acid through the first set of nozzles. The method includes initiating dissolution or degradation of the acid-resistant material to open the second set of nozzles and pumping acid through the entire lateral. The method includes performing a well flowback. Exemplary Embodiment 12 [0105] This exemplary embodiment is the same as Exemplary Embodiment 11, but further includes plugging a third set of nozzles with a second acid-resistant material, and initiating dissolution or degradation of the acid-resistant material to open the third set of nozzles for production of hydrocarbon fluids. The second acid-resistant material of the third set of nozzles is different from the acid-resistant material of the second set of nozzles. Exemplary Embodiment 13 [0106] This exemplary embodiment is the same as Exemplary Embodiment 12, except that initiating dissolution of the non-acid-resistant material to open the first set of nozzles includes exposing the liner to brine for a certain period of time. Exemplary Embodiment 14 [0107] This exemplary embodiment is the same as Exemplary Embodiments 12-13, except that initiating dissolution of the non-acid-resistant material to open the first set of nozzles includes pumping an activation fluid. Exemplary Embodiment 15 [0108] This exemplary embodiment is the same as Exemplary Embodiments 12-14, except that initiating dissolution of the acid-resistant material to open the second set of nozzles includes pumping an activation fluid. Exemplary Embodiment 16 [0109] This exemplary embodiment is the same as Exemplary Embodiments 12-15, except that initiating dissolution of the acid-resistant material to open the second set of nozzles includes pumping a solvent. Exemplary Embodiment 17 [0110] This exemplary embodiment is the same as Exemplary Embodiments 12-16, except that initiating dissolution of the acid-resistant material to open the second set of nozzles includes allowing the well to warm up to a reservoir temperature to initiate degradation of the acid- resistant material. Exemplary Embodiment 18 [0111] This exemplary embodiment is the same as Exemplary Embodiments 12-17, except that the method further includes pumping a first stage stimulation through the first set of nozzles and a second stage stimulation through the second set of nozzles. Exemplary Embodiment 19 [0112] This exemplary embodiment is the same as Exemplary Embodiments 12-18, except that the method further includes conducting a step rate test to estimate a number of nozzles contributing to flow. Exemplary embodiment 20 [0113] In this exemplary embodiment, a method for enhancing acid stimulation and improving production performance within a well using a liner includes plugging a first set of nozzles with a non-acid-resistant material and a second set of nozzles with an acid-resistant material. The first set of nozzles are arranged to optimize stimulation of a well and the second set of nozzles arranged to optimize production. The method includes installing the liner downhole and displacing drilling mud to brine in the wellbore. The method includes initiating dissolution or degradation of the non-acid-resistant material to open the first set of nozzles and pumping acid through the first set of nozzles. The method includes initiating dissolution or degradation of the acid-resistant material to open the second set of nozzles for production of hydrocarbon fluids. The method includes performing a well flowback. Exemplary Embodiment 21 [0114] This exemplary embodiment is the same as Exemplary Embodiments 20, except that the method includes pumping a single stage stimulation through the first set of nozzles and receiving fluids in a production stage through the first set of nozzles and the second set of nozzles. Exemplary Embodiment 22 [0115] This exemplary embodiment is the same as Exemplary Embodiments 20, except that the method includes plugging a third set of nozzles with a second acid-resistant material, and initiating dissolution or degradation of the second acid-resistant material to open the third set of nozzles for a second stimulation stage before initiating dissolution or degradation of the acid- resistant material to open the second set of nozzles for production of hydrocarbon fluids. The second acid-resistant material of the third set of nozzles is different from the acid-resistant material of the second set of nozzles. [0116] In one or more embodiments, the present techniques may be susceptible to various modifications and alternative forms, such as the following embodiments as noted in paragraphs 1 to 22: 1. A well completion, comprising a liner extending into a reservoir, the liner comprising: a plurality of nozzles arranged along the liner and configured to optimize stimulation of a well without decreasing well productivity, wherein each of a subset of the plurality of nozzles comprises a nozzle insert comprising an acid-resistant material that delays an opening of the subset of plurality of nozzles during stimulation. 2. The well completion of paragraph 1, wherein the liner further comprises a second subset of the plurality of nozzles that comprise nozzle insert comprising a non-acid-resistant material. 3. The well completion of paragraph 2, wherein the second subset of the plurality of nozzles comprising the non-acid-resistant material are configured in compartments to be stimulated during a first stage of a two-stage well stimulation when the liner is placed into the well. 4. The well completion of paragraphs 2 or 3, wherein the subset of the plurality of nozzles comprising the non-acid-resistant material are configured to achieve an effective stimulation in a single stage well stimulation. 5. The well completion of any of paragraphs 1 to 4, wherein the subset of the plurality of nozzles comprising the acid-resistant material are configured in compartments to be stimulated during a second stage of a two-stage well stimulation when the liner is placed into the well. 6. The well completion of any of paragraphs 1 to 5, wherein the subset of the plurality of nozzles comprising the acid-resistant material are configured to minimize pressure drop during production after a single stage well stimulation. 7. The well completion of any of paragraphs 1 to 6, wherein the nozzles comprise screw-in nozzles, and nozzles inserts are molded as part of a nozzle assembly using an alloy of a different composition than that of the screw-in nozzles. 8. The well completion of any of paragraphs 1 to 7, wherein the nozzles inserts comprise a non- metallic material that is inserted into the nozzles. 9. The well completion of any of paragraphs 1 to 8, wherein the acid-resistant material is degradable or dissolvable under ambient reservoir temperature. 10. The well completion of any of paragraphs 1 to 9, wherein the acid-resistant material is degradable or dissolvable using an activation fluid. 11. A method for enhancing acid stimulation within a well using a liner, comprising: plugging a first set of nozzles with a non-acid-resistant material and a second set of nozzles with an acid- resistant material, wherein the first set of nozzles and second set of nozzles are arranged to optimize stimulation of a well; installing the liner downhole and displacing drilling mud to brine in a wellbore; initiating dissolution or degradation of the non-acid-resistant material to open the first set of nozzles and pumping acid through the first set of nozzles; initiating dissolution or degradation of the acid-resistant material to open the second set of nozzles, and pumping acid through an entire lateral; and performing a well flowback. 12. The method of paragraph 11, comprising plugging a third set of nozzles with a second acid- resistant material, and initiating dissolution or degradation of the acid-resistant material to open the third set of nozzles for production of hydrocarbon fluids, wherein the second acid-resistant material of the third set of nozzles is different from the acid-resistant material of the second set of nozzles. 13. The method of paragraphs 11 or 12, wherein initiating dissolution of the non-acid-resistant material to open the first set of nozzles comprises exposing the liner to brine for a certain period of time. 14. The method of any of paragraphs 11 to 13, wherein initiating dissolution of the non-acid- resistant material to open the first set of nozzles comprises pumping an activation fluid. 15. The method of any of paragraphs 11 to 14, wherein initiating dissolution or degradation of the acid-resistant material to open the second set of nozzles comprises pumping an activation fluid. 16. The method of any of paragraphs 11 to 15, wherein initiating dissolution of the acid-resistant material to open the second set of nozzles comprises pumping a solvent. 17. The method of any of paragraphs 11 to 16, wherein initiating dissolution or degradation of the acid-resistant material to open the second set of nozzles comprises allowing the well to warm up to a reservoir temperature to initiate dissolution or degradation of the acid-resistant material. 18. The method of any of paragraphs 11 to 17, comprising pumping a first stage stimulation through the first set of nozzles and a second stage stimulation through the second set of nozzles. 19. The method of any of paragraphs 11 to 18, comprising conducting a step rate test to estimate a number of nozzles contributing to flow. 20. A method for enhancing acid stimulation and improving production performance within a well using a liner, comprising: plugging a first set of nozzles with a non-acid-resistant material and a second set of nozzles with an acid-resistant material, wherein the first set of nozzles are arranged to optimize stimulation of a well and the second set of nozzles arranged to optimize production; installing the liner downhole and displacing drilling mud to brine in a wellbore; initiating dissolution or degradation of the non-acid-resistant material to open the first set of nozzles and pump acid through the first set of nozzles; initiating dissolution or degradation of the acid-resistant material to open the second set of nozzles for production of hydrocarbon fluids; and performing a well flowback. 21. The method of paragraph 20, comprising pumping a single stage stimulation through the first set of nozzles and receiving fluids in a production stage through the first set of nozzles and the second set of nozzles. 22. The method of paragraphs 20 or 21, comprising plugging a third set of nozzles with a second acid-resistant material, and initiating dissolution or degradation of the second acid-resistant material to open the third set of nozzles for a second stimulation stage before initiating dissolution or degradation of the acid-resistant material to open the second set of nozzles for production of hydrocarbon fluids, wherein the second acid-resistant material of the third set of nozzles is different from the acid-resistant material of the second set of nozzles. [0117] While the embodiments described herein are well-calculated to achieve the advantages set forth, it will be appreciated that the embodiments described herein are susceptible to modification, variation, and change without departing from the spirit thereof. Indeed, the present techniques include all alternatives, modifications, and equivalents falling within the true spirit and scope of the appended claims.

Claims

CLAIMS What is claimed is: 1. A well completion, comprising a liner extending into a reservoir, the liner comprising: a plurality of nozzles arranged along the liner and configured to optimize stimulation of a well without decreasing well productivity, wherein each of a subset of the plurality of nozzles comprises a nozzle insert comprising an acid-resistant material that delays an opening of the subset of plurality of nozzles during stimulation.

2. The well completion of claim 1, wherein the liner further comprises a second subset of the plurality of nozzles that comprise nozzle insert comprising a non-acid-resistant material.

3. The well completion of claim 2, wherein the second subset of the plurality of nozzles comprising the non-acid-resistant material are configured in compartments to be stimulated during a first stage of a two-stage well stimulation when the liner is placed into the well.

4. The well completion of claim 2, wherein the subset of the plurality of nozzles comprising the non-acid-resistant material are configured to achieve an effective stimulation in a single stage well stimulation.

5. The well completion of claim 1, wherein the subset of the plurality of nozzles comprising the acid-resistant material are configured in compartments to be stimulated during a second stage of a two-stage well stimulation when the liner is placed into the well.

6. The well completion of claim 1, wherein the subset of the plurality of nozzles comprising the acid-resistant material are configured to minimize pressure drop during production after a single stage well stimulation.

7. The well completion of claim 1, wherein the nozzles comprise screw-in nozzles, and nozzles inserts are molded as part of a nozzle assembly using an alloy of a different composition than that of the screw-in nozzles.

8. The well completion of claim 1, wherein the nozzles inserts comprise a non- metallic material that is inserted into the nozzles.

9. The well completion of claim 1, wherein the acid-resistant material is degradable or dissolvable under ambient reservoir temperature.

10. The well completion of claim 1, wherein the acid-resistant material is degradable or dissolvable using an activation fluid.

11. A method for enhancing acid stimulation within a well using a liner, comprising: plugging a first set of nozzles with a non-acid-resistant material and a second set of nozzles with an acid-resistant material, wherein the first set of nozzles and second set of nozzles are arranged to optimize stimulation of a well; installing the liner downhole and displacing drilling mud to brine in a wellbore; initiating dissolution or degradation of the non-acid-resistant material to open the first set of nozzles and pumping acid through the first set of nozzles; initiating dissolution or degradation of the acid-resistant material to open the second set of nozzles, and pumping acid through an entire lateral; and performing a well flowback.

12. The method of claim 11, comprising plugging a third set of nozzles with a second acid-resistant material, and initiating dissolution or degradation of the acid-resistant material to open the third set of nozzles for production of hydrocarbon fluids, wherein the second acid- resistant material of the third set of nozzles is different from the acid-resistant material of the second set of nozzles.

13. The method of claim 11, wherein initiating dissolution of the non-acid-resistant material to open the first set of nozzles comprises exposing the liner to brine for a certain period of time.

14. The method of claim 11, wherein initiating dissolution of the non-acid-resistant material to open the first set of nozzles comprises pumping an activation fluid.

15. The method of claim 11, wherein initiating dissolution or degradation of the acid- resistant material to open the second set of nozzles comprises pumping an activation fluid.

16. The method of claim 11, wherein initiating dissolution of the acid-resistant material to open the second set of nozzles comprises pumping a solvent.

17. The method of claim 11, wherein initiating dissolution or degradation of the acid- resistant material to open the second set of nozzles comprises allowing the well to warm up to a reservoir temperature to initiate dissolution or degradation of the acid-resistant material.

18. The method of claim 11, comprising pumping a first stage stimulation through the first set of nozzles and a second stage stimulation through the second set of nozzles.

19. The method of claim 11, comprising conducting a step rate test to estimate a number of nozzles contributing to flow.

20. A method for enhancing acid stimulation and improving production performance within a well using a liner, comprising: plugging a first set of nozzles with a non-acid-resistant material and a second set of nozzles with an acid-resistant material, wherein the first set of nozzles are arranged to optimize stimulation of a well and the second set of nozzles arranged to optimize production; installing the liner downhole and displacing drilling mud to brine in a wellbore; initiating dissolution or degradation of the non-acid-resistant material to open the first set of nozzles and pump acid through the first set of nozzles; initiating dissolution or degradation of the acid-resistant material to open the second set of nozzles for production of hydrocarbon fluids; and performing a well flowback.

21. The method of claim 20, comprising pumping a single stage stimulation through the first set of nozzles and receiving fluids in a production stage through the first set of nozzles and the second set of nozzles.

22. The method of claim 20, comprising plugging a third set of nozzles with a second acid-resistant material, and initiating dissolution or degradation of the second acid-resistant material to open the third set of nozzles for a second stimulation stage before initiating dissolution or degradation of the acid-resistant material to open the second set of nozzles for production of hydrocarbon fluids, wherein the second acid-resistant material of the third set of nozzles is different from the acid-resistant material of the second set of nozzles.