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BACKGROUND 
       [0001]    The present disclosure relates to well systems, and more particularly to controlling flow in well systems. 
         [0002]    It is often desirable to control fluid flow into the completion string of a well system, for example, to balance inflow of fluids along the length of the well. For instance, some horizontal wells have issues with the heel-toe effect, where gas or water cones in the heel of the well and causes a difference in fluid influx along the length of the well. The differences in fluid influx can lead to premature gas or water break through, significantly reducing the production from the reservoir. Inflow control devices (ICD) can be positioned in the completion string at heel of the well to stimulate inflow at the toe and balance fluid inflow along the length of the well. In another example, different zones of the formation accessed by the well can produce at different rates. ICDs can be placed in the completion string to reduce production from high producing zones, and thus stimulate production from low or non-producing zones. Finally, ICDs can be used in other circumstances to balance or otherwise control fluid inflow. 
       SUMMARY 
       [0003]    In one general implementation, a wellbore flow control apparatus includes a plurality of inflow control assemblies engageable with a pipe joint that includes a proximal end engageable with a first downhole tool and a distal end engageable with a second downhole tool; and at least one inflow control device (ICD) mounted in each of the plurality of inflow control assemblies, each of the inflow control devices including an inlet adapted to receive a flow of a wellbore fluid at a flow velocity that is less than a transport velocity of fines in the wellbore fluid, and an outlet adapted to transmit a flow of the wellbore fluid to the pipe joint. 
         [0004]    In a first aspect combinable with the general implementation, each of the plurality of inflow control assemblies includes a housing engageable with the pipe joint, the at least one ICD mounted at least partially within the housing. 
         [0005]    In a second aspect combinable with any of the previous aspects, the housing is threadingly engageable with one of the proximal or distal ends of the pipe joint. 
         [0006]    In a third aspect combinable with any of the previous aspects, at least one of the plurality of inflow control assemblies includes an end inflow control assembly. 
         [0007]    In a fourth aspect combinable with any of the previous aspects, the end inflow control assembly includes a wellbore fluid inlet positioned on only one axial surface of the end inflow control assembly. 
         [0008]    In a fifth aspect combinable with any of the previous aspects, at least one of the plurality of inflow control assemblies includes a middle inflow control assembly engageable with the pipe joint between the end inflow control assembly and one of the proximal or distal ends of the pipe joint. 
         [0009]    In a sixth aspect combinable with any of the previous aspects, the middle inflow control assembly includes wellbore fluid inlets positioned on respective axial surfaces of the middle inflow control assembly. 
         [0010]    In a seventh aspect combinable with any of the previous aspects, the middle inflow control assembly includes another wellbore fluid inlet positioned on a radial surface of the middle inflow control assembly. 
         [0011]    An eighth aspect combinable with any of the previous aspects further includes a filter that extends between the end inflow control assembly and another end flow control assembly such that a radial gap is defined between an outer surface of the pipe joint and the filter. 
         [0012]    In a ninth aspect combinable with any of the previous aspects, the middle inflow control assembly is engageable with the pipe joint in the gap and between the filter and the outer surface of the pipe joint. 
         [0013]    In a tenth aspect combinable with any of the previous aspects, the middle inflow control assembly is engageable with the pipe joint and the screen and is positioned in the gap with an outer radial surface of the middle inflow control assembly spaced apart from the outer surface of the pipe joint an equidistant as the filter. 
         [0014]    In an eleventh aspect combinable with any of the previous aspects, a porosity of the filter is selected so that fines in the wellbore fluid flow through the filter with the wellbore fluid. 
         [0015]    In a twelfth aspect combinable with any of the previous aspects, the filter includes at least one of a wire wrap, a mesh screen, a slotted liner, a perforated shroud, or a prepack screen. 
         [0016]    In a thirteenth aspect combinable with any of the previous aspects, the housing includes a filter that extends to enclose at least a portion of the ICD. 
         [0017]    In a fourteenth aspect combinable with any of the previous aspects, the filter extends to enclose the plurality of ICDs. 
         [0018]    In a fifteenth aspect combinable with any of the previous aspects, the filter includes a plurality of filter sections, each filter section enclosing at least a portion of one of the plurality of ICDs. 
         [0019]    A sixteenth aspect combinable with any of the previous aspects further includes a divider positioned in a gap between adjacent filter sections. 
         [0020]    In a seventeenth aspect combinable with any of the previous aspects, the divider includes swell rubber. 
         [0021]    In an eighteenth aspect combinable with any of the previous aspects, each of the ICDs includes at least one of a nozzle, an orifice, a helix channel, one or more tubulars, or an autonomous ICD. 
         [0022]    In another general implementation, a method for controlling flow of a wellbore fluid includes positioning a plurality of inflow control assemblies on a pipe joint in a wellbore, the pipe joint including a proximal end engageable with a first downhole tool and a distal end engageable with a second downhole tool; receiving a flow of a wellbore fluid from a subterranean zone to an inlet of at least one inflow control device (ICD), the at least one ICD mounted in each of the plurality of inflow control assemblies, the flow at a velocity that is less than the transport velocity of fines in the wellbore fluid; and transmitting the flow of the wellbore fluid to the pipe joint from the ICDs to an interior of the pipe joint. 
         [0023]    A first aspect combinable with the general implementation further includes receiving the flow of the wellbore fluid at a housing that at least partially encloses the ICD; and distributing the flow of the wellbore fluid through a portion of the housing to the ICD. 
         [0024]    In a second aspect combinable with any of the previous aspects, distributing the flow of the wellbore fluid through a portion of the housing to the ICD includes distributing the flow of the wellbore fluid through one or more axially-facing inlets of the housing. 
         [0025]    In a third aspect combinable with any of the previous aspects, distributing the flow of the wellbore fluid through a portion of the housing to the ICD further includes distributing the flow of the wellbore fluid through a radially-facing inlet of the housing. 
         [0026]    A fourth aspect combinable with any of the previous aspects further includes receiving the flow of the wellbore fluid through a filter that extends at least partially between the proximal and distal ends of the pipe joint and into a radial gap defined between an outer surface of the pipe joint and the filter. 
         [0027]    In a fifth aspect combinable with any of the previous aspects, receiving the flow of the wellbore fluid through a filter includes receiving fines in the flow of the wellbore fluid through the filter; and circulating the fines in the flow of the wellbore fluid to the inlet of the at least one ICD. 
         [0028]    A sixth aspect combinable with any of the previous aspects further includes receiving the flow of the wellbore fluid through a filter that extends to enclose at least a portion of the ICD. 
         [0029]    In a seventh aspect combinable with any of the previous aspects, the filter extends to enclose the plurality of ICDs. 
         [0030]    In an eighth aspect combinable with any of the previous aspects, the filter includes a plurality of filter sections, each filter section enclosing at least a portion of one of the plurality of ICDs. 
         [0031]    In a ninth aspect combinable with any of the previous aspects, receiving a flow of a wellbore fluid at a velocity that is less than the transport velocity of fines in the wellbore fluid includes restricting a flow rate of the wellbore fluid entering the at least one ICD based on a property of the wellbore fluid; and modifying a velocity of the flow of the wellbore fluid to be less than the transport velocity of fines in the wellbore fluid based on the restriction. 
         [0032]    In a tenth aspect combinable with any of the previous aspects, the wellbore fluid includes a hydrocarbon fluid and an aqueous fluid. 
         [0033]    In an eleventh aspect combinable with any of the previous aspects, restricting a flow rate of the wellbore fluid entering the at least one ICD based on a property of the wellbore fluid includes restricting a flow rate of the wellbore fluid entering the at least one ICD based on a difference in a property of the hydrocarbon fluid and a property of the aqueous fluid. 
         [0034]    In a twelfth aspect combinable with any of the previous aspects, the property includes a viscosity, a velocity, or a density of the wellbore fluid. 
         [0035]    In a thirteenth aspect combinable with any of the previous aspects, restricting a flow rate of the wellbore fluid entering the at least one ICD based on a difference in a property of the hydrocarbon fluid and a property of the aqueous fluid includes flowing the hydrocarbon fluid through a first passage of the at least one ICD; flowing the aqueous fluid through a second passage of the at least one ICD that is different than the first passage; and flowing the hydrocarbon fluid and the aqueous fluid together from the first and second passages based at least in part on the difference in the property of the hydrocarbon fluid and the property of the aqueous fluid. 
         [0036]    In another general implementation, a wellbore flow control system includes a pipe joint including a tubular that extends between threaded ends; and a plurality of flow control apparatus fixed to the tubular between the threaded ends, each of the flow control apparatus including means for receiving a flow of a wellbore fluid into the flow control apparatus at a flow velocity less than a transport velocity of particulates in the wellbore fluid and transmitting the flow of the wellbore fluid to a volume defined by the tubular. 
         [0037]    A first aspect combinable with the general implementation further includes means for filtering the flow of wellbore fluid that encloses at least a portion of the plurality of flow control apparatus. 
         [0038]    In a second aspect combinable with any of the previous aspects, the means for filtering includes a specified porosity that includes apertures larger than a majority of the particulates. 
         [0039]    In a third aspect combinable with any of the previous aspects, the means for receiving the flow of the wellbore fluid is fluidly coupled to an interior of the tubular that includes the volume. 
         [0040]    Various implementations of a system for controlling flow in a wellbore may include none, one, some, or all of the following features. For example, the system for controlling flow in a wellbore may resist (e.g., all or in part) plugging (e.g., by particulates from a subterranean zone) in an unconsolidated geological formation. As another example, production of sands, fines, and other particulates to a terranean surface within a wellbore fluid may be minimized or eliminated. As another example, conventional filtering techniques to reduce or help reduce production of such particulates may be minimized (e.g., by using screens of larger porosity) thereby minimizing installation and/or production costs. As yet another example, “hot spots” of high wellbore fluid flow rates through production equipment may be eliminated or minimized, thereby reducing erosion on such equipment due to production of sand or fines or other particulates in the wellbore fluid. As yet another example, flow rates through production (or injection) equipment may be more uniform (e.g., along a length or lengths of production tubing) as compared to conventional techniques 
         [0041]    The details of one or more implementations are set forth in the accompanying drawings and the description below. Other features, objects, and advantages will be apparent from the description and drawings, and from the claims. 
     
    
     
       DESCRIPTION OF DRAWINGS 
         [0042]      FIG. 1  is a schematic diagram that illustrate a well system that includes one or more inflow control assemblies; 
           [0043]      FIGS. 2A-2B  are schematic diagrams that illustrate example implementations of flow control systems; 
           [0044]      FIG. 3  is a schematic diagram that illustrates another example implementation of a flow control system; 
           [0045]      FIGS. 4A-4C  are schematic diagrams that illustrate example implementations of inflow control devices that may be used with a flow control system; and 
           [0046]      FIGS. 5A-5C  are schematic diagrams that illustrate further example implementations of flow control systems. 
       
    
    
     DETAILED DESCRIPTION 
       [0047]    According to the present disclosure, a flow control system includes one or more flow control apparatus positioned on a base pipe and in fluid communication with an interior volume of the base pipe. Each flow control apparatus includes one or more ICDs that adjust a flow of a wellbore fluid received at the flow control apparatus from a subterranean zone so that a velocity of the flow of the wellbore fluid provided to the interior volume is less than a transport velocity of sands or fines in the wellbore fluid. 
         [0048]    Various implementations of the concepts disclosed herein may be utilized in various orientations and in various configurations. Example orientations include inclined, inverted, horizontal, vertical, and others. The concepts of this patent application are not limited to any of the example implementations disclosed herein. 
         [0049]    Directional terms are used to describe the example implementations. Example directional terms include “above,” “below,” “upper,” “lower,” and others. The terms “above,” “upper,” and “upward” may refer to a direction toward the earth&#39;s surface along a wellbore. The terms “below,” “lower,” and “downward” may refer to a direction away from the earth&#39;s surface along a wellbore. 
         [0050]      FIG. 1  is a schematic diagram that illustrate a well system  10  that includes one or more inflow control assemblies  16 . As illustrated, the well system  10  includes a completion string  12  installed in a wellbore  14  of a well, thereby defining an annulus  20  between the wellbore  14  and the string  12 . The completion string  12  includes multiple inflow control assemblies  16  positioned in an uncased generally horizontal portion of the wellbore  14 . Generally, the completion string  12  is an assembly of equipment that includes a tubular conduit and extends through all or a portion of the wellbore  14 . The completion string  12  may be separate from or anchored to a casing of the wellbore  14 . The completion string  12  is permanently or semi-permanently installed in the wellbore  14 , and is the primary equipment used to produce the well over its expected life. 
         [0051]    The packers  18  seal or substantially seal against passage of fluids between a wall of the wellbore  14  and the completion string  12 , and thus isolate portions of the wellbore  14  from other portions of the wellbore  14 . As illustrated, one or more of the inflow control assemblies  16  may be positioned in an isolated portion of the wellbore  14 , for example, between packers  18  set in the wellbore. In addition, or alternatively, many of the inflow control assemblies  16  could be positioned in a long, continuous portion of the wellbore  14 , without packers isolating the wellbore between the screens. 
         [0052]    Gravel packs could be provided about any or all of the inflow control assemblies  16 , if desired. A variety of additional well equipment (such as valves, sensors, pumps, control and actuation devices, etc.) could also be provided in the well system  10 . 
         [0053]    The well system  10  is merely representative of one well system in which the principles of the present disclosure may be beneficially utilized. However, the invention is not limited in any manner to the details of the well system  10  described herein. For example, the inflow control assemblies  16  could instead be positioned in a cased and perforated portion of a wellbore, the inflow control assemblies  16  could be positioned in a generally vertical portion of a wellbore, the inflow control assemblies  16  could be used in an injection well, rather than in a production well. For example, although shown in the context of a horizontal well system  10 , the concepts herein can be applied to other well configurations, including vertical well systems consisting of a vertical or substantial vertical wellbore, multi-lateral well systems having multiple wellbores deviating from a common wellbore and/or other well systems. Also, although described in a production context, concepts herein can are applicable in other contexts, including injection (e.g., with the inflow control assemblies  16  as part of an injection string), well treatment (e.g., with the inflow control assemblies  16  as part of a treatment string) and/or other applications. 
         [0054]    In one alternative example, the string  12  can be used to inject stimulating fluids (e.g., acid in an acidizing treatment, steam in a heated fluid injection treatment, and/or other types of stimulating fluid) into a subterranean zone that surrounds the wellbore  14  (e.g., a horizontal portion of the wellbore  14 ). Thereafter, the string  12  can be used to produce fluids (e.g., hydrocarbons and/or other fluids) from the subterranean zone substantially uniformly, or in some other flow profile, along the length of the production/injection interval. In another example, the string  12  is used for injection of sweeping fluids (e.g., water, brine and/or other fluids) into the subterranean zone substantially uniformly, or in some other flow profile, along the length of the production/injection interval for the purpose of maintaining pressure in the subterranean zone and sweeping the zone&#39;s fluids to a specified location in the subterranean zone. The well may be shut-in while the sweeping fluids reside in the subterranean zone. In certain instances, the greater resistance or sealing against inflow into the string  12  can limit cross-flow of fluids from one sub-interval, through the string  12  and out to another sub-interval. Thereafter, the string  12  is used to produce fluids (e.g., hydrocarbons and/or other fluids) from the subterranean zone substantially uniformly, or in some other flow profile, along the length of the production/injection interval. 
         [0055]    During the production of fluids from the subterranean zone, each of the illustrated flow control apparatus  16  may receive a wellbore fluid (e.g., a gas or liquid or multiphase hydrocarbon fluid) from the subterranean zone that is produced into the annulus  20 . Once received from the annulus  20 , the flow control apparatus  16  may transmit the wellbore fluid to an interior of the completion string  12 , such as to an interior of a tubular joint, or “pipe joint,” that makes up the completion string  12 . In other example embodiments, the flow control apparatus  16  may transmit the wellbore fluid to an interior of a coiled tubing that makes up the completion string  12 . Wellbore fluid produced into the completion string  12  may be further produced to the terranean surface. 
         [0056]    As described in more detail below, each of the flow control apparatus  16  may include one or more inflow control devices (“ICDs”) that adjust a flow rate and/or flow velocity of the wellbore fluid received into the flow control apparatus  16  from the annulus  20 . Examples of ICDs can include, for instance, nozzle type ICDs, orifice-type ICDs, helix channel ICDs, valves, tubings, and autonomous ICDs (e.g., microfluidic or vortex type ICDs). As further examples, ICDs may include flow channels that direct and/or adjust a flow of the wellbore fluid as it is distributed through the flow control apparatus  16 . ICDs may include vanes mounted in flow paths that direct and/or adjust a flow of the wellbore fluid as it is distributed through the flow control apparatus  16 . ICDs may include posts or other textured surfaces that direct and/or adjust a flow of the wellbore fluid as it is distributed through the flow control apparatus  16 . 
         [0057]    In example implementations, the ICDs are autonomous ICDs (“AICDs”). AICDs may include an autonomous valve that autonomously (i.e., without human or other interaction) changes between allowing and restricting against flow to the completion string  12  from the annulus  20  in response to a fluid flow characteristic, such as, at least one of fluid flow rate, viscosity or density. For example, an autonomous valve can become more restrictive of fluid flow as the flow rate increases and less restrictive as the flow rate decreases or vice versa. An autonomous valve can become more restrictive of fluid flow as the viscosity fluid increases and less restrictive of viscosity of the fluid decreases or vice versa. An autonomous valve can become more restrictive of fluid flow as the fluid density increases and less restrictive as the fluid density decreases or vice versa. In certain instances, an autonomous valve can automatically be more restrictive to water than oil or vice versa, more restrictive to gas than oil or vice versa, and/or more restrictive to production flow (e.g., flow from the wellbore  14  into the interior of the completion string  12 ) than to injection flow (e.g., flow from the interior of the completion string  12  into the wellbore  14 ) or vice versa. 
         [0058]    Several examples of autonomous valves that could be used as the autonomous valve are disclosed in U.S. patent Ser. No. 12/700,685, entitled “METHOD AND APPARATUS FOR AUTONOMOUS DOWNHOLE FLUID SELECTION WITH PATHWAY DEPENDENT RESISTANCE SYSTEM,” filed Feb. 4, 2010, the entirety of which is incorporated herein by reference. Still other examples exist. In some examples, autonomous valves (e.g., an AICD) include no moving parts. The autonomous valve includes multiple passages, each having a different resistance to flow in relation to a characteristic of the fluid flow. The passages include fluid diodes that provide resistance to flow based on the density, viscosity, and/or velocity of the fluid they receive. The multiple passages feed into a fluid amplifier and the flows from the passages act on each other to direct the total flow based on the respective momentum of flow from the passages. The amplifier increases the total fluid flow&#39;s tendency to flow towards one direction, and thus directs the flow to preferentially enter one or another of multiple outlets. The result is that the resistance to flow through the autonomous valve as a whole depends on the characteristics of the fluid flow, such as its density, viscosity and/or flow rate. 
         [0059]    Each flow control apparatus  16  has an exterior housing that, in some cases, is sealed to the completion string  12 . Wellbore fluid can be communicated from the annulus  20  to an interior of the housing and to the one or more ICDs. 
         [0060]      FIGS. 2A-2B  are schematic diagrams that illustrate example implementations of flow control systems  200  and  250 , respectively. Generally, at a high level, the flow control systems  200  and  250  each include multiple flow control apparatus that are mounted or coupled to a base pipe (e.g., a pipe joint of a tubing string such as completion string  12 ). Each of the multiple flow control apparatus includes one or more ICDs that receive a flow of a wellbore fluid from a subterranean formation and adjust the flow so that a velocity of the flow of the wellbore fluid to an interior of the base pipe is below (e.g., slightly or significantly) a transport velocity of fines (e.g., sand or other particulates) carried in the wellbore fluid. 
         [0061]    In some aspects, a transport velocity of fines may be determined based on a terminal settling velocity of the fines (e.g., sand or other particulates) in the wellbore fluid. The terminal velocity of the fines in a fluid at rest is determined according to the weight of the fines, the cross sectional area of the fines, the density of the fluid, and the drag coefficient. For example, the terminal velocity of a particle is determined according to the equation: 
         [0000]    
       
         
           
             
               
                 v 
                 t 
               
               = 
               
                 
                   
                     2 
                      
                     
                         
                     
                      
                     m 
                   
                   
                     
                       C 
                       d 
                     
                      
                     A 
                      
                     
                         
                     
                      
                     ρ 
                   
                 
               
             
             , 
           
         
       
     
         [0000]    where v t  is the terminal settling velocity, m is the mass of the particle, C d  is the drag coefficient, A is the cross-sectional area of the particle, and ρ is the fluid density. 
         [0062]    The transport velocity is related to the terminal settling velocity by a factor which can be, in some instances, about 10. Thus, the transport velocity of the particle (e.g., fines, sand, or otherwise) is about 10 times the determined terminal settling velocity. In some aspects, sand transport velocities, for example, can range from between about 0.001 m/s to 10 m/s and more optimally, between about 0.1 m/s and 0.6 m/s. Thus, the ICDs adjust the flow of a wellbore fluid that includes sand so that a velocity of the flow of the wellbore fluid to the interior of the base pipe is below between about 0.1 and 0.6 m/s in some aspects. 
         [0063]    As illustrated, the flow control system  200  includes inflow control assemblies  205  that receive a flow of a wellbore fluid  210  from the annulus  20  and transmit the wellbore fluid  217  through conduits  215  to an interior  220  of a base pipe  212 . In some aspects, the base pipe  212  is a single pipe joint that is can be coupled (e.g., threadingly) to additional pipe joints on both ends of the base pipe  212  or other downhole tools. For example, in some aspects the base pipe  212  is one of a Range 1 (e.g., between about 16-25 ft.), Range 2 (e.g., between about 25-34 ft.), or Range 3 pipe joint. In the case of a Range 3 pipe joint, the base pipe  212  may be threaded on both ends and be 34-48 ft. or about 40 ft. long. 
         [0064]    In the case of the base pipe  212  comprising a single pipe joint, the conduits  215  may be apertures formed in the pipe  212  and, in some cases, multiple apertures from an exterior of the pipe  212  to the interior  220  may be formed around the circumference of the base pipe  212 . In other cases, the base pipe  212  may include all or portions of several pipe joints that are coupled together (e.g., threadingly or otherwise). For example, in such implementations, a particular flow control apparatus  205  may act as a coupling between two pipe joints of the base pipe  212  in that the apparatus  205  may be coupled (e.g., threadingly) to an end of two adjacent pipe joints, thereby forming a coupling between the pipe joints. In such aspects, the conduit  215  may simply be a gap between the ends of the pipe joints that form the base pipe  212 . 
         [0065]    As illustrated in  FIG. 2A , flow of the wellbore fluid  210  may enter the multiple flow control apparatus  205  through one or multiple surfaces of the apparatus  205 . For example, in some aspects, the wellbore fluid  210  may enter only axially-facing surfaces (e.g., facing in an uphole and/or downhole direction in a vertical wellbore). In some aspects, the wellbore fluid  210  may enter only a radially-facing surface (e.g., facing the wellbore  14 ). In some aspects, the wellbore fluid  210  may enter axially-facing surfaces and radially-facing surfaces. 
         [0066]    Turning to  FIG. 2B , the flow control system  250  is illustrated, which includes multiple flow control apparatus  280 ,  285 , and  290  positioned on a base pipe  255  that is coupled to another base pipe (or other base pipes) through a connection  260  (e.g., a threaded connection). The system  250 , as illustrated, also includes a filter  275  (e.g., screen, mesh, perforated shroud, prepack screen, or otherwise) that extends between an end housing  270  and an end flow control apparatus  290 . The filter  275 , in some aspects, may be sized (e.g., have a porosity) to prevent particular size particles (e.g., larger than fines or sand) from traversing the filter  275  while allowing smaller particles (e.g., fines or sand or otherwise) from traversing the filter  275  in the wellbore fluid  210 . 
         [0067]    In some example implementations, the flow control system  250  (and other flow control systems described herein) may not include the filter  275 . For example, because a flow velocity of the wellbore fluid  210  that enters one or more ICDs in each flow control apparatus  280 ,  285 , and/or  290  is below a transport velocity for fines and/or sand in the fluid  210 , a filter may be unnecessary to prevent and/or limit the production of such particles in the wellbore fluid  217  (as well as clogging and other problems). The sand and/or fines would not be transported into the ICDs in such example implementations. In some example aspects, however, the filter  275  may not be configured to prevent and/or limit the passage of sand and/or fines but instead, be configured to, for example, withstand a wellbore collapse or to hold a gravel pack in place to support the wellbore. In some aspects, such a filter  275  may include a screen that uses a relatively larger gauge that, in conventional systems, allows fines and/or sands to pass through. But, in accordance with the present disclosure, the filter  275  may not be exposed to sands and/or fines as the flow velocity through such a filter may be less than the transport velocity of sand and/or fines. 
         [0068]    In further implementations, the filter  275  may screen or filter fines and/or sand but in much less of a quantity due to the lower flow velocity of the wellbore fluid  210 . The filter  275 , therefore, may never or rarely experience plugging or other maintenance issues. 
         [0069]    As illustrated, the end housing  270  is mounted on or coupled to the base pipe  255  at, for example, an uphole end and may not, in this example, receive a flow of the wellbore fluid  210 . The end housing  270 , as shown, may simply provide an end connection for the filter  275 . At the other end of the filter  275 , the end flow control apparatus  290  provides a second connection for the filter  275  and also receives a flow of the wellbore fluid  210  that is transmitted through an ICD to a conduit  295  and exits out as wellbore fluid  217  to the interior  220  of the base pipe  255 . As illustrated, the end flow control apparatus  290  may only receive the wellbore fluid  210  at a axially-facing surface. 
         [0070]    Inflow control apparatus  280  and  285  are positioned, in this example, between the end housing  270  and the end flow control apparatus  290 . In this example, the flow control apparatus  280  is positioned on the base pipe  255  underneath the filter  275 , thereby allowing, in some aspects, the wellbore fluid  210  to flow into axially-facing and radially-facing surfaces of the apparatus  280 . Further, in this example, the flow control apparatus  285  is positioned and sized (e.g., a housing of the apparatus) to intersect the filter  275 . The flow control apparatus  285 , therefore, in this example, may receive the wellbore fluid  210  into axially-facing surfaces of the apparatus  285 . 
         [0071]    As with the system  200 , each of the flow control apparatus of system  250  (e.g., apparatus  280 ,  285 , and/or  290 ) includes one or more ICDs that receive the wellbore fluid  210  from the annulus and adjust the flow so that the velocity of the flow of the wellbore fluid  210  to the ICDs in the housings  280 ,  285 , and  290  is below (e.g., slightly or significantly) a transport velocity of fines (e.g., sand or other particulates) carried in the wellbore fluid  210 . In this example, the combination of the end housing  270 , inflow control devices  280 ,  285 , and  290 , and base pipe  255  comprise an inflow control assembly  265 . In some instances, the filter  275  is also part of the inflow control assembly  265 . Further, other implementations of system  250  exist. For example, the system  250  may include more flow control apparatus, may only include one or more flow control apparatus  280  or  285 , may include two end flow control apparatus  290 , or may include multiple pipe joints (e.g., multiple base pipes  255  coupled through connections  260 ). 
         [0072]    In operation, systems  200  and  250  can each be positioned in the wellbore  14  (e.g., in a horizontal portion, a vertical portion, a leg, or otherwise). Wellbore fluid  210  flows from the wellbore  14  into the annulus (e.g., from an open hole completion, from a perforated casing, or otherwise). The fluid  210  flows into the illustrated flow control apparatus (and in some cases through the filter  275  first) and into one or more ICDs positioned in each flow control apparatus. The wellbore fluid  210  flows into the flow control apparatus at a velocity that is less than or significantly less than the transport velocity of the fines or sand and thus, such particulates are not carried along in the fluid  210 . The ICDs in the flow control apparatus regulate the flow of the fluid  210  into the housings. The flow  217  exiting the ICDs (e.g., through the conduits  295  and into the interior  220  of the base pipe  255 ) is above the transport velocity of the sands or fines. The wellbore fluid  217  that enters the interior  220  of the base pipe  255  can be produced to the surface, largely free from (or with a reduced amount of) sand or fines 
         [0073]    In some cases, a particular number or type (e.g., end flow control apparatus  290  and/or flow control apparatus  280  or  285 ) may be selected based on production criteria. For example, criteria such as desired flow profile, desired flow rate, formation characteristics, and otherwise may determine the number, as well as the type, of flow control apparatus in the inflow control assembly  265 . 
         [0074]      FIG. 3  is a schematic diagram that illustrates another example implementation of a flow control system  300 . In this example, a flow control apparatus  305  is used as a coupling to connect (e.g., threadingly) ends  325  of two base pipes  314  that are part of a completion string in a wellbore  14 . Further, in this example, filters  310  abut (or are adjacent to) axial sides of the flow control apparatus  305  and comprise wrap on pipe screens. 
         [0075]    For example, in this implementation, the filters  310  are depicted as a wire wrapped screen, having a wire helically wrapped around the base pipe  314 . The space between adjacent wraps of the wire is closely controlled to be smaller than a specified size of particulate filtered by the filters  310 . For example, in some aspects, the filters  310  may be designed to prevent particulates larger than fines or sand from passing through while allowing fines and sands to pass through (thereby decreasing the cost and complexity of the filters  310 ). Although depicted as a wire wrapped screen, other configurations of screens, including screens having one or more layers of wire wrap, mesh and/or other filtration structures, could be used. 
         [0076]    In operation, wellbore fluid  210  passes through the filters  310  radially and enters the flow control apparatus  305  axially, then flows though the radially-facing openings in a housing of the apparatus  305 . The fluid  210  enters an ICD  330  at a particular flow rate and flow velocity. The wellbore fluid  310  passes through the ICD  330  (e.g., a nozzle, orifice, helix channel, tubing, AICD, or otherwise) and into the interior  320  of the base pipe  314  to be produced to the surface. In some aspects, the ICD  330  adjusts the velocity and/or rate of the wellbore fluid  210  so that, as the fluid  217  enters the interior  320  of the base pipe  314 , the velocity of the fluid  217  is below a transport velocity of sands or fines in the wellbore fluid  210 . Alternatively, the flow  210  of the wellbore fluid that enters the ICD  330  is below a transport velocity of sands or fines in the wellbore fluid  210  and the flow  217  into the interior  320  of the base pipe  314  may be above or below the transport velocity of sands or fines in the wellbore fluid  210 . In any event, such flow  217  into the interior may be all or largely free of sand and/or fines. 
         [0077]      FIGS. 4A-4C  are schematic diagrams that illustrate example implementations of inflow control devices  400 ,  420 , and  450 , respectively, that may be used with a flow control system (e.g., flow control systems  200 ,  250 ,  300 , or otherwise). More particularly, one or more of the ICDs  400 ,  420 , and/or  450  can be used in any one of the illustrated flow control apparatus. Other ICDs are also contemplated by the present disclosure beyond these examples illustrated here. Each of the illustrated ICDs can, at a high level, receive a flow of a wellbore fluid from a subterranean formation at a velocity below the transport fine velocity by adjusting the flow so that a velocity is below (e.g., slightly or significantly) a transport velocity of fines (e.g., sand or other particulates) carried in the wellbore fluid. 
         [0078]    Turning to  FIG. 4A , the ICD  400  includes flow paths  405  that extend (e.g., from a surface of a flow control apparatus exposed to an annulus of a wellbore) to the base pipe  414  that includes multiple apertures  415 . The apertures  415  extend from an outer surface of the base pipe  414  to an interior of the base pipe  414 . The flow paths  405  include vanes  410  that are positioned in and extend from the flow paths  405 . Although a single vane  410  is illustrated in each flow path  405 , multiple vanes  410  may be positioned per flow path  405  or some flow paths  405  may not include any vanes  410 . 
         [0079]    In operation, wellbore fluid  210  flows (e.g., from an annulus through a housing of a flow control apparatus) into the ICD  400  and into the flow paths  410 . The wellbore fluid  210  enters the ICD  400  at a particular flow rate and velocity that is less than a transport velocity of sands or fines in the fluid  210 . Thus, sands and/or fines in the fluid  210  are not transported through the flow to and, in some cases, into, the ICD  400 . Based on the flow paths  405  and vanes  410  (alone or in combination), the velocity of the wellbore fluid  210  is reduced in the ICD  400  to a rate less than the transport velocity of sands or fines contained in the fluid  210 . Thus, the fluid  210  entering the apertures  415  may be substantially free of, or have a reduced amount of, fines and sands. 
         [0080]    Turning to  FIG. 4B , the ICD  420  includes flow paths  425  that extend (e.g., from a surface of a flow control apparatus exposed to an annulus of a wellbore) to the base pipe  414  that includes multiple apertures  430 . The apertures  430  extend from an outer surface of the base pipe  414  to an interior of the base pipe  414 . The flow paths  425  are illustrated in this example as extending relatively straight to the base pipe  414 , however, in alternative implementations, the flow paths  430  (e.g., grooves formed in a surface of the ICD  420 ) may be zig-zag, curved, circuitous, or otherwise. 
         [0081]    In operation, wellbore fluid  210  flows (e.g., from an annulus through a housing of a flow control apparatus) into the ICD  420  and into the flow paths  430 . The wellbore fluid  210  enters the ICD  420  at a particular flow rate and velocity that is less than a transport velocity of sands or fines in the fluid  210 . Thus, sands and/or fines in the fluid  210  are not transported through the flow to and, in some cases, into, the ICD  420 . Based on the flow paths  430 , the velocity of the wellbore fluid  210  is reduced in the ICD  420  to a rate less than the transport velocity of sands or fines contained in the fluid  210 . Thus, the fluid  210  entering the apertures  430  may be substantially free of, or have a reduced amount of, fines and. 
         [0082]    Turning to  FIG. 4C , the ICD  450  includes a surface onto which multiple posts  455  or other raised flow obstructions are mounted. The surface extends to the base pipe  414  that includes multiple apertures  460 . The apertures  460  extend from an outer surface of the base pipe  414  to an interior of the base pipe  414 . As illustrated, multiple posts  455  are positioned on the flow surfaces and can be placed in an ordered pattern, semi-random pattern, or random pattern. 
         [0083]    In operation, wellbore fluid  210  flows (e.g., from an annulus through a housing of a flow control apparatus) into the ICD  450  and onto the flow surfaces onto which the posts  455  are mounted. The wellbore fluid  210  enters the ICD  450  at a particular flow rate and velocity that is less than a transport velocity of sands or fines in the fluid  210 . Thus, sands and/or fines in the fluid  210  are not transported through the flow to and, in some cases, into, the ICD  450 . Based on the posts  455  that present flow obstructions to the wellbore fluid  210 , the velocity of the wellbore fluid  210  is reduced in the ICD  450  to a rate less than the transport velocity of sands or fines contained in the fluid  210 . Thus, the fluid  210  entering the apertures  460  may be substantially free of, or have a reduced amount of, fines and. 
         [0084]      FIGS. 5A-5C  are schematic diagrams that illustrate further example implementations of flow control systems  500 ,  520 , and  550 , respectively. Generally, one or more of the flow control systems  500 ,  520 , and/or  550  may be used in the well system  10  in conjunction with, or in place of, one or more of the flow control systems  200 ,  250 , and/or  300 . Generally, each of the flow control systems  500 ,  520 , and  550  include one or more flow control apparatus mounted on or coupled to a base pipe with a filter that extends over at least a portion of the flow control apparatus. Each of the flow control apparatus includes one or more ICDs that receive a flow of wellbore fluid from an annulus of a wellbore and adjust the flow so that the velocity of the flow of the wellbore fluid to an interior of a base pipe is below (e.g., slightly or significantly) a transport velocity of fines (e.g., sand or other particulates) carried in the wellbore fluid. 
         [0085]    Turning particularly to  FIG. 5A , the flow control system  500  includes multiple flow control apparatus  505  mounted on or coupled to a base pipe (e.g., completion string  212 ). In this example, each flow control apparatus is enclosed (e.g., substantially) by a filter (e.g., screen, mesh, or otherwise) and also includes one or more ICDs (e.g., enclosed within the filter) that receives a wellbore fluid  210  from the annulus  20  and provides an adjusted flow of the wellbore fluid  217  to an interior of the completion string  212 . The ICDs enclosed within the filters in the flow control apparatus  505  may be, for instance, nozzles, valves, AICDs, or otherwise. 
         [0086]    In operation, flow of the fluid  210  is received through the filters of the flow control apparatus  505  and to the ICDs enclosed within the filters. The ICDs, in some aspects, may be set (e.g., according to a number of flow control apparatus  505  on each base pipe joint, according to a type of ICDs used in the flow control apparatus  505 , or otherwise) to provide a maximum velocity of the wellbore fluid  210  to the completion string  212 , so as to more uniformly distribute flow from the annulus  20  to the completion string  212 . In some aspects, the maximum velocity may be set so as to avoid “hot spots” of high flow of the wellbore fluid  210  to the completion string  212 . In some aspects, the maximum velocity may allow for the transport of sands or fines in the wellbore fluid  210  into the completion string  212  but at rates in which a flow distribution among the flow control apparatus is uniform, constant, and/or substantially equal. In some aspects, the maximum velocity may be lower than a transport velocity of sands or fines in the wellbore fluid  210 . 
         [0087]    Turning now to  FIG. 5B , the flow control system  520  includes multiple flow control apparatus  505  mounted on or coupled to a base pipe (e.g., completion string  212 ). In this example, each flow control apparatus is enclosed (e.g., substantially) by a filter (e.g., screen, mesh, or otherwise) and also includes one or more ICDs (e.g., enclosed within the filter) that receives a wellbore fluid  210  from the annulus  20  and provides an adjusted flow of the wellbore fluid  210  to an interior of the completion string  212 . The ICDs enclosed within the filters in the flow control apparatus  505  may be, for instance, nozzles, valves, AICDs, or otherwise. Further, in this example, swell rubber  510  is positioned between adjacent flow control apparatus  505 , thereby sealing sections of flow into the flow control apparatus of the wellbore fluid  210 . In some aspects, the system  520  may operate substantially similar to the system  500  but flow into axially-facing surfaces of the flow control apparatus  505  may be limited by the swell rubber  510 . 
         [0088]    Turning now to  FIG. 5C , the flow control system  550  includes a single flow control apparatus  555  mounted on or coupled to a base pipe (e.g., completion string  212 ). In this example, the flow control apparatus  555  is enclosed (e.g., substantially) by a filter (e.g., screen, mesh, or otherwise) and also includes one or more ICDs (e.g., enclosed within the filter) that receives a wellbore fluid  210  from the annulus  20  and provides an adjusted flow of the wellbore fluid  217  to an interior of the completion string  212 . The ICDs enclosed within the filters in the flow control apparatus  555  may be, for instance, nozzles, valves, AICDs, or otherwise. In some aspects, the system  550  may operate substantially similar to the systems  500  and/or  520  but a single filter limits particulates (e.g., sand or fines) from reaching the ICDs positioned in the flow control apparatus  555 . 
         [0089]    A number implementations have been described. Nevertheless, it will be understood that various modifications may be made without departing from the spirit and scope of the disclosure. Accordingly, other implementations are within the scope of the following claims.

Summary:
Techniques for controlling flow of a wellbore fluid include positioning a plurality of inflow control assemblies on a pipe joint in a wellbore, the pipe joint including a proximal end engageable with a first downhole tool and a distal end engageable with a second downhole tool; receiving a flow of a wellbore fluid from a subterranean zone to an inlet of at least one inflow control device (ICD), the at least one ICD mounted in each of the plurality of inflow control assemblies, the flow at a velocity that is less than the transport velocity of fines in the wellbore fluid; and transmitting the flow of the wellbore fluid to the pipe joint from the ICDs to an interior of the pipe joint.