Patent Publication Number: US-2023135692-A1

Title: Assessing and reducing deposition of scales and other solids

Description:
CROSS-REFERENCE TO RELATED APPLICATIONS 
     This application claims priority to U.S. Provisional Patent Application Ser. No. 63/273,774 titled “Assessing and Reducing Deposition of Scales and Other Solids” and filed on Oct. 29, 2021, the entire contents of which are hereby incorporated herein by reference. 
    
    
     TECHNICAL FIELD 
     The present application is related to subterranean field operations and, more particularly, to assessing and reducing deposition of scales and/or other solids. 
     BACKGROUND 
     Some subterranean formations, such as shale, may produce subterranean resources through techniques such as horizontal drilling and fracturing. Over time, the fractures may become restricted or blocked. Preventing or reducing the development and growth of these restrictions or blockages may lead to enhanced extraction of the subterranean resources for an extended period of time. 
     SUMMARY 
     In general, in one aspect, the disclosure relates to a method for evaluating a fluid to reduce a deposition of a solid within a fractured subterranean formation. The method may include obtaining information about a plurality of materials inside of a testing vessel, where the plurality of materials is designed to be representative of the fractured subterranean formation. The method may also include providing a fluid that flows through the plurality of materials inside the testing vessel for a period of time, where the testing vessel is subjected to conditions designed to be representative of downhole conditions of the fractured subterranean formation. The method may further include evaluating the plurality of materials to characterize the deposition of the solid on at least some of the plurality of materials after the period of time. 
     In another aspect, the disclosure relates to a system for evaluating a fluid to reduce a deposition of a solid within a fractured subterranean formation. The system may include a testing module that includes a testing vessel, where the testing vessel is configured to receive a plurality of materials, where the plurality of materials is designed to be representative of the fractured subterranean formation, where the testing module is configured to be representative of downhole conditions at the fractured subterranean formation on the testing vessel, and where the testing module is further configured to provide the fluid that flows through the plurality of materials in the testing vessel for a period of time. 
     These and other aspects, objects, features, and embodiments will be apparent from the following description and the appended claims. 
    
    
     
       BRIEF DESCRIPTION OF THE DRAWINGS 
       The drawings illustrate only example embodiments and are therefore not to be considered limiting in scope, as the example embodiments may admit to other equally effective embodiments. The elements and features shown in the drawings are not necessarily to scale, emphasis instead being placed upon clearly illustrating the principles of the example embodiments. Additionally, certain dimensions or positions may be exaggerated to help visually convey such principles. In the drawings, reference numerals designate like or corresponding, but not necessarily identical, elements. 
         FIGS.  1 A through  1 C  show a field system, and details thereof, with which example embodiments may be used. 
         FIG.  2    shows the detail of  FIG.  1 C  at a subsequent point in time according to certain example embodiments. 
         FIG.  3    shows the detail of  FIG.  2    at a subsequent point in time according to certain example embodiments. 
         FIG.  4    shows a diagram of a testing system for assessing and reducing subsurface deposition of scales and/or other solids according to certain example embodiments. 
         FIG.  5    shows a system diagram of a controller according to certain example embodiments. 
         FIG.  6    shows a computing device in accordance with certain example embodiments. 
         FIG.  7    shows a flowchart of a method for evaluating a fluid for reducing scale deposition within fractures according to certain example embodiments. 
         FIGS.  8 A and  8 B  shows proppant with scale deposition according to certain example embodiments. 
         FIG.  9    shows a graph of differential pressure with respect to a testing vessel using a fluid over time according to certain example embodiments. 
         FIG.  10    shows a graph of differential pressure with respect to a testing vessel using another fluid over time according to certain example embodiments. 
         FIG.  11    shows a graph of permeability with respect to material in a testing vessel using the fluid of  FIG.  9    over time according to certain example embodiments. 
         FIG.  12    shows a graph of calcite weight in proppant within a testing vessel after testing using the fluid of  FIGS.  9  and  11    according to certain example embodiments. 
         FIG.  13    shows a graph of elemental mapping by Energy Dispersive X-Ray Analysis (EDX) of proppant tested with the fluid of  FIGS.  9 ,  11 , and  12    that includes the cation brine. 
         FIG.  14    shows a graph of elemental mapping by EDX of proppant tested with the fluid of  FIGS.  9 ,  11 , and  12    that includes the 10 ppm of scale inhibitor. 
         FIG.  15    shows a graph of permeability with respect to material in a testing vessel using the fluid of  FIG.  10    over time according to certain example embodiments. 
         FIG.  16    shows a graph of calcite weight in proppant within a testing vessel after testing using the fluid of  FIGS.  10  and  15    according to certain example embodiments. 
         FIG.  17    shows a graph of elemental mapping by EDX of proppant tested with the fluid of  FIGS.  10 ,  15 , and  16    that includes the cation brine and 0 ppm of scale inhibitor. 
         FIG.  18    shows a graph of elemental mapping by EDX of proppant tested with the fluid of  FIGS.  10 ,  15 , and  16    that includes the cation brine and 80 ppm of scale inhibitor. 
         FIG.  19    shows another diagram of part of a testing system for assessing and reducing subsurface deposition of scales and/or other solids according to certain example embodiments. 
         FIGS.  20 A through  20 C  show an image of a testing system that is modeled after the testing system of  FIG.  19    according to certain example embodiments. 
     
    
    
     DETAILED DESCRIPTION 
     The example embodiments discussed herein are directed to systems, apparatus, methods, and devices for assessing and reducing deposition of scales and/or solids (e.g., asphaltenes, sludge, fines). As defined herein, reducing deposition of scales and/or other solids may involve any of a number of different actions. For example, reducing deposition of scales and/or other solids may include minimizing the accumulation or deposition of scales and/or other solids without completely eliminating the scales and/or other solids. As another example, reducing deposition of scales and/or other solids as defined herein may additionally or alternatively mean preventing the development of scales and/or other solids. As yet another example, reducing deposition of scales and/or other solids as defined herein may additionally or alternatively mean completely eliminating scales and/or other solids that have previously developed. 
     The use of the terms “about”, “approximately”, and similar terms applies to all numeric values, whether or not explicitly indicated. These terms generally refer to a range of numbers that one of ordinary skill in the art would consider as a reasonable amount of deviation to the recited numeric values (i.e., having the equivalent function or result). For example, this term may be construed as including a deviation of ±10 percent of the given numeric value provided such a deviation does not alter the end function or result of the value. Therefore, a value of about 1% may be construed to be a range from 0.9% to 1.1%. Furthermore, a range may be construed to include the start and the end of the range. For example, a range of 10% to 20% (i.e., range of 10%-20%) includes 10% and also includes 20%, and includes percentages in between 10% and 20%, unless explicitly stated otherwise herein. Similarly, a range of between 10% and 20% (i.e., range between 10%-20%) includes 10% and also includes 20%, and includes percentages in between 10% and 20%, unless explicitly stated otherwise herein. 
     A “subterranean formation” refers to practically any volume under a surface. For example, it may be practically any volume under a terrestrial surface (e.g., a land surface), practically any volume under a seafloor, etc. Each subsurface volume of interest may have a variety of characteristics, such as petrophysical rock properties, reservoir fluid properties, reservoir conditions, hydrocarbon properties, or any combination thereof. For example, each subsurface volume of interest may be associated with one or more of: temperature, porosity, salinity, permeability, water composition, mineralogy, hydrocarbon type, hydrocarbon quantity, reservoir location, pressure, etc. Those of ordinary skill in the art will appreciate that the characteristics are many, including, but not limited to: shale gas, shale oil, tight gas, tight oil, tight carbonate, carbonate, vuggy carbonate, unconventional (e.g., a permeability of less than 25 millidarcy (mD) such as a permeability of from 0.000001 mD to 25 mD)), diatomite, geothermal, mineral, etc. The terms “formation”, “subsurface formation”, “hydrocarbon-bearing formation”, “reservoir”, “subsurface reservoir”, “subsurface area of interest”, “subsurface region of interest”, “subsurface volume of interest”, and the like may be used synonymously. The term “subterranean formation” is not limited to any description or configuration described herein. 
     A “well” or a “wellbore” refers to a single hole, usually cylindrical, that is drilled into a subsurface volume of interest. A well or a wellbore may be drilled in one or more directions. For example, a well or a wellbore may include a vertical well, a horizontal well, a deviated well, and/or other type of well. A well or a wellbore may be drilled in the subterranean formation for exploration and/or recovery of resources. A plurality of wells (e.g., tens to hundreds of wells) or a plurality of wellbores are often used in a field depending on the desired outcome. 
     A well or a wellbore may be drilled into a subsurface volume of interest using practically any drilling technique and equipment known in the art, such as geosteering, directional drilling, etc. Drilling the well may include using a tool, such as a drilling tool that includes a drill bit and a drill string. Drilling fluid, such as drilling mud, may be used while drilling in order to cool the drill tool and remove cuttings. Other tools may also be used while drilling or after drilling, such as measurement-while-drilling (MWD) tools, seismic-while-drilling (SWD) tools, wireline tools, logging-while-drilling (LWD) tools, or other downhole tools. After drilling to a predetermined depth, the drill string and the drill bit may be removed, and then the casing, the tubing, and/or other equipment may be installed according to the design of the well. The equipment to be used in drilling the well may be dependent on the design of the well, the subterranean formation, the hydrocarbons, and/or other factors. 
     A well may include a plurality of components, such as, but not limited to, a casing, a liner, a tubing string, a sensor, a packer, a screen, a gravel pack, artificial lift equipment (e.g., an electric submersible pump (ESP)), and/or other components. If a well is drilled offshore, the well may include one or more of the previous components plus other offshore components, such as a riser. A well may also include equipment to control fluid flow into the well, control fluid flow out of the well, or any combination thereof. For example, a well may include a wellhead, a choke, a valve, and/or other control devices. These control devices may be located on the surface, in the subsurface (e.g., downhole in the well), or any combination thereof. In some embodiments, the same control devices may be used to control fluid flow into and out of the well. In some embodiments, different control devices may be used to control fluid flow into and out of a well. In some embodiments, the rate of flow of fluids through the well may depend on the fluid handling capacities of the surface facility that is in fluidic communication with the well. The equipment to be used in controlling fluid flow into and out of a well may be dependent on the well, the subsurface region, the surface facility, and/or other factors. Moreover, sand control equipment and/or sand monitoring equipment may also be installed (e.g., downhole and/or on the surface). A well may also include any completion hardware that is not discussed separately. The term “well” may be used synonymously with the terms “borehole,” “wellbore,” or “well bore.” The term “well” is not limited to any description or configuration described herein. 
     Example embodiments of assessing and reducing deposition of scales and/or other solids may be at a subsurface (e.g., propped fractures, frac face, in or near perforations, within and adjacent to a wellbore in a subterranean formation). Example embodiments of assessing and reducing deposition of scales and/or other solids may additionally or alternatively be used in any of a number of other applications. For instance, example embodiments may be used to reduce deposition of scales and/or other solids in production facilities. Such production facilities may include, but are not limited to, production tubing, heat exchangers, and conduit or other pipes (e.g., a pipeline) used to transport fluid (e.g., produced fluids from oil and gas wells). 
     It is understood that when combinations, subsets, groups, etc. of elements are disclosed (e.g., combinations of components in a composition, or combinations of steps in a method), that while specific reference of each of the various individual and collective combinations and permutations of these elements may not be explicitly disclosed, each is specifically contemplated and described herein. By way of example, if an item is described herein as including a component of type A, a component of type B, a component of type C, or any combination thereof, it is understood that this phrase describes all of the various individual and collective combinations and permutations of these components. For example, in some embodiments, the item described by this phrase could include only a component of type A. In some embodiments, the item described by this phrase could include only a component of type B. In some embodiments, the item described by this phrase could include only a component of type C. In some embodiments, the item described by this phrase could include a component of type A and a component of type B. In some embodiments, the item described by this phrase could include a component of type A and a component of type C. In some embodiments, the item described by this phrase could include a component of type B and a component of type C. In some embodiments, the item described by this phrase could include a component of type A, a component of type B, and a component of type C. In some embodiments, the item described by this phrase could include two or more components of type A (e.g., A1 and A2). In some embodiments, the item described by this phrase could include two or more components of type B (e.g., B1 and B2). In some embodiments, the item described by this phrase could include two or more components of type C (e.g., C1 and C2). In some embodiments, the item described by this phrase could include two or more of a first component (e.g., two or more components of type A (A1 and A2)), optionally one or more of a second component (e.g., optionally one or more components of type B), and optionally one or more of a third component (e.g., optionally one or more components of type C). In some embodiments, the item described by this phrase could include two or more of a first component (e.g., two or more components of type B (B1 and B2)), optionally one or more of a second component (e.g., optionally one or more components of type A), and optionally one or more of a third component (e.g., optionally one or more components of type C). In some embodiments, the item described by this phrase could include two or more of a first component (e.g., two or more components of type C (C1 and C2)), optionally one or more of a second component (e.g., optionally one or more components of type A), and optionally one or more of a third component (e.g., optionally one or more components of type B). 
     If a component of a figure is described but not expressly shown or labeled in that figure, the label used for a corresponding component in another figure may be inferred to that component. Conversely, if a component in a figure is labeled but not described, the description for such component may be substantially the same as the description for the corresponding component in another figure. The numbering scheme for the various components in the figures herein is such that each component is a three-digit number or a four-digit number, and corresponding components in other figures have the identical last two digits. For any figure shown and described herein, one or more of the components may be omitted, added, repeated, and/or substituted. Accordingly, embodiments shown in a particular figure should not be considered limited to the specific arrangements of components shown in such figure. 
     Further, a statement that a particular embodiment (e.g., as shown in a figure herein) does not have a particular feature or component does not mean, unless expressly stated, that such embodiment is not capable of having such feature or component. For example, for purposes of present or future claims herein, a feature or component that is described as not being included in an example embodiment shown in one or more particular drawings is capable of being included in one or more claims that correspond to such one or more particular drawings herein. 
     Example embodiments of assessing and reducing deposition of scales and/or other solids will be described more fully hereinafter with reference to the accompanying drawings, in which example embodiments of assessing and reducing deposition of scales and/or other solids are shown. Assessing and reducing deposition of scales and/or other solids may, however, be embodied in many different forms and should not be construed as limited to the example embodiments set forth herein. Rather, these example embodiments are provided so that this disclosure will be thorough and complete, and will fully convey the scope of assessing and reducing deposition of scales and/or other solids to those of ordinary skill in the art. Like, but not necessarily the same, elements (also sometimes called components) in the various figures are denoted by like reference numerals for consistency. 
     Terms such as “first”, “second”, “outer”, “inner”, “top”, “bottom”, “above”, “below”, “distal”, “proximal”, “front,”, “rear,” “left,” “right,” “on”, and “within”, when present, are used merely to distinguish one component (or part of a component or state of a component) from another. This list of terms is not exclusive. Such terms are not meant to denote a preference or a particular orientation, and they are not meant to limit embodiments of assessing and reducing deposition of scales and/or other solids. In the following detailed description of the example embodiments, numerous specific details are set forth in order to provide a more thorough understanding of the invention. However, it will be apparent to one of ordinary skill in the art that the invention may be practiced without these specific details. In other instances, well-known features have not been described in detail to avoid unnecessarily complicating the description. 
       FIGS.  1 A through  1 C  show a field system  199 , including details thereof, with which example embodiments may be used. Specifically,  FIG.  1 A  shows a schematic diagram of a land-based field system  199  in which a wellbore  120  has been drilled in a subterranean formation  110 .  FIG.  1 B  shows a detail of a substantially horizontal section  103  of the wellbore  120  of  FIG.  1 A .  FIG.  1 C  shows a detail of an induced fracture  101  of  FIG.  1 B . The field system  199  in this example includes a wellbore  120  disposed in a subterranean formation  110  using field equipment  109  (e.g., a derrick, a tool pusher, a clamp, a tong, drill pipe, casing pipe, a drill bit, a wireline tool, a fluid pumping system) located above a surface  108  and within the wellbore  120 . Once the wellbore  120  is drilled, a casing string  125  is inserted into the wellbore  120  to stabilize the wellbore  120  and allow for the extraction of subterranean resources (e.g., natural gas, oil) from the subterranean formation  110 . 
     The surface  108  may be ground level for an onshore application and the sea floor/lakebed for an offshore application. For offshore applications, at least some of the field equipment may be located on a platform that sits above the water level. The point where the wellbore  120  begins at the surface  108  may be called the wellhead. While not shown in  FIGS.  1 A  and  1 B, there may be multiple wellbores  120 , each with its own wellhead but that is located close to the other wellheads, drilled into the subterranean formation  110  and having substantially horizontal sections  103  that are close to each other. In such a case, the multiple wellbores  120  may be drilled at the same pad or at different pads. When the drilling process is complete, other operations, such as fracturing operations, may be performed. The fractures  101  are shown to be located in the horizontal section  103  of the wellbore  120  in  FIG.  1 B . The fractures  101 , whether induced and/or naturally occurring, may additionally or alternatively be located in other sections (e.g., a substantially vertical section, a transition area between a vertical section and a horizontal section) of the wellbore  120 . Example embodiments may be used along any portion of the wellbore  120  where fractures  101  are located. 
     The subterranean formation  110  may include one or more of a number of formation types, including but not limited to shale, limestone, sandstone, clay, sand, and salt. In certain embodiments, a subterranean formation  110  may include one or more reservoirs in which one or more resources (e.g., oil, natural gas, water, steam) may be located. One or more of a number of field operations (e.g., fracturing, coring, tripping, drilling, setting casing, extracting downhole resources) may be performed to reach an objective of a user with respect to the subterranean formation  110 . 
     The wellbore  120  may have one or more of a number of segments or hole sections, where each segment or hole section may have one or more of a number of dimensions. Examples of such dimensions may include, but are not limited to, a size (e.g., diameter) of the wellbore  120 , a curvature of the wellbore  120 , a total vertical depth of the wellbore  120 , a measured depth of the wellbore  120 , and a horizontal displacement of the wellbore  120 . There may be multiple overlapping casing strings of various sizes (e.g., length, outer diameter) contained within and between these segments or hole sections to ensure the integrity of the wellbore construction. In this case, one or more of the segments of the subterranean wellbore  120  is the substantially horizontal section  103 . As stated above, in additional or alternative cases, one or more of the segments of the subterranean wellbore  120  is a substantially vertical section. 
     As discussed above, inserted into and disposed within the wellbore  120  of  FIGS.  1 A and  1 B  are a number of casing pipes that are coupled to each other end-to-end to form the casing string  125 . In this case, each end of a casing pipe has mating threads (a type of coupling feature) disposed thereon, allowing a casing pipe to be directly or indirectly mechanically coupled to another casing pipe in an end-to-end configuration. The casing pipes of the casing string  125  may be indirectly mechanically coupled to each other using a coupling device, such as a coupling sleeve. 
     Each casing pipe of the casing string  125  may have a length and a width (e.g., outer diameter). The length of a casing pipe may vary. For example, a common length of a casing pipe is approximately 40 feet. The length of a casing pipe may be longer (e.g., 60 feet) or shorter (e.g., 10 feet) than 40 feet. The width of a casing pipe may also vary and may depend on the cross-sectional shape of the casing pipe. For example, when the shape of the casing pipe is cylindrical, the width may refer to an outer diameter, an inner diameter, or some other form of measurement of the casing pipe. Examples of a width in terms of an outer diameter may include, but are not limited to, 4½ inches, 7 inches, 7⅝ inches, 8⅝ inches, 10¾ inches, 13⅜ inches, and 14 inches. 
     The size (e.g., width, length) of the casing string  125  may be based on the information (e.g., diameter of the borehole drilled) gathered using field equipment with respect to the subterranean wellbore  120 . The walls of the casing string  125  have an inner surface that forms a cavity that traverses the length of the casing string  125 . Each casing pipe may be made of one or more of a number of suitable materials, including but not limited to steel. Cement  109  is poured into the wellbore  120  through the cavity and then forced upward between the outer surface of the casing string  125  and the wall of the subterranean wellbore  120 . In some cases, a liner may additionally be used with, or alternatively be used in place of, some or all of the casing pipes. 
     Once the cement dries to form concrete, a number of fractures  101  are induced in the subterranean formation  110 . The fractures  101  may be induced in any of a number of ways known in the industry, including but not limited to hydraulic fracturing, fracturing using electrodes, and/or other methods of inducing fractures. The hydraulic fracturing process involves the injection of large quantities of fluids (outside of the fluids discussed below with respect to  FIG.  4   ) containing water, chemical additives, and proppants  112  into the subterranean formation  110  from the wellbore  120  to create fracture networks. An example of fracturing using electrodes may be found in U.S. Pat. No. 9,840,898 issued on Dec. 12, 2017, to Kasevich et al., the entirety of which is herein incorporated by reference. A subterranean formation  110  naturally has fractures  101 , but these naturally occurring fractures  101  have inconsistent characteristics (e.g., length, spacing) and so in some cases maynot be relied upon for extracting subterranean resources without having additional fractures  101 , such as what is shown in  FIG.  1 B , induced in the subterranean formation  110 . 
     Operations that induce fractures  101  in the subterranean formation  110  use any of a number of fluids (outside of the fluids discussed below with respect to  FIG.  4   ) that include proppant  112  (e.g., sand, ceramic pellets). When proppant  112  is used, some of the fractures  101  (also sometimes called principal or primary fractures) receive proppant  112 , while a remainder of the fractures  101  (also sometimes called secondary fractures) do not have any proppant  112  in them. 
     As shown in  FIG.  1 C , the proppant  112  is designed to become lodged inside at least some of the induced fractures  101  to keep those fractures  101  open after the fracturing operation is complete. The size of the proppant  112  is an important design consideration. Sizes (e.g., 40/70 mesh, 50/140 mesh) of the proppant  112  may vary. While the shape of the proppant  112  is shown as being uniformly spherical, and the size is substantially identical among the proppant  112 , the actual sizes and shapes of the proppant  112  may vary, as shown in  FIG.  8    below. If the proppant  112  is too small, the proppant  112  will not be effective at keeping the fractures  101  open enough to effectively allow subterranean resources  111  to flow through the fractures  101  from the rock matrices  162  in the subterranean formation  110  to the wellbore  120 . If the proppant  112  is too large, the proppant  112  may plug up the fractures  101 , blocking the flow of the subterranean resources  111  through the fractures  101 . 
     The use of proppant  112  in certain types of subterranean formation  110 , such as shale, is important. Shale formations typically have permeabilities on the order of microdarcys (μD) to nanodarcys (nD). When fractures  101  are induced in such formations with low permeabilities, it is important to sustain the fractures  101  and their conductivity for an extended period of time in order to extract more of the subterranean resource  111 . 
     The various induced fractures  101  that originate at the wellbore  120  and extend outward into the rock matrices  162  in the subterranean formation  110  in this case have consistent penetration lengths perpendicular to the wellbore  120  and have consistent coverage along at least a portion of the lateral length (substantially horizontal section) of the wellbore  120 . For example, induced fractures  101  may be 50 meters high and 200 meters long. Further, the induced fractures  101  may be spaced a distance  192  apart from each other. The distance  192  (e.g., 25 meters, 5 meters, 12 meters) may be optimized based on the permeability and the porosity of the rock matrix  162  of the subterranean formation  110 . 
     The induced fractures  101  create a volume  190  within the subterranean formation  110  where the rock matrix  162  of the subterranean formation  110  is connected to the high conductivity fractures  101  located a short distance away. In addition to different configurations of the fractures  101 , other factors that may contribute to the viability of the subterranean formation  110  may include, but are not limited to, permeability of the rock matrix  162 , capillary pressure, and the temperature and pressure of the subterranean formation  110 . Each fracture  101 , whether induced or naturally occurring, is defined by a wall  102 , also called a frac face  102  herein. The frac face  102  provides a transition between the paths formed by the rock matrices  162  in the subterranean formation  110  and the fracture  101 . The subterranean resources  101  flow through the paths formed by the rock matrices  162  in the subterranean formation  110  into the fracture  101 . 
       FIG.  2    shows the detail of  FIG.  1 C  at a subsequent point in time according to certain example embodiments.  FIG.  3    shows the detail of  FIG.  2    at a subsequent point in time according to certain example embodiments. For example,  FIG.  2    may show the detail of  FIG.  1 C  six months later than the time captured in  FIG.  1 C  after flowing a scale enhancer (a type of fluid) therethrough, and  FIG.  3    may show the detail of  FIG.  2    four year later than the time captured in  FIG.  2    after continuing to flow the scale enhancer therethrough. Referring to  FIGS.  1 A through  3   , the detail in  FIG.  2    shows, in addition to the proppant  112  within the fracture  101 , a subterranean resource  111  (e.g., natural gas, oil) is shown flowing within the fracture  101  from the rock matrix  162 , around the proppant  112  in the fracture  101 , and on to the wellbore  120 . 
     As the subterranean resource  111  flows within the paths formed by the rock matrices  162  and around or on the proppant  112  in the fracture  101 , scale deposition  213  may occur (e.g., scale particles formed during the shut-in stage before the well is put on production) on the pore throat within the rock matrices  162 , on the proppant  112 , and/or on the frac face  102 . (It should be noted that while  FIGS.  2  and  3    refer to scale deposition  213 , element  213  described herein may more generally refer to any type of solid, which may also include, but is not limited to, asphaltenes, sludge, and fines.) Over time, the scale depositions  213  may begin to accumulate on the rock matrices  162 , on the proppant  112 , and/or on the frac face  102 . In some cases, at least some of the scale depositions  213  may be an inorganic deposit from ionic materials in water that attaches to solid surfaces. Hydrocarbons may be adsorbed on scale depositions  213 . Under field conditions, scale depositions  213  may be a mixture of inorganic and organic components. 
     Scale depositions  213  may be initiated during a prior phase (e.g., completion) of a field operation, where fluids (outside of the fluids discussed below with respect to  FIG.  4   ) and chemicals used downhole may interact with formation rock (e.g., the frac face  102 , the rock matrices  162 ), resulting in the mobilization and release of elements from the rock matrices  162  adjacent to the fractures  101 , and comingle with formation water in and/or near perforations and along fractures  101 . Later, in a subsequent phase (e.g., shutting in) of the field operation, the rock-fluid interaction and the commingling of different fluids may lead to the formation (crystallization) and growth of scale depositions  213  in or near the perforations, the rock matrices  162 , and the fractures  101 . In yet another subsequent phase (e.g., production) of the field operation, the degradation in the conductivity and production flow path integrity over time in the rock matrices  162  and the fractures  101 , caused by agglomerate build up of scale depositions  213 , may lead to plugging in or near the perforations, rock matrices  162 , fractures  101 , and completion tools. 
     The scale depositions  213  that accumulate within the rock matrices  162  and the fractures  101  may be composed of one or more of any of a number of compounds, including but not limited to calcium carbonate, barium sulfate, calcium sulfate, strontium sulfate, iron carbonate, iron oxide, iron sulfide, other oxides, other sulfides, other carbonates, other sulfates, halides, and hydroxides. While the scale depositions  213  may additionally or alternatively be composed of other compounds (e.g., gas hydrates, organic deposits (e.g., asphaltenes, waxes, acid induced sludges), and naphthenates), example embodiments may, in some cases, focus on the reduction of scale depositions  213  caused by inorganic deposits. The scale depositions  213  may be caused by one or more of any of a number of factors, including but not limited to supersaturation, mixing incompatible ions, changes in temperature, changes in pressure, carbon dioxide interaction, and a change in the pH of water in the fluid. 
     Scale depositions  213  may form during the shut-in stage prior to the well being put into production, as shown in  FIG.  2   . In such a case, the scale depositions  213  deposited on the rock matrices  162 , on the proppant  112 , and on the frac face  102  may be small and spotty. As a result, the scale depositions  213  do not contribute much to inhibiting the flow of the subterranean resource  111  through the paths within the rock matrices  162  and around the proppant  112  within the fracture  101  formed by the frac face  102 . In the portion of the fracture  101  shown at the time captured in  FIG.  2   , there are 2 separate scale depositions  213  within the rock matrices  162 ,  8  scale depositions  213  on the proppant  112 , and  4  scale depositions  213  on the frac face  102 . The number, size, and location of the scale depositions  213  within the rock matrices  162  and the fracture  101  may vary. 
     When the well is put on production, some scale depositions  213  may stay at their original position, while some scale particles may move/migrate together with the produced water and deposit at another location along the production pathway. As more water is produced, if no mitigation efforts are made, the existing scale depositions  213  may increase in size and new scale depositions  213  may develop over time. An example of this is captured in  FIG.  3   , which shows that the scale depositions  213  become larger and less spotty. As a result, the scale depositions  213  in  FIG.  3    begin to contribute to inhibiting the flow of the subterranean resource  111  (e.g., a hydrocarbon) along the paths formed by the rock matrices  162 , through the frac face  102  (impacting migration of the subterranean resource  111  from the rock matrix  162 ), and around the proppant  112  (combined with the scale depositions  213  on the proppant  112  and on the frac face  102 ) within the fracture  101 . 
     In the portion of the fracture  101  shown at the time captured in  FIG.  3   , there are 25 separate scale depositions  213  within the rock matrices  162 , at the frac face  102 , and on the proppant  112 , many of which are significantly larger than the size of the scale depositions  213  shown in  FIG.  2   . Also, some of the scale depositions  213  in  FIG.  3    have migrated to a new location relative to their location in  FIG.  2   . Again, the number, size, and location of the scale depositions  213  within the fracture  101  may vary. Example embodiments may be designed in some cases to analyze the type of inorganic material in the scale depositions  213  in a particular experiment or field condition of a field operation. Example embodiments are also designed to determine the optimal way to reduce (e.g., remediate (e.g., removal of scale depositions  213  with a chemical treatment in the form of a fluid (e.g., an acid, a chelant)), mitigate) the development and accumulation of the scale depositions  213  in that particular field operation. 
       FIG.  4    shows a diagram of a system  400  for assessing and reducing deposition of scales and/or other solids according to certain example embodiments. The system  400  of  FIG.  4    includes one or more fluid component sources  428 , one or more injection systems  438 , a testing module  470 , a post-testing fluid collection system  450 , one or more optional mixing modules  465 , one or more controllers  404 , one or more sensor devices  460 , one or more users  451  (including one or more optional user systems  455 ), a network manager  480 , piping  488 , and one or more valves  485 . The testing module  470  includes one or more testing vessels  472 . 
     The components shown in  FIG.  4    are not exhaustive, and in some embodiments, one or more of the components shown in  FIG.  4    may not be included in the example testing system  400 . Any component of the testing system  400  may be discrete or combined with one or more other components of the testing system  400 . Also, one or more components of the testing system  400  may have different configurations. For example, one or more sensor devices  460  may be disposed within or disposed on other components (e.g., the piping  488 , a valve  485 , the testing module  470 , the post-testing fluid collection system  450 ). As another example, a controller  404 , rather than being a stand-alone device, may be part of one or more other components (e.g., testing module  470 , the post-testing fluid collection system  450 , an injection system  438 ) of the testing system  400 . 
     Referring to  FIGS.  1 A through  4   , a fluid  437  is pushed through one or more testing vessels  472  of the testing module  470 . As defined herein, a fluid  437  is a liquid in aqueous phase. Examples of a fluid  437  may be or include, but are not limited to, produced water (with or without chemical additives), injection water, produced fluids (e.g., oil, water), aqueous fluids prepared in a lab or received from an oilfield/well, synthesized brine, and chemical products (e.g., diluted liquid chemical products, non-diluted liquid chemical products). A fluid  437  is made up of multiple fluid components  427  (e.g., water, a dissolved salt, a chelant, a cation, an anion, a scale inhibitor additive, a brine) that are mixed together before reaching the testing module  470 . Two or more fluid components  427  may be mixed together in the piping  488  at a header  489  as those fluid components  427  interact with each other to form a fluid  437  and flow toward the testing module  470 . Alternatively, the testing system  400  may include one or more of the optional mixing modules  465  that mix two or more fluid components  427  together before the fluid components  427  reach the testing module  470  as a fluid  437 . A mixing module  465  may include one or more of a number of features used to mix two or more fluid components  427  together. Such features may include, but are not limited to, a vessel, a sensor device  460 , a controller  404 , an agitator, a paddle, a circulating system, an aerator, a vibrating mechanism, and a centrifuge. A mixing module  465  and the header  489  may each be referred to as a common vessel herein. 
     There may be one or more fluid component sources  428 . In certain example embodiments, there are at least two fluid component sources  428 . As shown in  FIG.  4   , the system  400  includes fluid component source  428 - 1  (which holds fluid component  427 - 1 ) through fluid component source  428 -N (which holds fluid component  427 -N). Each fluid component  427  (e.g., an additive) may be or include a fluid. A single fluid component  427  or a mixture of multiple fluid components  427  (but not the fluid  437 ) may be disposed in a fluid component source  428 . In certain example embodiments, when a fluid  437  is or includes an anionic brine, two fluid component sources  428  may be or include NaCl and NaHCO 3 , each of which may be dissolved in de-ionized (DI) water. When the scale depositions  213  include calcite, the anion HCO 3   − , which originates from the NaHCO 3  salt, is included in the brine to provide formation of the calcite scale depositions  213 . Even though this fluid  437  includes both cations and anions, it is called an anionic brine because of the HCO 3   − . 
     In addition, or in the alternative, the fluid may be or include a cationic brine (Ca 2+ ). In such a case, two fluid component sources  428  may be or include NaCl and CaCl 2 ), each of which may be dissolved in DI water. When the scale depositions  213  includes calcite, the cation Ca 2+ , which originates from the CaCl 2 ) salt, is included in the brine to provide formation of the calcite scale depositions  213 . Even though this fluid  437  includes both cations and anions, it is called a cationic brine because of the Ca 2+ . 
     To control the composition of the fluid  437  at a given point in time, the amount of the individual fluid components  427  that are released or withdrawn from a fluid component source  428  may be regulated in real time. This regulation may be performed automatically by a controller  404  or manually by a user  451  (including an associated user system  455 ). This regulation may be performed using equipment such as the injection systems  438 , valves  485 , regulators, sensor devices  460 , and meters. Examples of a fluid component source  428  may include, but are not limited to, a natural vessel (e.g., land that forms a natural body of water) and a man-made storage tank or other vessel. A fluid component  427  of a fluid component source  428  may have any of a number of different compositions that are naturally occurring or man-made. In some cases, a fluid component  427  of the fluid  437  includes water. 
     Each injection system  438  is configured to extract a fluid component  427  from a fluid component source  428  and push the fluid component  427  toward the testing module  470 . The number of injection systems  438  in the testing system  400  may vary. In this case, there are N injection systems  438  (injection  438 - 1  through  438 -N). In some embodiments, there may be one injection system  438  for each fluid component source  428 . In alternative embodiments, there may be one injection system  438  for multiple fluid component sources  428 . Each injection system  438  may include one or more of a number of pieces of equipment to perform its function. Examples of such equipment may include, but are not limited to, a compressor, a motor, a pump, piping (e.g., piping  488 ), a valve (e.g., valve  485 ), a controller (e.g., controller  404 ), and a sensor device (e.g., sensor device  460 ). 
     The piping  488  (including the header  489 ) may include multiple pipes, ducts, elbows, joints, sleeves, collars, and similar components that are coupled to each other (e.g., using coupling features such as mating threads) to establish a network for transporting the fluid components  427  from the fluid component sources  428 , through the injection systems  438 , to the header  489  (where the fluid components  427  mix together to form a fluid  437 ), to the testing module  470 , and finally from the testing module  470  to the post-testing fluid collection system  450 . Each component of the piping  488  may have an appropriate size (e.g., inner diameter, outer diameter) and be made of an appropriate material (e.g., steel, PVC) to safely and efficiently handle the pressure, temperature, flow rate, and other characteristics of the fluid components  427  or each fluid  437 , as applicable. 
     There may be a number of valves  485  placed in-line with the piping  488  at various locations (including at the header  489 ) in the testing system  400  to control the flow of fluid components  427  and/or each fluid  437  therethrough. A valve  485  may have one or more of any of a number of configurations, including but not limited to a guillotine valve, a ball valve, a gate valve, a butterfly valve, a pinch valve, a needle valve, a plug valve, a diaphragm valve, and a globe valve. One valve  485  may be configured the same as or differently compared to another valve  485  in the testing system  400 . Also, one valve  485  may be controlled (e.g., manually, automatically by the controller  404 ) the same as or differently compared to another valve  485  in the testing system  400 . 
     The testing module  470  is configured to house one or more testing vessels  472 . The testing module  470  receives a fluid  437  from the header  489 , allows the fluid  437  to run through one or more testing vessels  472 , and sends the post-testing fluid  457  to the post-testing fluid collection system  450 . When multiple testing vessels  472  are involved in a particular test with a fluid  437 , one testing vessel  472  may be configured in series and/or in parallel with respect to one or more of the other testing vessels  472 . 
     In certain example embodiments, the testing vessels  472  are passive objects that have a fluid  437  pass through them without the testing vessels  472  being modified or taking action during this process. In such a case, the testing module  470  may control various aspects (e.g., temperature, pressure, flow rate) of the fluid  437  and/or the testing vessel  472 . In certain example embodiments, the testing module  470  is designed to subject the materials  475  in the testing vessel  472  to conditions (e.g., pressure, temperature, flow rate) that are representative of the corresponding conditions of the fractures  101  and rock matrices  162  in the subterranean formation  110  adjacent to the wellbore  120 . The testing module  470  may include one or more of a number of pieces of equipment to perform these functions. Examples of such equipment may include, but are not limited to, a motor, a pump, a compressor, piping (e.g., piping  488 ), a valve (e.g., valve  485 ), a controller (e.g., controller  404 ), and a sensor device (e.g., sensor device  460 ). 
     A testing vessel  472  is a vessel (e.g., a column) inside of which various materials  475  (e.g., rock, proppant  112 , scale depositions  213 , solid scale inhibitors) are disposed. The materials  475  in a testing vessel  472  may be designed to be representative of induced fractures  101  in a subterranean formation  110  adjacent to a wellbore  120 . In some cases, the materials  475  placed in a testing vessel  472  are taken from the subterranean formation  110 . For example, cuttings or other loose rock that circulate to the surface  108  during a field operation (e.g., drilling, completion) may be removed from the mud circulating system (part of the field equipment  109 ) and placed in a testing vessel  472 . 
     As another example, a core sample may be taken of the subterranean formation  110  by a tool (e.g., a wireline tool) placed in the wellbore  120  adjacent to the induced fractures  101 . In such a case, the core sample may be retrieved from the tool when the tool is brought to the surface  108  and subsequently placed, either intact or crushed (cutting size), in a testing vessel  472 . As still another example, proppant  112  used to prop open the induced fractures  101  adjacent to the wellbore  120  may be used as some of the materials  475  in the testing vessel  472 . Factors that may be controlled with respect to the materials  475  in a testing vessel  472  may include, but are not limited to, the number of materials  475 , the content (e.g., rock (e.g., cuttings, core samples), materials (e.g., metal) of field equipment, proppant, scale inhibitor, oil-phase solids, oil-phase sludges, water-phase solids, water-phase sludges) of the materials  475 , the size of the materials  475 , and the shape of the materials  475 . 
     The main purpose of the testing module  470  is to be representative of downhole conditions by continually providing a fluid  437  that flows through the material  475  in the testing vessel  472 . In order to accomplish this, the testing vessel  472  may be made of any of a number of appropriate materials (e.g., glass, polytetrafluoroethylene-lined stainless steel) that may withstand the conditions (e.g., pressure, temperature, salinity, flow rate) experienced by the testing module  470 , which are designed to be representative of downhole conditions. After a period of time, the testing process may be paused or stopped so that the materials  475  in the testing vessel  472  may be evaluated. In some example embodiments, the fluid  437  may be designed to reduce (e.g., eliminate, lower) scaling that may appear and grow on some of the materials  475  (e.g., the proppant  112 , rock, materials (e.g., metals) representative of downhole equipment (e.g., casing pipe) and/or other (e.g., surface) equipment (e.g., wellhead, pumping equipment) used in a field operation) in the testing vessel  472 . Evaluation of the materials  475  in the testing vessel  472  may include characterizing (e.g., determining the amount of) scale depositions  213  disposed on the proppant  112 , rock, and/or other materials  475  in a testing vessel  472  over time. This characterization and evaluation may then be correlated to how effective a fluid  437  that includes a scale inhibitor or other fluids/chemicals used during that phase of testing may be at reducing (e.g., eliminating, lowering) scale depositions  213  in the induced fractures  101  adjacent to the wellbore  120 . 
     As another example, if a desired goal is to use the testing module  470  to determine the impact of freshly formed scale depositions  213  on fracture conductivity, the testing module  470  may be used to gauge the optimal fluid  437  (e.g., the concentration of a particular brine) so that the formation of scale depositions  213  occurs on some or all of the materials  475  in the testing vessel  472 . For instance, an initial test may be performed to determine the amount of time (sometimes called induction time) it takes for calcite (a form of scale deposition  213 ) to start to form. By mixing a fluid of cationic (Ca 2+ ) and anionic (HCO 3   2− ) brines (individually, these brines are considered fluid components  427  of the fluid  437 ), it may be found that scale depositions  213  develop after 40 seconds in a test tube or bottle (a form of testing vessel  472 ). As yet another example, if a desired goal is to use the testing module  470  to determine if a non-scaling fluid  437  (e.g., a type of brine) may pass through the materials  475  in the testing vessel  472  without disturbing the proppant  112 , the testing module  470  may be used to demonstrate blockage within the materials  475  in the testing vessel  472  using a fluid  437  that promotes scaling. 
     As still another example, if a desired goal is to use the testing module  470  to demonstrate that a particular fluid  437  (also sometimes called a chemical treatment herein) may decrease formation of scale depositions  213  and other blockage in the materials  475  (or components thereof, such as proppant  112  and rock) within the testing vessel  472 , the testing module  470  may be used to analyze the effectiveness of various fluids  437  as scale inhibitors. In some cases, the testing module  470  may include one or more features (e.g., a spectrograph, a gas chromatograph, a camera with a high zoom lens, a controller  404 , one or more sensor devices  460 ) that perform some or all of the evaluation of materials  475  within a testing vessel  472  that have been tested. The testing vessel  472  may be removable (e.g., by a user  451 ) from and insertable into the testing module  470 . The testing module  470  may include one or more features (e.g., a clamp, a latched lid) that ensure that a testing vessel  472  is secure within the testing module  470 . 
     Objectives that may be achieved by having a fluid  437  flow through materials  475  in a testing vessel  472  of the testing module  470  may include, but are not limited to, determining whether scale depositions  213  may deposit at subsurface fractures, determining how scale deposition  213  on the materials  475  impacts permeability and fluid flow, determining how scale deposition  213  on the materials  475  impacts the frac face  102  and surface of proppant  112 , determining how much scale deposition  213  may cause significant change in permeability, determining how adding scale inhibitor in a fluid  437  (e.g., a scaling brine) may mitigate scale depositions  213  on the materials  475 , determining the impact of crushing/embedding/clustering of proppant  112  on solid depositions (e.g., scale depositions  213 ) and flow assurance risks (e.g., plugging, fluid flow restriction), determining the effectiveness and impact of chemical additives (e.g., chelants, acids) as fluid components  427  of a fluid  437  on the removal of scale depositions  213  at fractures  101  (e.g., in rock matrices  162 , on proppant  112 , on a frac face  102 ), determining the effectiveness of pre-packed solid scale inhibitors as fluid components  427  of a fluid  437  in mitigating scale deposition  213  from produced water, studying adsorption and desorption of scale depositions  213  from a frac face  102  in fractures  101 , optimizing squeeze treatment design to control scale depositions  213 , and determining the impact of water cut (representative of field condition produced fluid contains both oil and water) on scale depositions  213  on a frac face  102 , rock matrices  162 , and proppants  112 . 
     One or more sensor devices  460  may be integrated with the testing module  470 . For example, two sensor devices  460  in the form of or including pressure sensors may be positioned before the testing vessel  472  and after the testing vessel  472  to provide a differential pressure value across the testing vessel  472 . The differential pressure value may provide information as to, for example, a change in permeability, an accumulation of scale depositions  213 , and/or other plugging in the material  475 . In addition, or in the alternative, one or more sensor devices  460  (e.g., a permeability meter) may be integrated with the testing vessel  472  to measure the permeability of the materials  475 . In some cases, in order to ensure that the post-testing fluid collection system  450  receives the post-testing fluid  457  from the testing module  470  at an appropriate pressure, a pressure regulator (or other similar equipment) may be installed between the testing vessel  472  and the post-testing fluid collection system  450 . 
     The post-testing fluid collection system  450  is configured to receive the post-testing fluid  457 , which is the byproduct of the fluid  437  that has flowed through the materials  475  in one or more testing vessels  472  of the testing module  470 . The post-testing fluid collection system  450  may include a vessel to contain some or all of the post-testing fluid  457 . In some cases, the post-testing fluid collection system  450  may also be configured to perform one or more tests on the post-testing fluid  457 . In such cases, the post-testing fluid collection system  450  may include one or more of a number of features (e.g., a motor, a pump, a compressor, piping (e.g., piping  488 ), a valve (e.g., valve  485 ), a spectrograph, a gas chromatograph, a camera with a high zoom lens, a controller  404 , one or more sensor devices  460 ) to conduct such testing. 
     The testing system  400  may include one or more controllers  404 . A controller  404  of the testing system  400  communicates with and in some cases controls one or more of the other components (e.g., a sensor device  460 , an injection system  438 , the testing module  470 , the post-testing fluid collection system  450 ) of the testing system  400 . A controller  404  performs a number of functions that include obtaining and sending data, evaluating data, following protocols, running algorithms, and sending commands. A controller  404  may include one or more of a number of components. As discussed below with respect to  FIG.  5   , such components of a controller  404  may include, but are not limited to, a control engine, a communication module, a timer, a counter, a power module, a storage repository, a hardware processor, memory, a transceiver, an application interface, and a security module. When there are multiple controllers  404  (e.g., one controller  404  for one or more injection systems  438 , another controller  404  for the testing module  470 , yet another controller  404  for the post-testing fluid collection system  450 ), each controller  404  may operate independently of each other. Alternatively, one or more of the controllers  404  may work cooperatively with each other. As yet another alternative, one of the controllers  404  may control some or all of one or more other controllers  404  in the testing system  400 . Each controller  404  may be considered a type of computer device, as discussed below with respect to  FIG.  6   . 
     Each sensor device  460  includes one or more sensors that measure one or more parameters (e.g., pressure, flow rate, temperature, humidity, fluid content, voltage, current, permeability, porosity, rock characteristics). Examples of a sensor of a sensor device  460  may include, but are not limited to, a temperature sensor, a flow sensor, a pressure sensor, a gas spectrometer, a voltmeter, an ammeter, a permeability meter, a porosimeter, and a camera. A sensor device  460  may be integrated with or measure a parameter associated with one or more components of the testing system  400 . For example, a sensor device  460  may be configured to measure a parameter (e.g., flow rate, pressure, temperature) of a fluid component  427  or a fluid  437  flowing through the piping  488  at a particular location (e.g., between a fluid component source  428  and a corresponding injection system  438 , between the header  489  and the testing module  470 , between the testing module  470  and the post-testing fluid collection system  450 ). 
     As another example, a sensor device  460  may be configured to determine how open or closed a valve  485  within the testing system  400  is. As yet another example, one or more sensor devices  460  may be used to characterize (e.g., identify an amount of) scale depositions  213  that have accumulated on proppant  112  in a testing vessel  472 . In some cases, a number of sensor devices  460 , each measuring a different parameter, may be used in combination to determine and confirm whether a controller  404  should take a particular action (e.g., operate a valve  485 , operate or adjust the operation of the testing module  470 ). When a sensor device  460  includes its own controller  404  (or portions thereof), then the sensor device  460  may be considered a type of computer device, as discussed below with respect to  FIG.  6   . 
     A user  451  may be any person that interacts, directly or indirectly, with a controller  404  and/or any other component of the testing system  400 . Examples of a user  451  may include, but are not limited to, a business owner, a research scientist, an engineer, a company representative, a geologist, a consultant, a drilling engineer, a contractor, and a manufacturer&#39;s representative. A user  451  may use one or more user systems  455 , which may include a display (e.g., a GUI). A user system  455  of a user  451  may interact with (e.g., send data to, obtain data from) the controller  404  via an application interface and using the communication links  405 . The user  451  may also interact directly with the controller  404  through a user interface (e.g., keyboard, mouse, touchscreen). 
     The network manager  480  is a device or component that controls all or a portion (e.g., a communication network, the controller  404 ) of the testing system  400 . The network manager  480  may be substantially similar to the controller  404 , as described above. For example, the network manager  480  may include a controller that has one or more components and/or similar functionality to some or all of the controller  404 . Alternatively, the network manager  480  may include one or more of a number of features in addition to, or altered from, the features of the controller  404 . As described herein, control and/or communication with the network manager  480  may include communicating with one or more other components of the same testing system  400  or another system. In such a case, the network manager  480  may facilitate such control and/or communication. The network manager  480  may be called by other names, including but not limited to a master controller, a network controller, and an enterprise manager. The network manager  480  may be considered a type of computer device, as discussed below with respect to  FIG.  6   . 
     Interaction between each controller  404 , the sensor devices  460 , the users  451  (including any associated user systems  455 ), the network manager  480 , and other components (e.g., the valves  485 , an injection system  438 , the testing module  470 , and the post-testing fluid collection system  450 ) of the testing system  400  may be conducted using communication links  405  and/or power transfer links  487 . Each communication link  405  may include wired (e.g., Class 1 electrical cables, Class 2 electrical cables, electrical connectors, Power Line Carrier, RS485) and/or wireless (e.g., Wi-Fi, Zigbee, visible light communication, cellular networking, Bluetooth, Bluetooth Low Energy (BLE), ultrawide band (UWB), WirelessHART, ISA100) technology. A communication link  405  may transmit signals (e.g., communication signals, control signals, data) between each controller  404 , the sensor devices  460 , the users  451  (including any associated user systems  455 ), the network manager  480 , and the other components of the testing system  400 . 
     Each power transfer link  487  may include one or more electrical conductors, which may be individual or part of one or more electrical cables. In some cases, as with inductive power, power may be transferred wirelessly using power transfer links  487 . A power transfer link  487  may transmit power between each controller  404 , the sensor devices  460 , the users  451  (including any associated user systems  455 ), the network manager  480 , and the other components of the testing system  400 . Each power transfer link  487  may be sized (e.g., 12 gauge, 18 gauge, 4 gauge) in a manner suitable for the amount (e.g., 480V, 24V, 120V) and type (e.g., alternating current, direct current) of power transferred therethrough. 
       FIG.  5    shows a system diagram of a controller  404  according to certain example embodiments. Referring to  FIGS.  1 A through  5   , the controller  404  may be substantially the same as a controller  404  discussed above with respect to  FIG.  4   . The controller  404  includes multiple components. In this case, the controller  404  of  FIG.  5    includes a control engine  506 , a communication module  507 , a timer  535 , a power module  530 , a storage repository  531 , a hardware processor  521 , a memory  522 , a transceiver  524 , an application interface  526 , and, optionally, a security module  528 . The controller  404  (or components thereof) may be located at or near the various components of the testing system  400 . In addition, or in the alternative, the controller  404  (or components thereof) may be located remotely from (e.g., in the cloud, at an office building) the various components of the testing system  400 . 
     The storage repository  531  may be a persistent storage device (or set of devices) that stores software and data used to assist the controller  404  in communicating with one or more other components of a system, such as the users  451  (including associated user systems  455 ), each injection system  438 , the testing module  470 , each post-testing fluid collection system  450 , the network manager  480 , and the sensor devices  460  of the testing system  400  of  FIG.  4    above. In one or more example embodiments, the storage repository  531  stores one or more protocols  532 , algorithms  533 , and stored data  534 . 
     The protocols  532  of the storage repository  531  may be any procedures (e.g., a series of method steps) and/or other similar operational processes that the control engine  506  of the controller  404  follows based on certain conditions at a point in time. The protocols  532  may include any of a number of communication protocols that are used to send and/or obtain data between the controller  404  and other components of a system (e.g., testing system  400 ). Such protocols  532  used for communication may be a time-synchronized protocol. Examples of such time-synchronized protocols may include, but are not limited to, a highway addressable remote transducer (HART) protocol, a wirelessHART protocol, and an International Society of Automation (ISA) 100 protocol. In this way, one or more of the protocols  532  may provide a layer of security to the data transferred within a system (e.g., testing system  400 ). Other protocols  532  used for communication may be associated with the use of Wi-Fi, Zigbee, visible light communication (VLC), cellular networking, BLE, UWB, and Bluetooth. 
     The algorithms  533  may be any formulas, mathematical models, forecasts, simulations, and/or other similar tools that the control engine  506  of the controller  404  uses to reach a computational conclusion. For example, one or more algorithms  533  may be used, in conjunction with one or more protocols  532 , to assist the controller  404  to determine when to start, adjust, and/or stop the operation of the testing module  470  and/or the post-testing fluid collection system  450 . As another example, one or more algorithms  533  may be used, in conjunction with one or more protocols  532 , to assist the controller  404  to determine when to start, adjust, and/or stop the operation of an injection system  438 . As yet another example, one or more algorithms  533  may be used, in conjunction with one or more protocols  532 , to assist the controller  404  to identify an optimal formulation of a fluid to reduce or eliminate scale depositions  213  on proppant  112  within a testing vessel  472 . As still another example, one or more algorithms  533  may be used, in conjunction with one or more protocols  532 , to assist the controller  404  in trending the performance of a fluid under certain conditions over time. 
     An example of an algorithm  533  is represented by the formula: Q=[kA(P i −P o )]÷μL, where Q is a flow rate (in cm 3 /s), P i  is inlet fluid pressure (in Pa), P o  is outlet fluid pressure (in Pa), μ is dynamic viscosity of the fluid (poise or Pa·S), L is the length of the material in the testing vessel  472  (in cm), k is the permeability of the materials  475  in the testing vessel  472  (in mD), and A is the area of the materials  475  in the testing vessel  472  (in cm 2 ). 
     Stored data  534  may be any data associated with a field (e.g., the subterranean formation  110 , the induced fractures  101 , the rock matrices  162  within the volume  190  adjacent to a wellbore  120 , the characteristics of proppant  112  used in a field operation), other fields (e.g., other wellbores and subterranean formations), the other components (e.g., the user systems  455 , the testing module  270 , the materials  475  in the testing vessel  472 , the post-testing fluid collection system  450 ), including associated equipment (e.g., motors, pumps, compressors), of the testing system  400 , measurements made by the sensor devices  460 , threshold values, tables, results of previously run or calculated algorithms  533 , updates to protocols  532 , user preferences, and/or any other suitable data. Such data may be any type of data, including but not limited to historical data, present data, and future data (e.g., forecasts). The stored data  534  may be associated with some measurement of time derived, for example, from the timer  535 . 
     Examples of a storage repository  531  may include, but are not limited to, a database (or a number of databases), a file system, cloud-based storage, a hard drive, flash memory, some other form of solid-state data storage, or any suitable combination thereof. The storage repository  531  may be located on multiple physical machines, each storing all or a portion of the communication protocols  532 , the algorithms  533 , and/or the stored data  534  according to some example embodiments. Each storage unit or device may be physically located in the same or in a different geographic location. 
     The storage repository  531  may be operatively connected to the control engine  506 . In one or more example embodiments, the control engine  506  includes functionality to communicate with the users  451  (including associated user systems  455 ), the sensor devices  460 , the network manager  480 , and the other components in the testing system  400 . More specifically, the control engine  506  sends information to and/or obtains information from the storage repository  531  in order to communicate with the users  451  (including associated user systems  455 ), the sensor devices  460 , the network manager  480 , and the other components of the testing system  400 . As discussed below, the storage repository  531  may also be operatively connected to the communication module  507  in certain example embodiments. 
     In certain example embodiments, the control engine  506  of the controller  404  controls the operation of one or more components (e.g., the communication module  507 , the timer  535 , the transceiver  524 ) of the controller  404 . For example, the control engine  506  may activate the communication module  507  when the communication module  507  is in “sleep” mode and when the communication module  507  is needed to send data obtained from another component (e.g., a sensor device  460 ) in the testing system  400 . In addition, the control engine  506  of the controller  404  may control the operation of one or more other components (e.g., the testing module  470 , the post-testing fluid collection system  450 , an injection system  438 ), or portions thereof, of the testing system  400 . 
     The control engine  506  of the controller  404  may communicate with one or more other components of the testing system  400 . For example, the control engine  506  may use one or more protocols  532  to facilitate communication with the sensor devices  460  to obtain data (e.g., measurements of various parameters, such as temperature, pressure, and flow rate), whether in real time or on a periodic basis and/or to instruct a sensor device  460  to take a measurement. The control engine  506  may use measurements of parameters taken by sensor devices  460  while a fluid flows through the materials  475  in a testing vessel  472 , as well as one or more protocols  532  and/or algorithms  533 , to analyze the performance of the fluid  437  (e.g., that includes a scale inhibitor with a concentration ranging from lower (e.g., 1 ppmv) concentrations to higher (e.g., 50 ppmv, up to 20%) concentrations) in reducing scale depositions  213  on proppant  112 , rock, and/or other components of the materials  475  in the testing vessel  472 . 
     As yet another example, the control engine  506  may use one or more algorithms  533  and/or protocols  532  to recommend a change to the formulation (e.g., adding a fluid component  427 , removing a fluid component  427 , increasing an amount of a fluid component  427 , decreasing an amount of a fluid component  427 ) of a fluid  437  in an attempt to improve reduction of scale depositions  213  on some or all of the materials  475 . For instance, a fluid  437  may include a scale inhibitor to prevent/inhibit the formation of new scale depositions  213  from an aqueous phase. As another example, a fluid  437  may include chelants, an acid treatment product, or a scale removal product to remove existing scale depositions  213 . The system  400  may be used for either or both purposes. As a specific example, the materials  475  may include proppant  112 . An initial fluid  437  that flows through the materials  475  in the testing vessel  472  of the testing module  470  may cause scale depositions  213  to form on the proppant  112 . Later, a different fluid  437  that includes a non-scaling brine (e.g., a cation brine only) may flow through the materials  475  in the testing vessel  472  of the testing module  470  to understand how the permeability of some or all of the materials  475  evolves over time. 
     The control engine  506  may generate and process data associated with control, communication, and/or other signals sent to and obtained from the users  451  (including associated user systems  455 ), the sensor devices  460 , the network manager  480 , and the other components of the testing system  400 . In certain embodiments, the control engine  506  of the controller  404  may communicate with one or more components of a system external to the testing system  400 . For example, the control engine  506  may interact with an inventory management system by ordering replacements for components or pieces of equipment (e.g., a sensor device  460 , a valve  485 , a motor) within the testing system  400  that has failed or is failing. As another example, the control engine  506  may interact with a contractor or workforce scheduling system by arranging for the labor needed to replace a component or piece of equipment in the testing system  400 . In this way and in other ways, the controller  404  is capable of performing a number of functions beyond what could reasonably be considered a routine task. 
     In certain example embodiments, the control engine  506  may include an interface that enables the control engine  506  to communicate with the sensor devices  460 , the user systems  455 , the network manager  480 , and the other components of the testing system  400 . For example, if a user system  455  operates under IEC Standard 62386, then the user system  455  may have a serial communication interface that will transfer data to the controller  404 . Such an interface may operate in conjunction with, or independently of, the protocols  532  used to communicate between the controller  404  and the users  451  (including corresponding user systems  455 ), the sensor devices  460 , the network manager  480 , and the other components of the testing system  400 . 
     The control engine  506  (or other components of the controller  404 ) may also include one or more hardware components and/or software elements to perform its functions. Such components may include, but are not limited to, a universal asynchronous receiver/transmitter (UART), a serial peripheral interface (SPI), a direct-attached capacity (DAC) storage device, an analog-to-digital converter, an inter-integrated circuit (I2C), and a pulse width modulator (PWM). 
     The communication module  507  of the controller  404  determines and implements the communication protocol (e.g., from the protocols  532  of the storage repository  531 ) that is used when the control engine  506  communicates with (e.g., sends signals to, obtains signals from) the user systems  455 , the sensor devices  460 , the network manager  480 , and the other components of the testing system  400 . In some cases, the communication module  507  accesses the stored data  534  to determine which communication protocol is used to communicate with another component of the testing system  400 . In addition, the communication module  507  may identify and/or interpret the communication protocol of a communication obtained by the controller  404  so that the control engine  506  may interpret the communication. The communication module  507  may also provide one or more of a number of other services with respect to data sent from and obtained by the controller  404 . Such services may include, but are not limited to, data packet routing information and procedures to follow in the event of data interruption. 
     The timer  535  of the controller  404  may track clock time, intervals of time, an amount of time, and/or any other measure of time. The timer  535  may also count the number of occurrences of an event, whether with or without respect to time. Alternatively, the control engine  506  may perform a counting function. The timer  535  is able to track multiple time measurements and/or count multiple occurrences concurrently. The timer  535  may track time periods based on an instruction obtained from the control engine  506 , based on an instruction obtained from a user  451 , based on an instruction programmed in the software for the controller  404 , based on some other condition (e.g., the occurrence of an event) or from some other component, or from any combination thereof. In certain example embodiments, the timer  535  may provide a time stamp for each packet of data obtained from another component (e.g., a sensor device  460 ) of the testing system  400 . 
     The power module  530  of the controller  404  obtains power from a power supply (e.g., AC mains) and manipulates (e.g., transforms, rectifies, inverts) that power to provide the manipulated power to one or more other components (e.g., the timer  535 , the control engine  506 ) of the controller  404 , where the manipulated power is of a type (e.g., alternating current, direct current) and level (e.g., 12V, 24V, 120V) that may be used by the other components of the controller  404 . In some cases, the power module  530  may also provide power to one or more of the sensor devices  460 . 
     The power module  530  may include one or more of a number of single or multiple discrete components (e.g., transistor, diode, resistor, transformer) and/or a microprocessor. The power module  530  may include a printed circuit board, upon which the microprocessor and/or one or more discrete components are positioned. In addition, or in the alternative, the power module  530  may be a source of power in itself to provide signals to the other components of the controller  404 . For example, the power module  530  may be or include an energy storage device (e.g., a battery). As another example, the power module  530  may be or include a localized photovoltaic power system. 
     The hardware processor  521  of the controller  404  executes software, algorithms (e.g., algorithms  533 ), and firmware in accordance with one or more example embodiments. Specifically, the hardware processor  521  may execute software on the control engine  506  or any other portion of the controller  404 , as well as software used by the users  451  (including associated user systems  455 ), the network manager  480 , and/or other components of the testing system  400 . The hardware processor  521  may be an integrated circuit, a central processing unit, a multi-core processing chip, SoC, a multi-chip module including multiple multi-core processing chips, or other hardware processor in one or more example embodiments. The hardware processor  521  may be known by other names, including but not limited to a computer processor, a microprocessor, and a multi-core processor. 
     In one or more example embodiments, the hardware processor  521  executes software instructions stored in memory  522 . The memory  522  includes one or more cache memories, main memory, and/or any other suitable type of memory. The memory  522  may include volatile and/or non-volatile memory. The memory  522  may be discretely located within the controller  404  relative to the hardware processor  521 . In certain configurations, the memory  522  may be integrated with the hardware processor  521 . 
     In certain example embodiments, the controller  404  does not include a hardware processor  521 . In such a case, the controller  404  may include, as an example, one or more field programmable gate arrays (FPGA), one or more insulated-gate bipolar transistors (IGBTs), and/or one or more integrated circuits (ICs). Using FPGAs, IGBTs, ICs, and/or other similar devices known in the art allows the controller  404  (or portions thereof) to be programmable and function according to certain logic rules and thresholds without the use of a hardware processor. Alternatively, FPGAs, IGBTs, ICs, and/or similar devices may be used in conjunction with one or more hardware processors  521 . 
     The transceiver  524  of the controller  404  may send and/or obtain control and/or communication signals. Specifically, the transceiver  524  may be used to transfer data between the controller  404  and the users  451  (including associated user systems  455 ), the sensor devices  460 , the network manager  480 , and the other components of the testing system  400 . The transceiver  524  may use wired and/or wireless technology. The transceiver  524  may be configured in such a way that the control and/or communication signals sent and/or obtained by the transceiver  524  may be obtained and/or sent by another transceiver that is part of a user system  455 , a sensor device  460 , the network manager  480 , and/or another component of the testing system  400 . The transceiver  524  may send and/or obtain any of a number of signal types, including but not limited to radio frequency signals. 
     When the transceiver  524  uses wireless technology, any type of wireless technology may be used by the transceiver  524  in sending and obtaining signals. Such wireless technology may include, but is not limited to, Wi-Fi, Zigbee, VLC, cellular networking, BLE, UWB, and Bluetooth. The transceiver  524  may use one or more of any number of suitable communication protocols (e.g., ISA100, HART) when sending and/or obtaining signals. 
     Optionally, in one or more example embodiments, the security module  528  secures interactions between the controller  404 , the users  451  (including associated user systems  455 ), the sensor devices  460 , the network manager  480 , and the other components of the testing system  400 . More specifically, the security module  528  authenticates communication from software based on security keys verifying the identity of the source of the communication. For example, user software may be associated with a security key enabling the software of a user system  455  to interact with the controller  404 . Further, the security module  528  may restrict receipt of information, requests for information, and/or access to information. 
     A user  451  (including an associated user system  455 ), the sensor devices  460 , the network manager  480 , and the other components of the testing system  400  may interact with the controller  404  using the application interface  526 . Specifically, the application interface  526  of the controller  404  obtains data (e.g., information, communications, instructions, updates to firmware) from and sends data (e.g., information, communications, instructions) to the user systems  455  of the users  451 , the sensor devices  460 , the network manager  480 , and/or the other components of the testing system  400 . Examples of an application interface  526  may be or include, but are not limited to, an application programming interface, a web service, a data protocol adapter, some other hardware and/or software, or any suitable combination thereof. Similarly, the user systems  455  of the users  451 , the sensor devices  460 , the network manager  480 , and/or the other components of the testing system  400  may include an interface (similar to the application interface  526  of the controller  404 ) to obtain data from and send data to the controller  404  in certain example embodiments. 
     In addition, as discussed above with respect to a user system  455  of a user  451 , one or more of the sensor devices  460 , the network manager  480 , and/or one or more of the other components of the testing system  400  may include a user interface. Examples of such a user interface may include, but are not limited to, a graphical user interface, a touchscreen, a keyboard, a monitor, a mouse, some other hardware, or any suitable combination thereof. 
     The controller  404 , the users  451  (including associated user systems  455 ), the sensor devices  460 , the network manager  480 , and the other components of the testing system  400  may use their own system or share a system in certain example embodiments. Such a system may be, or contain a form of, an Internet-based or an intranet-based computer system that is capable of communicating with various software. A computer system includes any type of computing device and/or communication device, including but not limited to the controller  404 . Examples of such a system may include, but are not limited to, a desktop computer with a Local Area Network (LAN), a Wide Area Network (WAN), Internet or intranet access, a laptop computer with LAN, WAN, Internet or intranet access, a smart phone, a server, a server farm, an android device (or equivalent), a tablet, smartphones, and a personal digital assistant (PDA). Such a system may correspond to a computer system as described below with regard to  FIG.  6   . 
     Further, as discussed above, such a system may have corresponding software (e.g., user system software, sensor device software, controller software). The software may execute on the same or a separate device (e.g., a server, mainframe, desktop personal computer (PC), laptop, PDA, television, cable box, satellite box, kiosk, telephone, mobile phone, or other computing devices) and may be coupled by the communication network (e.g., Internet, Intranet, Extranet, LAN, WAN, or other network communication methods) and/or communication channels, with wire and/or wireless segments according to some example embodiments. The software of one system may be a part of, or operate separately but in conjunction with, the software of another system within the testing system  400 . 
       FIG.  6    illustrates one embodiment of a computing device  618  that implements one or more of the various techniques described herein, and which is representative, in whole or in part, of the elements described herein pursuant to certain example embodiments. For example, a controller  404  (including components thereof, such as a control engine  506 , a hardware processor  520 , a storage repository  531 , a power module  530 , and a transceiver  524 ) may be considered a computing device  618 . Computing device  618  is one example of a computing device and is not intended to suggest any limitation as to scope of use or functionality of the computing device and/or its possible architectures. Neither should the computing device  618  be interpreted as having any dependency or requirement relating to any one or combination of components illustrated in the example computing device  618 . 
     The computing device  618  includes one or more processors or processing units  614 , one or more memory/storage components  615 , one or more input/output (I/O) devices  616 , and a bus  617  that allows the various components and devices to communicate with one another. The bus  617  represents one or more of any of several types of bus structures, including a memory bus or memory controller, a peripheral bus, an accelerated graphics port, and a processor or local bus using any of a variety of bus architectures. The bus  617  includes wired and/or wireless buses. 
     The memory/storage component  615  represents one or more computer storage media. The memory/storage component  615  includes volatile media (such as random access memory (RAM)) and/or nonvolatile media (such as read only memory (ROM), flash memory, optical disks, magnetic disks, and so forth). The memory/storage component  615  includes fixed media (e.g., RAM, ROM, a fixed hard drive, etc.) as well as removable media (e.g., a Flash memory drive, a removable hard drive, an optical disk, and so forth). 
     One or more I/O devices  616  allow a user  451  to enter commands and information to the computing device  618 , and also allow information to be presented to the user  160  and/or other components or devices. Examples of input devices  616  include, but are not limited to, a keyboard, a cursor control device (e.g., a mouse), a microphone, a touchscreen, and a scanner. Examples of output devices include, but are not limited to, a display device (e.g., a monitor or projector), speakers, outputs to a lighting network (e.g., DMX card), a printer, and a network card. 
     Various techniques are described herein in the general context of software or program modules. Generally, software includes routines, programs, objects, components, data structures, and so forth that perform particular tasks or implement particular abstract data types. An implementation of these modules and techniques are stored on or transmitted across some form of computer readable media. Computer readable media is any available non-transitory medium or non-transitory media that is accessible by a computing device. By way of example, and not limitation, computer readable media includes “computer storage media”. 
     “Computer storage media” and “computer readable medium” include volatile and non-volatile, removable and non-removable media implemented in any method or technology for storage of information such as computer readable instructions, data structures, program modules, or other data. Computer storage media include, but are not limited to, computer recordable media such as RAM, ROM, EEPROM, flash memory or other memory technology, CD-ROM, digital versatile disks (DVD) or other optical storage, magnetic cassettes, magnetic tape, magnetic disk storage or other magnetic storage devices, or any other medium which is used to store the desired information and which is accessible by a computer. 
     The computer device  618  is connected to a network (not shown) (e.g., a LAN, a WAN such as the Internet, cloud, or any other similar type of network) via a network interface connection (not shown) according to some example embodiments. Those skilled in the art will appreciate that many different types of computer systems exist (e.g., desktop computer, a laptop computer, a personal media device, a mobile device, such as a cell phone or personal digital assistant, or any other computing system capable of executing computer readable instructions), and the aforementioned input and output means take other forms, now known or later developed, in other example embodiments. Generally speaking, the computer system  618  includes at least the minimal processing, input, and/or output means necessary to practice one or more embodiments. 
     Further, those skilled in the art will appreciate that one or more elements of the aforementioned computer device  618  is located at a remote location and connected to the other elements over a network in certain example embodiments. Further, one or more embodiments is implemented on a distributed system having one or more nodes, where each portion of the implementation (e.g., an injection system  438 , the testing module  470 , the post-testing fluid collection system  450 ) is located on a different node within the distributed system. In one or more embodiments, the node corresponds to a computer system. Alternatively, the node corresponds to a processor with associated physical memory in some example embodiments. The node alternatively corresponds to a processor with shared memory and/or resources in some example embodiments. 
       FIG.  7    shows a flowchart  799  of a method for evaluating a fluid for reducing scale deposition within a fractured subterranean formation according to certain example embodiments. While the various steps in this flowchart  799  are presented sequentially, one of ordinary skill will appreciate that some or all of the steps may be executed in different orders, may be combined or omitted, and some or all of the steps may be executed in parallel. Further, in one or more of the example embodiments, one or more of the steps shown in this example method may be omitted, repeated, and/or performed in a different order. 
     In addition, a person of ordinary skill in the art will appreciate that additional steps not shown in  FIG.  7    may be included in performing this method. Accordingly, the specific arrangement of steps should not be construed as limiting the scope. Further, a particular computing device, such as the computing device discussed above with respect to  FIG.  6   , may be used to perform one or more of the steps for the methods shown in  FIG.  7    in certain example embodiments. Any of the functions performed below by a controller  404  may involve the use of one or more protocols  532 , one or more algorithms  533 , and/or stored data  534  stored in a storage repository  531 . 
     The method shown in  FIG.  7    is merely an example that may be performed by using an example system described herein. In other words, systems for evaluating a fluid for reducing scale deposition within a fractured subterranean formation may perform other functions using other methods in addition to and/or aside from those shown in  FIG.  7   . Referring to  FIGS.  1 A  through  7 , the method shown in the flowchart  799  of  FIG.  7    begins at the START step and proceeds to step  781 , where information about the materials  475  inside a testing vessel  472  is obtained. As used herein, the term “obtaining” may include receiving, retrieving, accessing, generating, etc. or any other manner of obtaining the information. The testing vessel  472  may be part of a testing module  470 . 
     The information may be obtained by a controller  404  (or an obtaining component thereof), which may include the controller  404  of  FIG.  5    above, using one or more algorithms  533  and/or one or more protocols  532 . The information may be obtained from a user  451 , including an associated user system  455 . In addition, or in the alternative, the information may be obtained from one or more sensor devices  460  that measure various parameters. Examples of the information obtained may include, but are not limited to, a composition (e.g., proppant  112 , rock) of the materials  475 , size of proppant  112 , rock type, size of the rock, permeability, porosity, and the arrangement of the materials  475  within the testing vessel  472  with respect to the flow of the fluid  437  (to be representative of field conditions). In certain example embodiments, the materials  475  include rock and proppant. The materials  475  may be designed to be representative of the fractured subterranean formation  110  adjacent to the wellbore  120 . In some cases, solid scale inhibitors may additionally or alternatively be among the materials  475 . 
     The information may also be associated with the testing vessel  472  that contains the materials  475 . Information associated with the testing vessel  472  may include, but is not limited to, the dimensions (e.g., length, width, height, cross-sectional shape) of the testing vessel  472  and the material (e.g., glass, stainless steel) of the testing vessel  472 . The information may be obtained at one time (e.g., prior to testing), over a period of time, periodically, or on some other basis. The information may be currently obtained data. In addition, or in the alternative, the data may be historical (e.g., data obtained from a prior field operation of the subterranean formation  110 ). 
     In step  782 , a fluid  437  is provided that flows through the testing vessel  472 . Specifically, the fluid  437  flows through the materials  475  within the testing vessel  472 . The fluid  437  may be made up of multiple fluid components  427 . Each fluid component  427  of a fluid  437  may be drawn from a fluid component source  428  using an associated injection system  438  and piping  488 . The fluid  437  may be provided to flow through the testing vessel  472  using one or more injection systems  438  or an independent pumping system. The fluid components  427  of the fluid  437  may mix together naturally in a header  489  of the piping  488  and/or using a mixing module  465 . 
     The composition of the fluid  437  may be known by a controller  404 . The composition of the fluid  437  may include a specific identification (e.g., CA 2+ , HCO 3   − ) of each fluid component  427  and the amount (e.g., 10 ppm, mg/L) of each fluid component  427 . For example, a user  451 , including an associated user system  455 , may communicate the composition of the fluid  437  to the controller  404 . As another example, a controller  404 , using one or more protocols  532  and/or one or more algorithms  533 , may determine the composition of a fluid  437  that may be tested. In such a case, a controller  404  may communicate, using one or more protocols  532 , this composition to a user  451  so that the user  451  may manipulate the appropriate fluid component sources  428  and associated injection systems  438  to attain the desired fluid  437 . Alternatively, a controller  404  may manipulate, using one or more algorithms  533  and/or one or more protocols  532 , the appropriate fluid component sources  428  and associated injection systems  438  to attain the desired fluid  437 . The fluid  437  flows through the materials  475  in the testing vessel  472  continually over a period of time (e.g., hours, days, months). 
     In certain example embodiments, a controller  404  may also set and/or control the environment to which the materials  475  in the testing vessel  472  are exposed using one or more algorithms  533  and/or one or more protocols  532 . For example, if a goal of the testing is to subject the materials  475  in the testing vessel  472  to conditions found in the subterranean formation  110 , then the controller  404  may accordingly control factors such as the temperature and the pressure applied to the testing vessel  472 . 
     In step  783 , parameters associated with the testing vessel  472  and the post-testing fluid  457  are evaluated. Some or all of the parameters may be measured by one or more sensor devices  460 . In addition, or in the alternative, some or all of the parameters may be calculated by a controller  404  using one or more algorithms  533  and/or one or more protocols  532 . The measured parameters may be received from the sensor devices  460  by a controller  404 . Examples of parameters that may be evaluated include, but are not limited to, a flow rate of the fluid  437  provided to the testing vessel  472 , the flow rate of the post-testing fluid  457  in the post-testing fluid collection system  450 , the pressure of an end of the testing vessel  472  receiving the fluid  437 , the pressure of an opposite end of the testing vessel  472  discharging the post-testing fluid  457 , a temperature of the materials  475  inside the testing vessel  472 , permeability of the materials  475  in the testing vessel  472 , and porosity of the materials  475  in the testing vessel  472 . 
     As an example, a differential pressure value (e.g., comparing the pressure before the testing vessel  472  and the pressure after the testing vessel  472 ) may provide information as to a change in permeability, an accumulation of scale depositions  213 , and/or plugging (e.g., scale deposition  213 ) of the material  475  within the testing vessel  472 . In some cases, the measured parameters may be compared to expected values. In addition, or in the alternative, the measured parameters may be used as variables in one or more algorithms  533  to generate an output. 
     In step  784 , a determination is made as to whether more data is needed. The need for more data may be based on one or more of a number of factors, including but not limited to time, trends, actual versus predicted values, and user preference. The determination may be made by a controller  404  using one or more algorithms  533  and/or one or more protocols  532 . The determination may be based, at least in part, on information provided by a user  451 , data collected from one or more sensor devices  460 , results of one or more algorithms  533 , and/or stored data  534  in the storage repository  531 . If more data is needed, then the process reverts to step  782 . If more data is not needed, then the process proceeds to step  785 . 
     In step  785 , a determination is made as to whether the fluid  437  needs to be adjusted. The determination may be made by a controller  404  based on the data obtained to that point and using one or more protocols  532  and/or algorithms  533 . The decision to adjust the fluid  437  may be based on one or more of a number of factors, including but not limited to the size and/or amount of accumulated scale depositions  213  in the materials  475  in the testing vessel  472 , the amount of time to that point that the materials  475  in the testing vessel  472  has been tested using the current fluid  437 , the continued effectiveness of the proppant  112  in propping channels within the materials  475  in the testing vessel  472 , and a change in the environment (e.g., pressure, temperature) of the materials  475  in the testing vessel  472 . If the fluid  437  needs to be adjusted, then the process proceeds to step  786 . If the fluid  437  does not need to be adjusted, then the process proceeds to step  787 . 
     In step  786 , the fluid  437  is adjusted. In other words, at least one aspect (e.g., an amount or concentration of a fluid component  427 , removal of a fluid component  427 , addition of a fluid component  427 ) of the fluid  437  is changed. The fluid  437  may be adjusted by a controller  404  (or an adjusting component thereof) using one or more algorithms  533  and/or one or more protocols  532 . The controller  404  may also determine precisely how the fluid  437  should be adjusted. Alternatively, the fluid  437  may be adjusted by a user  451 . In such a case, a controller  404  may provide instructions to the user  451  (or an associated user system  455 ) as to how the fluid  437  should be adjusted. When step  786  is finished, the process reverts to step  782 . When this occurs, the testing vessel  472  and/or the materials  475  may need to be cleaned or otherwise processed based on the original or previous fluid  437  flowing therethrough. In addition, or in the alternative, the conditions (e.g., temperature, pressure) to which the testing vessel  472  is exposed when the adjusted fluid  437  flows through the materials  475  may need to change relative to the corresponding conditions in existence when the original or previous fluid  437  flowed therethrough. 
     In step  787 , the materials  475  and scale in the testing vessel  472  and the post-testing fluid  457  in the post-testing fluid collection system  450  is evaluated. In other words, an evaluation is made as to the effectiveness of the fluid  437  used during testing based on the materials  475  and scale in the testing vessel  472  and the post-testing fluid  457  in the post-testing fluid collection system  450  after testing has concluded. The evaluation may be made by a controller  404  (or an evaluation component thereof) using one or more algorithms  533  and/or one or more protocols  532 . Alternatively, the evaluation may be made by a user  451  based on information provided to the user  451  (including an associated user system  455 ) by a controller  404 . 
     This step  787  may also include evaluating other aspects of the fractures  101  and areas adjacent to the wellbore  120 . Examples of such other aspects may include, but are not limited to, the amount of scale depositions  213  that is required to induce a significant decrease in permeability of a fracture  101 , whether mineral scale depositions  213  may block (e.g., by developing on proppant  112 , rock, and/or the frac face  102 ) fractures  101  propped by proppant  112 , the impact of scale depositions  213  on fluid flow at subsurface induced fractures  101 , the impact on solid depositions (e.g., scale depositions  213 ), subsurface integrity, and/or flow assurance risks (e.g., plugging, fluid flow restriction) due to crushing, embedding, and/or clustering of proppant  112 , the effectiveness and impact of the fluid  437  (including chemical additives (e.g., scale inhibitor)) on controlling solid (e.g., scale depositions  213 ) deposition risks, the impact of the size of proppant  112  on fluid flow assurance risks in subsurface fracture networks, scale removal for fractures  101  with rock presence propped by proppant  112 , the effectiveness of pre-packed solid scale inhibitors, scale inhibitor adsorption and desorption from rock adjacent to fractures  101 , scale squeeze treatment for hydraulically (or otherwise induced) fractures wells/reservoirs, the impact of the size of proppant  112  and water cut, the effectiveness and efficiency of subsurface chemical treatments, the impact of the fluid on specific types of scale depositions  213  (e.g., barite, calcium carbonate, iron oxide), and the impact of the fluid  437  on other types of solid deposition (e.g., asphaltene, sludge, fines). Any of these additional evaluations may be performed by a controller  404  (or an evaluation component thereof) using one or more protocols  532  and/or one or more algorithms  533 . 
     In step  788 , a recommendation about the fluid  437  is provided. The recommendation may be provided by a controller  404  (or a recommendation component thereof) using one or more protocols  532 . The recommendation may be provided to one or more users  451  (including associated user systems  455 ) and/or the network manager  480 . In one embodiment, a visual representation of the recommendation may be provided to one or more users  451  via an I/O device  616  such as a display, screen, etc. The recommendation about the fluid  437  may provide any level of detail about the fluid  437 , including but not limited to the precise composition of the fluid  437 , the amount of time that the fluid  437  is deemed to be effective, and the expected results (e.g., prevents accumulation of scale depositions  213 , slows the accumulation of scale depositions  213  by 75%) of using the fluid  437 . In certain example embodiments, the recommendation may be based on some of the other evaluations performed in step  787 . When step  788  is complete, the process proceeds to the END step. 
       FIGS.  8 A and  8 B  shows proppant  812  with scale deposition  813  according to certain example embodiments. Specifically,  FIG.  8 A  shows a micrographic (SEM) view of proppant  812 , and  FIG.  8 B  shows a detailed micrographic view of one piece of the proppant  812  of  FIG.  8 A . Referring to  FIGS.  1 A through  8 B , the proppant  812  shown in  FIG.  8 A  are all irregularly shaped and have varying sizes relative to each other. Similarly, as shown in  FIG.  8 B , the scale deposition  813  on one piece of the proppant  812  is irregular in terms of their shape, size (e.g., length, width, height), and location. The proppant  812  and scale  813  are substantially the same as the proppant  112  and scale depositions  213  discussed above. 
       FIG.  9    shows a graph  997  of differential pressure with respect to a testing vessel  472  using a fluid  437  over time according to certain example embodiments. Referring to  FIGS.  1 A through  9   , the graph  997  of  FIG.  9    has four plots that are laid out with differential pressure (in psi) along the vertical axis and time (in minutes) along the horizontal axis. The differential pressure may be established by determining a difference between a pressure (measured by one sensor device  460 ) at an inlet of a testing vessel  472  and a pressure (measured by one sensor device  460 ) at an outlet of the same testing vessel  472 . The fluid components  427  of the fluids  437  used for the plots in the graph  997  include 4000 mg/L of Ca 2+  and 6100 mg/L of HCO 3   − . The fluid components  427  of the fluids  437  may also include Na + , Cl + , K + , and/or other ions. To generate the plots in the graph  997  of  FIG.  9   , the fluid  437  is run through a testing vessel  472  of a testing module  470 , where the materials  475  in the testing vessel  472  include 40/70 mesh proppant (e.g., proppant  112 ). Elemental mapping (e.g., using EDS) reveals that the mesh proppant includes carbon, oxygen, aluminum, iron, and silicon. 
     Plot  991  represents the maximum differential pressure (representing substantial blockage) permitted in the testing module  470  at approximately 130 psi in this example. Plot  992  represents a fluid  437  that does not include any (0 ppm) scale inhibitor. With no scale inhibitor, the fluid  437  flowing through the materials  475  in the testing vessel  472  results in rapid scale deposition on proppants and blocks flow through the testing vessel  472  within 2 minutes. Plot  993  represents a fluid  437  that includes a fluid component  427  that is 10 ppm of scale inhibitor. With this small amount (10 ppm) of scale inhibitor, the fluid  437  flowing through the materials  475  in the testing vessel  472  results in somewhat slower scale deposition and blocks flow through the testing vessel  472  in approximately 13 minutes. Plot  994  represents a fluid  437  that includes a cation brine (e.g., a non-scaling brine). With the cation brine, the fluid  437  flowing through the materials  475  in the testing vessel  472  results in substantially no scale deposition, as the differential pressure remains constant at approximately 12 psi for the duration of the test (over 15 minutes). 
       FIG.  10    shows a graph  1097  of differential pressure with respect to a testing vessel  472  using another fluid  437  over time according to certain example embodiments. Referring to  FIGS.  1 A through  10   , the graph  1097  of  FIG.  10    has four plots that are laid out with differential pressure (in psi) along the vertical axis and time (in minutes) along the horizontal axis. The differential pressure may be established by determining a difference between a pressure (measured by one sensor device  460 ) at an inlet of a testing vessel  472  and a pressure (measured by one sensor device  460 ) at an outlet of the same testing vessel  472 . The fluid components  427  of the fluids  437  used for the plots in the graph  1097  include 400 mg/L of Ca 2+  and 610 mg/L of HCO 3   − . The fluid components  427  of the fluids  437  may also include Na + , Cl + , and K + . This is 1/10 th  the concentration of these fluid components  427  in the fluid  437  used in the plots for graph  997  of  FIG.  9   . To generate the plots in the graph  1097  of  FIG.  10   , the fluid  437  is run through a testing vessel  472  of a testing module  470 , where the materials  475  in the testing vessel  472  include 40/70 mesh proppant (e.g., proppant  112 ). Elemental mapping (e.g., using EDS) reveals that the mesh proppant includes carbon, oxygen, aluminum, iron, and silicon. In other words, the mesh proppant used for the plots of  FIG.  10    is the same as the mesh proppant used for the plots of  FIG.  9   . 
     Plot  1091  represents the maximum differential pressure (representing substantial blockage) permitted in the testing module  470  at approximately 130 psi in this example. Plot  1092  represents a fluid  437  that does not include any (0 ppm) scale inhibitor. With no scale inhibitor, the fluid  437  flowing through the materials  475  in the testing vessel  472  results in scale deposition and blocks flow through the testing vessel  472  within 22 minutes. This is significantly slower than plot  992  of  FIG.  9   , but the fastest among the plots in  FIG.  19   . Plot  1093  represents a fluid  437  that includes 10 ppm of scale inhibitor. With this small amount (10 ppm) of scale inhibitor, the fluid  437  flowing through the materials  475  in the testing vessel  472  results in somewhat slower scale deposition and blocks flow through the testing vessel  472  in well over 120 minutes. Plot  1094  represents a fluid  437  that includes 80 ppm of scale inhibitor. With this larger amount of scale inhibitor, the fluid  437  flowing through the materials  475  in the testing vessel  472  results in substantially no scale deposition, as the differential pressure remains constant at approximately 12 psi for the duration of the test (over 120 minutes). 
       FIG.  11    shows a graph  1198  of permeability with respect to materials  475  in a testing vessel  472  using the fluid of  FIG.  9    over time according to certain example embodiments. Referring to  FIGS.  1 A through  1 I , the graph  1198  of  FIG.  11    has four plots that are laid out with permeability (in mD) along the vertical axis and number of pore volumes along the horizontal axis. The fluid components  427  of the fluids  437  used for the plots in the graph  1198  include 4000 mg/L of Ca 2+  and 6100 mg/L of HCO 3   − , which is the same as the fluid  437  used for the plots in the graph  997  of  FIG.  9   . To generate the plots in the graph  1198  of  FIG.  11   , the fluid  437  is run through a testing vessel  472  of a testing module  470 , where the materials  475  in the testing vessel  472  includes 40/70 mesh proppant (e.g., proppant  112 ) as used for the graphs of  FIGS.  9  and  10    above. 
     Plot  1191  represents the minimum permeability (representing substantial blockage) permitted in the testing module  470  at approximately 1500 mD. Plot  1192  represents a fluid  437  that does not include any (0 ppm) scale inhibitor. With no scale inhibitor, the fluid  437  flowing through the materials  475  in the testing vessel  472  results in rapid scale deposition and blocks flow through the testing vessel  472  (reaches the minimum permeability) within 2 pore volumes. Plot  1193  represents a fluid  437  that includes 10 ppm of scale inhibitor. With this small amount (10 ppm) of scale inhibitor, the fluid  437  flowing through the materials  475  in the testing vessel  472  results in somewhat slower scale deposition and blocks flow through the testing vessel  472  in approximately 11 pore volumes. 
     Plot  1194  represents a fluid  437  that includes a cation brine. With the cation brine, the fluid  437  flowing through the materials  475  in the testing vessel  472  results in substantially no scale deposition, as the permeability remains constant at approximately 12000 mD for the duration of the test (over 14 pore volumes). One conclusion that may be drawn from the graph  1198  is that the scale inhibitor increases time required for blockage. Another conclusion that may be drawn from the graph  1198  is that the cation brine (without an anion brine) does not cause a significant change in permeability. In some alternative cases, a different type of non-scaling brine (e.g., DI water) may be used as the fluid  437  and generate similar results. 
       FIG.  12    shows a graph  1296  of calcite weight in proppant (e.g., proppant  112 ) within a testing vessel  472  after testing using the fluid  437  of  FIGS.  9  and  11    according to certain example embodiments. Referring to  FIGS.  1 A through  12   , the graph  1296  of  FIG.  12    shows two plots after testing conducted for  FIGS.  9  and  11    above. The graph  1296  shows that when the fluid  437  used during testing of the materials  475  in the testing vessel  472  had no scale inhibitor, there was no calcite found in the proppant of those materials  475 . By contrast, plots  1283  and  1284  in the graph  1296  show that when the fluid  437  used during testing of the materials  475  in the testing vessel  472  includes a scale inhibitor, there was calcite found in the proppant of those materials  475 . 
     Plot  1283  shows that when the fluid includes 5 ppm of a scale inhibitor, the calcite weight in the proppant is approximately 0.5%, as measured by Quantitative X-Ray Diffraction (QXRD) analysis, at the end of the test, where the remaining water is blown out of the testing vessel  472  (e.g., using air), and the remaining proppants  112  with scale deposition  213  on it were dried before characterization. Plot  1284  shows that when the fluid  437  includes 10 ppm of a scale inhibitor, the calcite weight in the proppant is approximately 0.43%, as measured by QXRD analysis at the end of the test. A number of conclusions may be reached from graph  1296 . For example, correlating to the graph  997  of  FIG.  9   , calcite is found in proppant for tests with increased differential pressure in the test module  470 . Also, a calcite weight of 0.4% or greater, as measured by QXRD analysis at the end of the test, may cause a significant decrease in permeability. Finally, scale depositions (e.g., scale depositions  213 ) is the cause of blockage in the materials  475  within the testing vessel  472 . 
       FIG.  13    shows a graph  1394  of elemental mapping by EDX of proppant tested with the fluid  437  of  FIGS.  9 ,  11 , and  12    that includes only the cation brine.  FIG.  14    shows a graph  1494  of elemental mapping by EDX of proppant tested with the fluid  437  of  FIGS.  9 ,  11 , and  12    that includes the 10 ppm scale inhibitor and the mixture of cation and anion brines. Referring to  FIGS.  1 A through  14   , the graph  1394  of  FIG.  13    shows that the mesh proppant includes carbon, oxygen, sodium, aluminum, silicon, and chlorine. The graph  1494  of  FIG.  14    shows that the mesh proppant includes carbon, oxygen, sodium, aluminum, silicon, chlorine, and calcium. In other words, the calcium peak in the graph  1494  of  FIG.  14    emerges when scaling conditions are brought out in testing. The fluid  437  that includes only the cation brine in the graph  1394  of  FIG.  13    contains Ca 2+  but no scaling tendency. These graphs of  FIGS.  13  and  14    reinforce the conclusion that calcite is formed on the proppant only during scaling conditions, and that the formed scale depositions  213  are the cause of the permeability decrease. 
       FIG.  15    shows a graph  1598  of permeability with respect to materials  475  in a testing vessel  472  using the fluid  437  of  FIG.  10    over time according to certain example embodiments. Referring to  FIGS.  1 A through  15   , the graph  1598  of  FIG.  15    has four plots that are laid out with permeability (in mD) along the vertical axis and number of pore volumes along the horizontal axis. The fluid components  427  of the fluids  437  used for the plots in the graph  1598  include 400 mg/L of Ca 2+  and 610 mg/L of HCO 3   − , which is similar to the fluid  437  used for the plots in the graph  997  of  FIG.  9   . To generate the plots in the graph  1598  of  FIG.  15   , the fluid  437  is run through a testing vessel  472  of a testing module  470 , where the materials  475  in the testing vessel  472  include 40/70 mesh proppant (e.g., proppant  152 ) as used for the graphs of  FIGS.  9  and  10    above. 
     Plot  1591  represents the minimum permeability (representing substantial blockage) permitted in the testing module  470  at approximately 1500 mD in this example. Plot  1592  represents a fluid  437  that does not include any (0 ppm) scale inhibitor. With no scale inhibitor, the fluid  437  flowing through the materials  475  in the testing vessel  472  results in rapid scale deposition and blocks flow through the testing vessel  472  (reaches the minimum permeability) within approximately 16 pore volumes. Plot  1593  represents a fluid  437  that includes 10 ppm of scale inhibitor. With this small amount (10 ppm) of scale inhibitor, the fluid  437  flowing through the materials  475  in the testing vessel  472  results in a reduced rate of scale deposition and blocks flow through the testing vessel  472  in well over 110 pore volumes. 
     Plot  1594  represents a fluid  437  that includes 80 ppm of scale inhibitor added into the fluid  437  (in that case, a brine) that was used to generate plot  1592 . With the elevated amount of scale inhibitor, the fluid  437  flowing through the materials  475  in the testing vessel  472  results in substantially no scale deposition, as the permeability remains constant at approximately 12000 mD for the duration of the test (over 110 pore volumes). One conclusion that may be drawn from the graph  1598  is that the scale inhibitor increases time required for blockage. Another conclusion that may be drawn from the graph  1598  is that the increase in the scale inhibitor to 80 ppm does not cause a significant change in permeability and prevented scale depositions  213  on the materials  475 . 
       FIG.  16    shows a graph  1696  of calcite weight in proppant (e.g., proppant  112 ) within a testing vessel  472  after testing using the fluid  437  of  FIGS.  10  and  15    according to certain example embodiments. Referring to  FIGS.  1 A through  16   , the graph  1696  of  FIG.  16    shows two plots after testing conducted for  FIGS.  10  and  15    above. The graph  1696  shows that when the fluid components  427  of the fluids  437  used during testing of the materials  475  in the testing vessel  472  had no brine or brine with an elevated (in this case, 80 ppm) amount of scale inhibitor, there was no calcite found in the proppant of those materials  475 . By contrast, plots  1683  and  1684  in the graph  1696  show that when the fluid used during testing of the materials  475  in the testing vessel  472  includes a brine and little or no scale inhibitor, there was calcite found in the proppant of those materials  475 . 
     Plot  1683  shows that when the fluid  437  includes a scaling brine (e.g., a 1:1 ratio cation brine-anion brine mixture) and 0 ppm of a scale inhibitor, the calcite weight in the proppant is approximately 0.5%. Plot  1684  shows that when the fluid  437  includes scaling brine and 10 ppm of a scale inhibitor, the calcite weight in the proppant is approximately 0.40%. A number of conclusions may be reached from graph  1696 . For example, correlating to the graph  1097  of  FIG.  10   , calcite is found in proppant for tests with increased differential pressure in the test module  470 . Also, a calcite weight of 0.4% or greater may cause a significant decrease in permeability (from ˜14000 mD to 1500 mD or lower). Finally, scale depositions (e.g., scale depositions  213 ) are the cause of blockage in the materials  475  within the testing vessel  472 . 
       FIG.  17    shows a graph  1794  of elemental mapping by EDX of proppant tested with the fluid  437  of  FIGS.  10 ,  15 , and  16    that includes the cation brine and 0 ppm of the scale inhibitor.  FIG.  18    shows a graph  1894  of elemental mapping by EDX of proppant tested with the fluid  437  of  FIGS.  10 ,  15 , and  16    that includes the cation brine and 80 ppm of scale inhibitor. Referring to  FIGS.  1 A through  18   , the graph  1794  of  FIG.  17    shows that the mesh proppant includes carbon, oxygen, aluminum, silicon, and calcium. The graph  1894  of  FIG.  18    shows that the mesh proppant includes carbon, oxygen, sodium, aluminum, and silicon. In other words, the calcium peak in the graph  1794  of  FIG.  17    emerges when scaling conditions are brought out in testing. The proppant  112  from the test with the fluid  437  that includes the cation brine and 80 ppm of scale inhibitor in the graph  1894  of  FIG.  18    has no significant calcium. These graphs of  FIGS.  17  and  18    reinforce the conclusion that calcite is formed on the proppant only during scaling conditions and caused the permeability decrease in the proppant. 
       FIG.  19    shows another diagram of part of a testing system  1900  for assessing and reducing subsurface deposition of scales and/or other solids according to certain example embodiments. Referring to  FIGS.  1 A through  19   , the portion of the testing system  1900  shown in  FIG.  19    may be substantially the same as the corresponding components of the testing system  400  of  FIG.  4   . For example, the portion of the testing system  1900  of  FIG.  19    includes three fluid component sources  1928 , three fluid components  1927 , three injection systems  1938 , piping  1988 , a sensor device  1960 , a valve  1988 , a testing module  1970  with a testing vessel  1972  having materials  1975  disposed therein, and a post-testing fluid collection system  1950 , which are substantially similar to the component sources  428 , the fluid components  427 , the injection systems  438 , the piping  488 , the sensor devices  460 , the valves  488 , the testing module  470 , the testing vessel  472 , the materials  475 , and the post-testing fluid collection system  450  of  FIG.  4   . 
     The first fluid component source  1928  of  FIG.  19    is in the form of an anion brine source  1928 - 1 , which releases an anion brine  1927 - 1  (a form of a fluid component  1927 ) that is moved toward the testing module  1970  by a pump  1938 - 1  (a form of an injection system  1938 ) through piping  1988 . The second fluid component source  1928  of  FIG.  19    is in the form of a scale inhibitor stock solution source  1928 - 2 , which releases a scale inhibitor stock solution  1927 - 2  (another form of a fluid component  1927 ) that is moved toward the testing module  1970  by a pump  1938 - 2  (another form of an injection system  1938 ) through piping  1988 . The third fluid component source  1928  of  FIG.  19    is in the form of a cation brine source  1928 - 3 , which releases a cation brine  1927 - 3  (yet another form of a fluid component  1927 ) that is moved toward the testing module  1970  by a pump  1938 - 3  (yet another form of an injection system  1938 ) through piping  1988 . 
     The three fluid component sources  1928  combine at a part of the piping  1988  upstream of the testing module  1970  that forms a header  1989 . When the three fluid component sources  1928  combine in the piping  1988 , a resulting fluid  1937 , which includes the anion brine  1927 - 1 , the scale inhibitor stock solution  1927 - 2 , and the cation brine  1927 - 3 , flows through some of the piping  1988  to the testing module  1970 . At the testing module  1970 , the fluid  1937  flows through the testing vessel  1972 , which in this case is in the form of a column  1972 . The column  1972  is filled (e.g., fully (packed), partly) with materials  1975 , which in this case are in the form of proppant and formation rocks (e.g., cuttings). 
     The differential pressure sensor  1960  (a form of a sensor device  460 ) of the system  1900  measures the difference between the pressure of the fluid  1937  entering the column  1972  and the pressure of the post-testing fluid  1957  (substantially the same as the post-testing fluid  457  of  FIG.  4   ) exiting the column  1972 . A controller (not shown, but substantially similar to a controller  404  of  FIG.  4   ) can control the valve  1988  in the form of a back pressure regulator  1988  if the values measured by the differential pressure sensor  1960  exceed a certain value or fall outside a range of values. The post-testing fluid  1957 , upon exiting the testing module  1970 , flows through some of the piping  1988  to the effluent sampling and analysis system  1950 , which is a form of a post-testing fluid collection system  450 . 
       FIGS.  20 A through  20 C  show an image of a testing system  2000  that is modeled after the testing system  1900  of  FIG.  19    according to certain example embodiments. Specifically,  FIG.  20 A  shows a front view of the testing system  2000 .  FIG.  20 B  shows a detailed view of part of the testing system  2000 .  FIG.  20 C  shows a front view of the column  2172  of the testing system  2000 . Referring to  FIGS.  1 A through  20 C , the testing system  2000  of  FIGS.  20 A through  20 C  includes three fluid component sources  2028 , three injection systems  2038 , piping  2088 , a sensor device  2060 , a pressure relief valve  2085 , a testing module  2070  with a column  2072  (a form of testing vessel  472 ) having materials (e.g., materials  1975 , hidden from view) disposed therein, and a post-testing fluid collection system  2050 . These components of the testing system  2000  are substantially similar to the corresponding components of the testing system  1900  of  FIG.  19    and the testing system  400  of  FIG.  4   . 
     The first fluid component source  2028  of  FIG.  20 A  is in the form of an anion brine source  2028 - 1 , which releases an anion brine (a form of a fluid component  427 ) that is moved toward the testing module  2070  by a pump  2038 - 1  (a form of an injection system  438 ) through piping  2088 . The second fluid component source  2028  of  FIG.  20 A  is in the form of a water source  2028 - 2 , which releases a water solution (another form of a fluid component  427 ) that is moved toward the testing module  2070  by a pump  2038 - 2  (another form of an injection system  438 ) through piping  2088 . In some cases, the water solution includes a scale inhibitor. The third fluid component source  2028  of  FIG.  20 A  is in the form of a cation brine source  2028 - 3 , which releases a cation brine (yet another form of a fluid component  427 ) that is moved toward the testing module  2070  by a pump  2038 - 3  (yet another form of an injection system  438 ) through piping  2088 . 
     The three fluid component sources  2028  combine at a part of the piping  2088  upstream of the testing module  2070  that forms a header  2089 . When the three fluid component sources  2028  combine in the piping  2088 , a resulting fluid (similar to the resulting fluid  437  of  FIG.  4   ), which includes the anion brine, the water solution, and the cation brine, flows through some of the piping  2088  to the testing module  2070 . At the testing module  2070 , the fluid flows through the column  2072  (a form of testing vessel  472 ). The column  2072  is filled (e.g., fully (packed), partly) with materials (hidden from view), such as proppant and formation rocks (e.g., cuttings). 
     The differential pressure sensor  2060  (a form of a sensor device  460 ) of the system  2000  measures the difference between the pressure of the fluid entering the column  2072  and the pressure of the post-testing fluid (substantially the same as the post-testing fluid  457  of  FIG.  4   ) exiting the column  2072 . The pressure relief valve  2085  can be adjusted when the values measured by the differential pressure sensor  2060  exceed a certain value or fall outside a range of values. The post-testing fluid, upon exiting the column  2072 , flows through some of the piping  2088  to the post-testing fluid collection system  2050 , which is a form of the post-testing fluid collection system  450  of  FIG.  4   . In this case, the column  2072 , the differential pressure sensor  2060 , the pressure relief valve  2085 , and some of the piping  2088 , including the header  2089 , are mounted to a frame  2039  that is substantially vertical. 
     As discussed above,  FIG.  20 C  shows an image of the column  2072  of the testing system  2000  according to certain example embodiments. The column  2072  in this case has a body  2073  having a cylindrical shape. The body  2073  in this case has an approximate length of 18 inches. In certain example embodiments, the length of the body  2073  of the column  2072  can range from 4 inches to 36 inches. The body  2073  of the column  2072  in this example is substantially cylindrical in shape with an inner diameter (ID) of approximately ⅛ inches and an approximate outside diameter (OD) of approximately ⅜ inch. In alternative embodiments, the body  2073  of the column  2072  can have other shapes that are not fully or partially cylindrical. In certain example embodiments, the ID of the body  2073  of the column  2072  can range from ⅛ inches to 2.5 inches, and the OD of the body  2073  of the column  2072  can range from ¼ inch to 3 inches. 
     The body  2073  of the column  2072  is designed to withstand the conditions (e.g., pressure, flow rate, acidity) at which the materials (e.g., materials  1975 ) disposed therein and the fluid (e.g., fluid  1937 ) flowing therethrough are tested. The body  2073  of the column  2072  can be made of one or more of any of a number of suitable materials, including but not limited to stainless steel, plexiglass, ceramics, PEEK, PTFE, corrosion resistant alloys (CRAs). In certain example embodiments, the inner walls of the body  2073  of the column  2072  may be featureless and smooth. The thickness of the wall of the body  2073  may be configured (e.g., 1/16 th  inch thick to ½ inch thick) to withstand a minimum pressure (e.g., 500 psig), a normal testing pressure (e.g., 3000 psig), and/or a maximum pressure (e.g., 6000 psig) that may be used during testing. In some cases, the thickness of the wall of the body  2073  may be configured to be substantially uniform along its length. 
     The column  2072  can include one or more coupling features  2074  that are configured to couple the column  2072  to one or more other components (e.g., piping  1988 ) of a testing system (e.g., testing system  1900 ). For example, in this case, the column  2072  has two coupling features  2074 , where one coupling feature  2074 - 1  is located toward one end of the body  2073  of the column  2072 , and where the other coupling feature  2074 - 2  is located toward the opposite end of the body  2073  of the column  2072 . In this case, the coupling features  2074  are configured substantially identically to each other in the form of threaded nuts that mate with complementary threads disposed on the outer perimeter of adjacent piping (e.g., piping  1988 ). In alternative embodiments, one or more of the coupling features  2074  may have a different configuration. Further, in alternative embodiments, the configuration of one coupling feature  2074  of the column  2072  can differ from the configuration of one or more of the other coupling features  2074  of the column  2072 . In any case, the coupling features  2074  are configured to couple to one or more other components of the testing system so that the desired testing conditions (e.g., pressure, flow rate) can be maintained. 
     In any case, one or more of the dimensions (e.g., the length, the outer diameter, the thread size) of a coupling feature  2074  can change based on one or more of a number of factors, including but not limited to the characteristics (e.g., outer diameter, length) of the body  2073  of the column  2072  and the characteristics (e.g., outer diameter, thread size) of another component (e.g., piping  1988 ) of the testing system (e.g., testing system  1900 ) to which the a coupling feature  2074  of the column  2072  is configured to be coupled. For example, a coupling feature  2074  have an outer diameter that ranges from approximately ¼″ to approximately 3″ and a length that ranges from approximately ½″ to approximately 1.5″. In certain example embodiments, a coupling feature  2074  has a substantially uniform outer surface. 
     As discussed above, an example testing system (e.g., testing system  400 , testing system  1900 , testing system  2000 ) can be used for one or more of a number of purposes using one or more of a number of analytical methods. The following Table 1 provides non-exclusive examples of some of these analytical methods and corresponding purposes. 
     
       
         
           
               
               
             
               
                 TABLE 1 
               
               
                   
               
               
                 ANALYTICAL METHOD 
                 PURPOSE 
               
               
                   
               
             
            
               
                 Scanning Electron Microscope 
                 Visualize morphology and perform elemental analysis 
               
               
                 (SEM) 
                 for materials (cutting, core, proppant, scales, etc.) 
               
               
                 Quantitative X-ray Diffraction 
                 Measure crystal structure and confirm scale type and 
               
               
                 (QXRD) 
                 material composition 
               
               
                 Differential Pressure 
                 Monitor pressure difference which is an indication of 
               
               
                   
                 scale deposition on materials inside packed column 
               
               
                 Photograph 
                 Overview of scale formation on materials 
               
               
                 Inductively coupled plasma-optical 
                 Elemental analysis for fluid samples 
               
               
                 emission spectrometry (ICP-OES) 
                   
               
               
                 Ion Chromatography (IC) 
                 Analyze water/brine composition 
               
               
                 pH probe 
                 Measure pH in water/brine samples 
               
               
                 X-ray Fluorescence (XRF) 
                 Elemental analysis 
               
               
                 Dissolution test 
                 Solid characterization 
               
               
                 X-ray mapping 
                 Evaluate element distribution 
               
               
                 Inductively coupled plasma-mass 
                 Elemental analysis for fluid samples 
               
               
                 spectrometry (ICP-MS) 
                   
               
               
                 Particle size analyzer 
                 Analyze particle size and distribution 
               
               
                 Stable isotope analysis 
                 Measure stable isotope ratio 
               
               
                   
               
            
           
         
       
     
     Example embodiments may be used for being representative of downhole conditions to determine one or more fluids (e.g., chemical products) that may inhibit or prevent the development of scale on proppant rock, and/or frac faces within induced fractures adjacent to a wellbore in a producing volume in a subterranean formation. Example embodiments may be used to fully or partially automate the process of generating different fluids from fluid components, providing the fluid that flows through materials in a testing vessel of a testing module, and evaluating the effectiveness of the fluid at reducing scale deposition or the accumulation thereof. Example embodiments may also communicate the results of an evaluation of a fluid, determine alternative fluids that may be more effective, generate those alternative fluids, and evaluate those alternative fluids during and after testing. Using example embodiments, the materials that are tested are subjected to conditions that are representative of those of a fractured subterranean formation. Example embodiments may provide a number of benefits. Such benefits may include, but are not limited to, ease of use, extending the life of a producing well, optimize use of proppant in fractures, flexibility, configurability, and compliance with applicable industry standards and regulations. 
     Although embodiments described herein are made with reference to example embodiments, it should be appreciated by those skilled in the art that various modifications are well within the scope and spirit of this disclosure. Those skilled in the art will appreciate that the example embodiments described herein are not limited to any specifically discussed application and that the embodiments described herein are illustrative and not restrictive. From the description of the example embodiments, equivalents of the elements shown therein will suggest themselves to those skilled in the art, and ways of constructing other embodiments using the present disclosure will suggest themselves to practitioners of the art. Therefore, the scope of the example embodiments is not limited herein.