Patent Publication Number: US-11028668-B2

Title: Reducing erosional peak velocity of fluid flow through sand screens

Description:
CROSS-REFERENCE TO RELATED APPLICATION 
     This application claims the benefit of U.S. Provisional Patent Application 62/700,018 filed Jul. 18, 2018, the entirety of which is incorporated by reference herein. 
    
    
     BACKGROUND 
     In the oil and gas industry, hydrocarbons can be produced from subterranean formations penetrated by a wellbore. Efficient control of the movement of unconsolidated formation particles into the wellbore, such as sand or other debris, has always been a pressing concern. Such formation movement commonly occurs during production from completions in loose sandstone or following hydraulic fracturing operations. Formation movement can also occur when a section of the wellbore collapses, which causes significant amounts of particulates and fines to circulate into the adjacent wellbore. Drawing formation particles into wellbore production equipment can cause numerous problems, such as plugging production tubing and subsurface flowlines and the eventual erosion of flowlines, valves, downhole pumps, and fluid separation equipment at the surface. 
     To control the migration of formation particles into wellbore production equipment, sand control screen assemblies are often installed downhole across formations. A typical sand control screen assembly includes a screen made of wire or metal wrapped about a perforated base pipe. Sand control screen assemblies allow fluids to flow therethrough and into the base pipe but prevent the influx of particulate matter of a predetermined size and greater. 
     The effectiveness of a sand control screen assembly can be augmented, particularly in open-hole completions, by installing a gravel pack in the wellbore annulus surrounding the sand control screen assembly within the wellbore. If a gravel pack is not used, however, sand control screen assemblies may nonetheless be used and are commonly referred to as “stand-alone screens.” Stand-alone screens are exposed to the open wellbore annulus and are, therefore, more susceptible to erosion damage during well production. When a stand-alone screen is installed in a high-pressure, high-productivity formation having high permeability streaks, the sand screen can be particularly vulnerable to failure due to sand erosion. 
    
    
     
       BRIEF DESCRIPTION OF THE DRAWINGS 
       The following figures are included to illustrate certain aspects of the present disclosure, and should not be viewed as exclusive embodiments. The subject matter disclosed is capable of considerable modifications, alterations, combinations, and equivalents in form and function, without departing from the scope of this disclosure. 
         FIG. 1  is an example well system that may employ one or more principles of the present disclosure. 
         FIG. 2  is a cross-sectional side view of a sand control screen assembly. 
         FIG. 3  is a cross-sectional side view of an example sand control screen assembly in accordance with one or more embodiments of the present disclosure. 
         FIG. 4  is a plot comparing fluid flow through a conventional sand control screen assembly with fluid flow through a sand control screen assembly according to the principles of the present disclosure. 
         FIG. 5  is a cross-sectional side view of a sand control screen assembly. 
         FIG. 6  is a cross-sectional side view of an example sand control screen assembly in accordance with one or more embodiments of the present disclosure. 
         FIG. 7  is another plot comparing fluid flow through a conventional sand control screen assembly with fluid flow through a sand control screen assembly according to the principles of the present disclosure. 
     
    
    
     DETAILED DESCRIPTION 
     The present disclosure relates to the field of well completions and downhole operations. More specifically, the present invention relates to a sand control device, and methods for conducting wellbore operations using a downhole fluid filtering device. 
     The ability of a sand screen to resist erosion due to particulates suspended in the fluid flowing therethrough is strongly linked to the velocity of the flow transporting the particles. The velocity of the flow, combined with the quantity of particles present in the stream, are the most relevant quantities when it comes to evaluating the life of sand screens and any reduction in either of the two will produce considerable gains in usable life of the screen. Due to the dynamics of fluid flow in a wellbore, a high velocity of entry through a sand screen is commonly experienced near areas where annular flow (i.e., flow along the wellbore in the annulus defined between the sand screen and the wellbore wall) is interrupted, such as at a wellbore isolation device (e.g., a wellbore packer). This high velocity greatly accelerates the erosion of the sand screen in this location and, if not mitigated, can reduce the risk of early failure of the sand screen. 
     The embodiments discussed herein describe methods of reducing erosional peak velocity of fluid flow through sand screens of a sand control screen assembly. The sand control screen assembly may be arranged in an open hole section of a wellbore and may include a base pipe defining a plurality of flow ports, a sand screen arranged about the base pipe, and a wellbore isolation device deployed within an annulus defined between the sand control screen assembly and an inner wall of the wellbore. A fluid from a surrounding subterranean formation may be circulated within the annulus, and the fluid within the annulus may be diverted through the sand screen and into the base pipe upon approaching the wellbore isolation device. A peak velocity of the fluid flowing through the sand screen may be reduced with a peak flux reducing assembly arranged axially adjacent the wellbore isolation device. 
       FIG. 1  is an example well system  100  that may employ one or more principles of the present disclosure, according to one or more embodiments. As depicted, the well system  100  includes a wellbore  102  that extends through various earth strata and has a substantially vertical section  104  extending to a substantially horizontal section  106 . The upper portion of the vertical section  104  may have a string of casing  108  or another type of wellbore liner cemented therein, and the horizontal section  106  may extend through a hydrocarbon-bearing subterranean formation  110 . In at least one embodiment, the horizontal section  106  may comprise an open hole section of the wellbore  102 . 
     A tubing string  112  may be positioned within the wellbore  102  and extend from the surface (not shown). In production operations, the tubing string  112  provides a conduit for fluids extracted from the formation  110  to travel to the surface. In injection operations, the tubing string  112  also provides a conduit for fluids introduced into the wellbore  102  at the surface to be injected into the formation  110 . At its lower end, the tubing string  112  may be coupled to a completion string  114  positionable within the horizontal section  106 . The completion string  114  may help divide the completion interval into various production intervals across the formation  110 . 
     As depicted, the completion string  114  may include a plurality of sand control screen assemblies  116  axially offset from each other along portions of the completion string  114 . Each sand control screen assembly  116  may be positioned between a pair of wellbore isolation devices  118  (alternately referred to as “packers” or “wellbore packing devices”) that provides a fluid seal between the completion string  114  and the inner wall of the wellbore  102 , thereby defining corresponding production intervals. In operation, the sand control screen assemblies  116  serve the primary function of filtering particulate matter out of the production fluid stream such that particulates and other fines are not produced to the surface via the tubing string  112 . 
     According to embodiments of the present disclosure, portions of the annulus  120  defined between the sand control screen assemblies  116  and the wall of the wellbore  102 , and longitudinally between adjacent wellbore isolation devices  118 , may remain open and otherwise not packed with gravel or sand (i.e., not gravel packed). Such portions of the wellbore  102  may be referred to as “open hole” portions, and the sand control screen assemblies  116  positioned in the open hole portions may be referred to as “stand alone screens.” 
     It should be noted that even though  FIG. 1  depicts a single sand control screen assembly  116  arranged in each production interval, it will be appreciated that any number of screen assemblies  116  may be deployed within a given production interval without departing from the scope of the disclosure. In addition, even though  FIG. 1  depicts multiple production intervals separated by the wellbore isolation devices  118 , it will be understood by those skilled in the art that the completion interval may include any number of production intervals with a corresponding number of wellbore isolation devices  118  arranged therein. 
     Moreover, while  FIG. 1  depicts the screen assemblies  116  as being arranged in the horizontal section  106  of the wellbore  102 , the screen assemblies  116  are equally well suited for use in wells having other directional configurations including vertical wells, deviated wellbores, slanted wells, multilateral wells, combinations thereof, and the like. The use of directional terms such as above, below, upper, lower, upward, downward, left, right, uphole, downhole and the like are used in relation to the illustrative embodiments as they are depicted in the figures, the upward direction being toward the top of the corresponding figure and the downward direction being toward the bottom of the corresponding figure, the uphole direction being toward the surface of the well and the downhole direction being toward the toe of the well. 
       FIG. 2  is a cross-sectional side view of a sand control screen assembly  200 . The sand control screen assembly  200  (hereafter “the screen assembly  200 ”) may be the same as or similar to any of the sand control screen assemblies  116  of  FIG. 1  and may, therefore, be used in the well system  100  depicted therein. The screen assembly  200  may be deployed and otherwise operated in an open hole section of the wellbore  102 , where the annulus  120  between the screen assembly  200  and the inner wall of the wellbore  200  is open and otherwise generally free of gravel and/or sand (i.e., not gravel packed). Consequently, the screen assembly  200  may be referred to or otherwise characterized as a “stand alone screen.” 
     As illustrated, the screen assembly  200  may include or otherwise be arranged about a base pipe  202  that defines one or more openings or flow ports  204  configured to provide fluid communication between an interior  206  of the base pipe  202  and the surrounding formation  110 . Accordingly, the base pipe  202  may be characterized as a “perforated” base pipe. The base pipe  202  may form part of the completion string  114  of  FIG. 1  and, in at least one embodiment, the screen assembly  200  may be arranged at the end of the completion string  114  and may otherwise comprise the last screen section at or near the toe of the wellbore  102 . 
     In some embodiments, the base pipe may comprise at least two tubular lengths, shown as a first base pipe portion  208   a  and a second base pipe portion  208   b  coupled to the first base pipe portion  208   a  at a pipe joint  210 . In the illustrated embodiment, the pipe joint  210  comprise a threaded box-and-pin connection, but may alternatively comprise any other type of tubing connection or connector. The base pipe  202  may be coupled to or form part of the tubing string  112  ( FIG. 1 ) and thereby be able to produce incoming fluids to a surface location for collection via the tubing string  112 . 
     In some embodiments, a wellbore isolation device  118  may be deployed within the annulus  120  at or near the pipe joint  210 . In at least one embodiment, the wellbore isolation device  118  may radially interpose the pipe joint  210  and the inner wall of the wellbore  102 , thereby providing a fluid seal between the base pipe  202  and the inner wall of the wellbore  102 . Moreover, the wellbore isolation device  118  may separate the annulus  120  into upper and lower sections or production intervals. 
     The screen assembly  200  may further include one or more sand screens arranged about the base pipe  202 , shown as a first or upper sand screen  212   a  and a second or lower sand screen  212   b . As illustrated, the first sand screen may be disposed about the first base pipe portion  208   a  and the second sand screen  212   b  may be disposed about the second base pipe portion  208   b . The first sand screen  212   a  may extend axially uphole from a first or upper housing  214   a  arranged about the first base pipe portion  208   a , and the second sand screen  212   b  may extend axially downhole from a second or lower housing  214   b  arranged about the second base pipe portion  208   b . The first and second housings  214   a,b  (alternately referred to as first and second “end rings”) provide a mechanical interface between the base pipe  202  and the corresponding first and second sand screens  212   a,b.    
     As illustrated, the sand screens  212   a,b  may each be radially offset a short distance from the outer radial surface of the first and second base pipe portions  208   a,b , respectively, and thereby define a production annulus  216  therebetween. The radial offset may result from one or more ribs (not shown) interposing the base pipe  202  and the screens  212   a,b  and extending longitudinally along the length of the first and second base pipe portions  208   a,b . A plurality of ribs may be angularly offset from each other about the circumference of the base pipe  202 , and the magnitude (depth) of the production annulus  216  may be dependent on the height of the ribs. 
     The sand screens  212   a,b  serve as a filter medium designed to allow fluids derived from the formation  110  to flow therethrough, but prevent the influx of particulate matter of a predetermined size and greater. In some embodiments, the sand screens  212   a,b  may be made from a plurality of layers of a wire mesh that are diffusion bonded or sintered together to form a fluid porous wire mesh screen. In other embodiments, however, the sand screens  212   a,b  may have multiple layers of a weave mesh wire material having a uniform pore structure and a controlled pore size that is determined based upon the properties of the formation  110 . For example, suitable weave mesh screens may include, but are not limited to, a plain Dutch weave, a twilled Dutch weave, a reverse Dutch weave, combinations thereof, or the like. In other embodiments, however, the sand screens  212   a,b  may include a single layer of wire mesh, multiple layers of wire mesh that are not bonded together, a single layer of wire wrap, multiple layers of wire wrap or the like, that may or may not operate with a drainage layer. Those skilled in the art will readily recognize that several other mesh designs are equally suitable, without departing from the scope of the disclosure. 
     In example operation, fluids  218  from the surrounding formation  110  may be drawn into the annulus  120  and circulated in the uphole direction (i.e., to the left in  FIG. 2 ) within the annulus  120  and the interior  206  of the base pipe  202 . The fluid  218  may access the interior  206  by passing through the screens  212   a,b , entering the production annulus  216 , and axially traversing the exterior of the base pipe  202  until locating and entering the flow ports  204 , which fluidly communicate with the interior  206  of the base pipe  202 . Particulate matter of a size greater than the screen gauge of the sand screens  212   a,b  may be prevented from passing into the production annulus  216  and thus into the interior  206  of the base pipe  202 . 
     Since the screen assembly  200  is positioned in an open hole annulus  120 , the fluid  218  will generally flow uphole in both the annulus  120  and the interior  206  of the base pipe  202 . When the fluid  218  flowing within the annulus  120  approaches the wellbore isolation device  118  (or any restriction in the annulus  120 ), however, the fluid  218  is forced to traverse the second screen  212   b  at or near the second housing  214   b  and subsequently enter the base pipe  202  via the flow ports  204  adjacent the second housing  214   b . Due to the dynamics of fluid flow, the fluid  218  from the annulus  120  is accelerated through the second screen  212   b  at peak velocity at or near the second housing  214   b , which can cause erosion of the screen  212   b  at this location. 
     Once bypassing the axial location of the wellbore isolation device  118  within the interior  206  of the base pipe  202 , the flow of the fluid  218  will naturally tend to spread out (split) again to reduce (minimize) friction and pressure. Accordingly, a portion of the fluid  218  flowing within the base pipe  202  may return to the annulus  120  by exiting the base pipe  202  and subsequently traversing the first screen  212   a  at or near the first housing  214   a . The fluid  218  exiting the base pipe  202  and traversing the first screen  212   a  may also be accelerated at peak velocity at or near the first housing  214   b . Due to the peak velocity of the fluid  218  traversing the screens  212   a,b  at their ends near the housings  214   a,b , localized fluid “hotspots” may develop and can result in erosional screen failure at these locations. 
     Embodiments of the present disclosure describe methods and systems of reducing the peak velocity of the fluid  218  entering and exiting the base pipe  202  and otherwise traversing the ends of the screens  212   a,b  at or near the housings  214   a,b . As described herein a peak flux reducing assembly may be arranged at or adjacent the wellbore isolation device  118  and operate to reduce a peak velocity of the fluid  218  traversing the sand screens  212   a,b  on either side of the wellbore isolation device  118  (e.g., before and/or after). In some embodiments, as described herein, the peak flux reducing assembly may urge the fluid  218  through the screens  212   a,b  at multiple locations and thereby generate multiple fluid hotspots that exhibit reduced fluid velocities as compared to a single fluid hotspot at an end of the sand screen  212   a,b . In other embodiments, the peak flux reducing assembly may progressively (gradually) reduce the volumetric flow area of the annulus  120  adjacent the ends of the screens  212   a,b . Progressively reducing the volumetric flow area may urge the fluid  218  to traverse the screens  212   a,b  (either influx or outflow) across a larger axial length of the screens  212   a,b  and thereby spread the volumetric flow over a larger area, which reduces the peak velocity of the fluid  218  traversing the screens  212   a,b . By reducing the peak velocity of the fluid  218  entering and exiting the base pipe  202  at or near the ends of the screens  212   a,b , localized erosion of the screens  212   a,b  may be drastically reduced, which may mitigate early failure of the screens  212   a,b.    
       FIG. 3  is a cross-sectional side view of an example sand control screen assembly  300  in accordance with one or more embodiments of the present disclosure. The sand control screen assembly  300  (hereafter “the screen assembly  300 ”) may similar to the screen assembly  200  of  FIG. 2  and, therefore, may be best understood with reference thereto, where like numerals will represent like components not described again. Similar to the screen assembly  200 , the screen assembly  300  may replace any of the sand control screen assemblies  116  of  FIG. 1  and, therefore, may be used in the well system  100  depicted therein. In at least one embodiment, the screen assembly  300  may be arranged at the end of the completion string  114  ( FIG. 1 ) and otherwise comprise the last screen section at or near the toe of the wellbore  102 . Moreover, the screen assembly  300  may be arranged in an open hole section of the wellbore  102 , thus making the screen assembly  300  a standalone screen. 
     Similar to the screen assembly  200  of  FIG. 2 , the screen assembly  300  includes the base pipe  202  and the sand screens  212   a,b  are arranged about the base pipe  202  and extend axially from the corresponding housings  214   a,b , respectively. Unlike the screen assembly  200  of  FIG. 2 , however, the screen assembly  300  may include a peak flux reducing assembly  302  arranged at or axially adjacent the wellbore isolation device  118 . The peak flux reducing assembly  302  may be operable to reduce the peak velocity of the fluid  218  traversing one or both of the sand screens  212   a,b  on either side of the wellbore isolation device  118 . While described herein as able to reduce the peak velocity of the fluid  218  through both of the sand screens  212   a,b , the peak flux reducing assembly  302  could alternatively be operable to reduce the peak velocity of the fluid  218  through only one of the sand screens  212   a,b , without departing from the scope of the disclosure. 
     As illustrated, the peak flux reducing assembly  302  may include one or more housing flow ports  304  (alternately referred to as “end ring” flow ports) defined in the base pipe  202  radially beneath the first and second housings  214   a,b . More specifically, the housing flow ports  304  may be defined in the first and second base pipe portions  208   a,b  and the corresponding housings  214   a,b  may be installed over the housing flow ports  304 . In some embodiments, multiple housing flow ports  304  may be defined in the base pipe portions  208   a,b  about the circumference thereof and located radially beneath the corresponding housings  214   a,b , respectively. 
     The peak flux reducing assembly  302  may further include an impermeable section of the base pipe  202  at the end of each screen  212   a,b  adjacent the housings  214   a,b . More specifically, the first base pipe portion  208   a  may provide a first impermeable section  306   a  and the second base pipe portion  208   b  may provide a second impermeable section  306   b , alternately referred to as a “tuned length” impermeable section. As illustrated, the first impermeable section  306   a  may extend between the housing flow port(s)  304  and the flow ports  204  of the first base pipe portion  208   a . Similarly, the second impermeable section  306   b  may extend between the housing flow port(s)  304  and the flow ports  204  of the second base pipe portion  208   b.    
     Each impermeable section  306   a,b  may comprise an axial length of the base pipe  202  that is non-perforated and is otherwise impermeable to fluid flow between the interior  206  and the production annulus  216  of each sand screen  212   a,b . In some embodiments, as illustrated, at least a portion of each impermeable section  306   a,b  may extend radially beneath a corresponding portion of the sand screens  212   a,b , respectively. Moreover, in some embodiments, a portion of each impermeable section  306   a,b  may extend radially beneath the corresponding housing  214   a,b.    
     In example operation, fluids  218  from the surrounding formation  110  may be drawn into the annulus  120  and then circulated in the uphole direction (i.e., to the left in  FIG. 3 ) within the annulus  120  and the interior  206  of the base pipe  202 . Since the screen assembly  300  is positioned in an open hole annulus  120 , the fluid  218  will generally flow uphole simultaneously in both the annulus  120  and the interior  206  of the base pipe  202 . When the fluid  218  flowing within the annulus  120  approaches the wellbore isolation device  118 , the fluid  218  will be forced to traverse the second screen  212   b  to enter the base pipe  202 . 
     The second impermeable section  306   b  may operate to urge the incoming fluid  218  through the second screen  212   b  via multiple flow paths. More specifically, a portion of the fluid  218  may pass through the second screen  212   b  at or near the location of the flow ports  204  nearest the housing flow port  304  in the second base pipe portion  208   b , and another portion of the fluid  218  may simultaneously pass through the second screen  212   b  at or near the end of the screen  212   b  at the second housing  214   b . Positioning the housing flow port  304  radially beneath the second housing  214   b  forces the fluid  218  to change fluid flow direction within the production annulus  216  to reach the housing flow port  304 . Consequently, since the fluid  218  enters the base pipe  202  at multiple locations, the peak velocity of the fluid  218  may be reduced as compared to fluid flow through a single location. 
     Once bypassing the axial location of the wellbore isolation device  118  within the interior  206  of the base pipe  202 , the flow of the fluid  218  will naturally tend to spread out (split) again to reduce (minimize) friction and pressure. Accordingly, a portion of the fluid  218  may return to the annulus  120  by exiting the base pipe  202  through the first screen  212   a . The first impermeable section  306   a  may operate to urge a portion of the fluid  218  out of the base pipe  202  via multiple flow paths. More specifically, a first portion of the fluid  218  may flow through the housing flow port  304  beneath the first housing  214   a , and another portion of the fluid  218  may simultaneously  212   b  flow through the flow ports  204  nearest the first housing  214   a . Positioning the housing flow port  304  radially beneath the first housing  214   a  forces the fluid  218  to change fluid flow direction within the production annulus  216  to reach the first screen  212   a . Consequently, the fluid  218  may exit the base pipe  202  at multiple locations, but at reduced peak velocities as compared to fluid flow through a single location. 
     In some embodiments, the screen assembly  300  may be tuned or otherwise optimized to adjust the influx and outflow of the fluid  218  through the sand screens  212   a,b  at the multiple locations. In at least one embodiment, for example, the size (diameter) of one or both of the housing flow ports  304  may be adjusted (enlarged or reduced). In other embodiments, or in addition thereto, the axial length of the impermeable sections  306   a,b  may be adjusted (elongated or shortened). Adjusting the size of the housing flow ports  304  and/or the length of the impermeable sections  306   a,b  may alter the backpressure of the fluid  218  and thus alter how much fluid  218  flows through the housing flow ports  304 , while the rest is diverted through the other flow ports  204 . 
     Adjustments to the size (diameter) of the housing flow ports  304  and/or the length of the impermeable sections  306   a,b  may be based on various known parameters of the screen assembly  300 . Example known parameters include, but are not limited to, one or more fluid properties of the fluid  218  (e.g., flow rate, viscosity, etc.), one or more geometric parameters of the well (e.g., diameter of the wellbore  102 , etc.), one or more features of the screens  212   a,b  (e.g., size of the screens, height of the ribs, number of flow ports  204  in the base pipe  202 , etc.), or any combination thereof. 
       FIG. 4  is a plot  400  comparing peak fluid flow velocity through the screen assembly  200  of  FIG. 2  and the screen assembly  300  of  FIG. 3  that incorporates the principles of the present disclosure. More specifically, the plot  400  tracks and reports the radial velocity of the fluid flow (in meters per second) based on distance (in meters) along the length of the base pipe  202  ( FIGS. 2 and 3 ) for each screen assembly  200 ,  300 . Accordingly, the results of the plot  400  will be best understood with continued reference to  FIGS. 2 and 3 . 
     For the screen assembly  200 , the radial velocity of the fluid flow is generally zero (moving right to left in uphole fluid flow) until around 3.2 meters, at which point the fluid rapidly accelerates through the second screen  212   b  ( FIG. 2 ) and into the base pipe  202 . This rapid fluid acceleration results in a single influx hotspot  402  of the fluid  218  ( FIG. 2 ) through the second screen  212   b  at a radial peak velocity of about −0.085 m/s (negative since flow is into the base pipe  202 ). Once in the base pipe  202  at or near 4.5 meters, the radial velocity of the fluid  218  drops back to zero until the flow reaches about 5.5 meters, at which point a portion of the fluid  218  again rapidly accelerates, but this time out of the base pipe  202  and through the first screen  212   a  ( FIG. 2 ). This rapid fluid acceleration results in a single outflow hotspot  404  of the fluid  218  through the first screen  212   a  at a radial peak velocity of about 0.05 m/s (positive since flow is out of the base pipe  202 ). 
     For the screen assembly  300  that incorporates the peak flux reducing assembly  302  ( FIG. 3 ), in contrast, the radial velocity of the fluid flow is generally zero (moving right to left in uphole flow) until around 2.5 meters, at which point a first portion of the fluid  218  ( FIG. 3 ) accelerates radially through the second screen  212   b  ( FIG. 3 ) and into the base pipe  202  ( FIG. 3 ). This results in a first influx hotspot  406   a  for the fluid  218  through the second screen  212   b  at a radial peak velocity of about −0.045 m/s. Because of the second impermeable section  306   b  ( FIG. 3 ) of the peak flux reducing assembly  302 , a second portion of the fluid  218  may also accelerate radially through the second screen  212   b  at about 3.5 meters and passes through the housing flow port  304  ( FIG. 3 ) radially beneath the second housing  214   b  ( FIG. 3 ). This results in a second influx hotspot  406   b  for the fluid  218  through the second screen  212   b  at a radial peak velocity of about −0.04 m/s. 
     As with the first screen assembly  200 , the radial velocity of the fluid  218  in the second screen assembly  300  drops back to zero until the flow reaches about 5.5 meters, at which point a portion of the fluid  218  again rapidly accelerates, but this time out of the base pipe  202 . Because of the first impermeable section  306   a  ( FIG. 3 ), flow out of the base pipe  202  may be split and thus results in a first outflow hotspot  408   a  and a second outflow hotspot  408   b . The first outflow hotspot  408   a  may be representative of fluid flow through the flow ports  204  ( FIG. 3 ) and the first screen  212   a  at about 6.5 meters, and the second outflow hotspot  408   b  may be representative of fluid flow through the housing flow port  304  ( FIG. 3 ) beneath the first housing  214   a  ( FIG. 3 ) and the first screen  212   a . As indicated, the radial peak velocity of the fluid  218  at the first outflow hotspot  408   a  is about 0.033 m/s, while the radial peak velocity of the fluid  218  at the second outflow hotspot  408   b  is about 0.03 m/s. 
     The plot  400  provides testing results that indicate that the screen assembly  300  that incorporates the peak flux reducing assembly  302  advantageously splits fluid flow hotspots into a plurality of hotspots, which correspondingly reduces the peak velocity of the fluid  218  entering and exiting the base pipe  202 . By reducing the peak velocity, localized erosion of the screens  212   a,b  may be reduced, which may mitigate early failure of the screens  212   a,b.    
       FIG. 5  is a cross-sectional side view of another sand control screen assembly  500 . The sand control screen assembly  500  (hereafter “the screen assembly  500 ”) may be similar in some respects to the screen assemblies  200 ,  300  of  FIGS. 2 and 3 , respectively, and therefore may be best understood with reference thereto, where like numerals will represent like components not described again. Similar to the screen assemblies  200  and  300 , the screen assembly  500  includes the base pipe  202  and the sand screens  212   a,b  are arranged about the base pipe  202 . 
     Unlike the screen assemblies  200  and  300 , however, the sand screens  212   a,b  may be wrapped directly onto the corresponding base pipe portions  208   a,b  such that no production annulus  216  ( FIGS. 2 and 3 ) is provided. In other embodiments, however, the production annulus  216  may nonetheless be provided beneath one or both of the sand screens  212   a,b . Moreover, the first and second and screens  212   a  may extend axially from corresponding first and second housings  502   a  and  502   b , respectively. Similar to the housings  214   a,b  of  FIGS. 2 and 3 , the housings  502   a,b  provide a mechanical interface between the base pipe  202  and the corresponding first and second sand screens  212   a,b . In other embodiments, however, one or both of the housings  502   a,b  may be omitted and the sand screens  212   a,b  may alternatively be welded or otherwise directly coupled to the base pipe  202 . 
     Operation of the screen assembly  500  is substantially similar to operation of the screen assembly  200  of  FIG. 2 . More specifically, fluids  218  from the surrounding formation  110  may be drawn into the annulus  120  and circulated in the uphole direction (i.e., to the left in  FIG. 5 ) within the annulus  120  and the interior  206  of the base pipe  202 . In open hole applications, the fluid  218  will generally flow uphole in both the annulus  120  and the interior  206  of the base pipe  202 . Upon approaching the wellbore isolation device  118 , the fluid  218  flowing within the annulus  120  is forced through the second screen  212   b  at or near the second housing  502   b  and subsequently enters the base pipe  202  via the flow ports  204  axially adjacent the second housing  502   b . Due to the dynamics of fluid flow, the fluid  218  from the annulus  120  is accelerated through the second screen  212   b  at peak velocity at or near the second housing  502   b , which greatly accelerates the erosion of the screen  212   b  at this location. 
     Once bypassing the axial location of the wellbore isolation device  118  within the interior  206  of the base pipe  202 , the flow of the fluid  218  will naturally tend to spread out (split) again to reduce (minimize) friction and pressure. Accordingly, a portion of the fluid  218  within the base pipe  202  may return to the annulus  120  by passing back out of the base pipe  202  and traversing the first screen  212   a  at or near the first housing  502   a . The fluid  218  exiting the base pipe  202  and the first screen  212   a  may also be accelerated at peak velocity at or near the first housing  502   b . Due to the peak velocity of the fluid  218  passing through the ends of the screens  212   a,b  near the housings  502   a,b , localized fluid “hotspots” may develop and can result in erosional screen failure at these locations. 
       FIG. 6  is a cross-sectional side view of an example sand control screen assembly  600  in accordance with one or more embodiments of the present disclosure. The sand control screen assembly  600  (hereafter “the screen assembly  600 ”) may be similar to the screen assembly  500  of  FIG. 5  and, therefore, may be best understood with reference thereto, where like numerals will represent like components not described again. The screen assembly  600  may replace any of the sand control screen assemblies  116  of  FIG. 1  and, therefore, may be used in the well system  100  depicted therein. In at least one embodiment, the screen assembly  600  may be arranged at the end of the completion string  114  ( FIG. 1 ) and otherwise comprise the last screen section at or near the toe of the wellbore  102 . Moreover, the screen assembly  600  may be arranged in an open hole section of the wellbore  102 , thus making the screen assembly  600  a standalone screen. 
     Similar to the screen assembly  500  of  FIG. 5 , the screen assembly  600  includes the base pipe  202  and the sand screens  212   a,b  are arranged about the base pipe  202  and extend axially from the corresponding housings  502   a,b , respectively. Unlike the screen assembly  500 , however, the screen assembly  600  may include a peak flux reducing assembly  602  arranged at or adjacent the wellbore isolation device  118  and operable to reduce a peak velocity of the fluid  218  traversing one or both of the sand screens  212   a,b . In the illustrated embodiment, the peak flux reducing assembly  602  is operable to reduce the peak velocity of the fluid  218  traversing both sand screens  212   a,b  on either axial side of the wellbore isolation device  118 , but could alternatively be operable to reduce the peak velocity of the fluid  218  traversing only one of the sand screens  212   a,b , without departing from the scope of the disclosure. 
     As illustrated, the peak flux reducing assembly  602  may include a first or uphole flow diverter  604   a  that extends axially uphole from the wellbore isolation device  118  and second or downhole flow diverter  604   b  that extends downhole from the wellbore isolation device  118 . In other embodiments, however, the peak flux reducing assembly  602  may include only one of the first or second flow diverters  604   a,b , without departing from the scope of the disclosure. The peak flux reducing assembly  602  may operate to progressively reduce the volumetric flow area of the annulus  120  at the ends of the screens  212   a,b  axially adjacent the wellbore isolation device  118 , which may spread the volumetric flow of the fluid  218  through the screens  212   a,b  (either influx or outflow) across a larger axial length (area). 
     In some embodiments, the peak flux reducing assembly  602  may comprise an integral part or extension of the wellbore isolation device  118 . In such embodiments, deploying the wellbore isolation device  118  within the annulus  120  may simultaneously deploy the flow diverters  604   a,b  on one or both sides of the wellbore isolation device  118 . Moreover, in such embodiments, the peak flux reducing assembly  602  may comprise an expandable or swellable material capable of creeping axially uphole and/or downhole to progressively reduce the volumetric flow area of the annulus  120 . In other embodiments, the peak flux reducing assembly  602  may comprise a separate component or structure from the wellbore isolation device  118 . In such embodiments, the peak flux reducing assembly  602  may be deployed simultaneously with the wellbore isolation device  118  or at a different time. 
     As illustrated, the peak flux reducing assembly  602  (i.e., the flow diverters  604   a,b ) may extend axially past the first and second housings  502   a,b  and radially above a portion of the sand screens  212   a,b  in either axial direction. Each flow diverter  604   a,b  may define or otherwise include a tapered or angled face  606  that extends from the wellbore isolation device  118  to the inner wall of the wellbore  102 . In some embodiments, as illustrated, the angled face  606  may be continuous or straight. In other embodiments, however, the angled face  606  may be discontinuous (e.g., stepped, jagged, undulating, etc.) or otherwise non-linear, without departing from the scope of the disclosure. In some embodiments, the first and second flow diverters  604   a,b  may comprise solid structures. In other embodiments, however, the first and second flow diverters  604   a,b  may comprise hollow shell structures that nonetheless facilitate flow diversion. 
     In example operation, fluids  218  from the surrounding formation  110  may be drawn into the annulus  120  and then circulated in the uphole direction (i.e., to the left in  FIG. 6 ) within the annulus  120  and the interior  206  of the base pipe  202 . The fluid  218  may access the interior  206  by passing through the screens  212   a,b , and since the screen assembly  600  is positioned in an open hole annulus  120 , the fluid  218  will generally flow uphole simultaneously in both the annulus  120  and the interior  206  of the base pipe  202 . 
     Upon approaching the wellbore isolation device  118  in the uphole direction, the fluid  218  in the annulus  120  will be diverted through the second screen  212   b  to enter the base pipe  202 . The second flow diverter  604   b  may operate to progressively reduce the volumetric flow area of the annulus  120  near the wellbore isolation device  118  in the uphole direction. As a result, the flux of the fluid  218  may be forced into the base pipe  202  progressively, and not all at once at the end of the second sand screen  212   b . Consequently, the fluid  218  may be urged through the second screen  212   b  across a larger (longer) axial length of the second screen  212   b  as compared to the embodiment of  FIG. 5 . More specifically, peak velocity of the fluid  218  traversing the second screen  212   b  may be less than the peak velocity of the fluid  218  traversing the second screen  212   b  in the embodiment of  FIG. 5 . 
     Once bypassing the axial location of the wellbore isolation device  118  within the interior  206  of the base pipe  202 , the flow of the fluid  218  will naturally tend to spread out (split) again to reduce (minimize) friction and pressure. Accordingly, a portion of the fluid  218  may return to the annulus  120  by exiting the base pipe  202  through the first screen  212   a . The first flow diverter  604   a  may progressively increase the volumetric flow area of the annulus  120  near the wellbore isolation device  118  in the uphole direction. As a result, the fluid  218  may be urged through the first screen  212   a  across a larger (longer) axial length of the first screen  212   a  as compared to the embodiment of  FIG. 5 . Consequently, the peak velocity of the fluid  218  traversing the first screen  212   a  may be less than the peak velocity of the fluid  218  traversing the first screen  212   a  in the embodiment of  FIG. 5 . By reducing the peak velocity of the fluid  218  entering and exiting the base pipe  202  at or near the ends of the screens  212   a,b , localized erosion of the screens  212   a,b  may be drastically reduced, which may mitigate early failure of the screens  212   a,b.    
     In some embodiments, the peak flux reducing assembly  602  may be tuned or otherwise optimized to adjust the influx and/or outflow of the fluid  218  through the sand screens  212   a,b . In at least one embodiment, for example, the size and/or configuration of the first and/or second flow diverters  604   a,b  may be adjusted. In such embodiments, the axial length of one or both of the flow diverters  604   a,b  may be elongated or shortened, which may result in spreading the flow of the fluid  218  through the screens  212   a,b  over differing axial lengths. In other embodiments, the angled face  606  of one or both of the flow diverters  604   a,b  may be altered to adjust the back pressure of the fluid  218  within the annulus  120 , which may correspondingly alter the flow area of the fluid through the screens  212   a,b.    
     Adjustments to the size and/or configuration of the peak flux reducing assembly  602  may be based on various known parameters of the screen assembly  600 . Example known parameters include, but are not limited to, one or more fluid properties of the fluid  218  (e.g., flow rate, viscosity, etc.), one or more geometric parameters of the well (e.g., diameter of the wellbore  102 , etc.), one or more features of the screens  212   a,b  (e.g., size of the screens, height of the ribs, number of flow ports  204  in the base pipe  202 , etc.), or any combination thereof. 
       FIG. 7  is a plot  700  comparing fluid flow through the screen assembly  500  of  FIG. 5  with fluid flow through the screen assembly  600  of  FIG. 6  that incorporates the principles of the present disclosure. Accordingly, the plot  700  will be best understood with continued reference to  FIGS. 5 and 6 . As illustrated, the radial velocity of the fluid flow (in meters per second) is tracked based on distance (in meters) along the length of the base pipe  202  ( FIGS. 5 and 6 ) for each screen assembly  500 ,  600 . Only fluid flow through the second sand screen  212   b  is depicted in the plot  700 . 
     For the screen assembly  500 , the radial velocity of the fluid flow is generally zero (moving right to left, e.g., uphole flow) until reaching the end of the sand screen  212   b , at which point the fluid rapidly accelerates radially through the second screen  212   b  ( FIG. 5 ) and into the base pipe  202 . This rapid fluid acceleration results in a single influx hotspot  702  for the influx of the fluid  218  ( FIG. 5 ) through the second screen  212   b  at a radial peak velocity of about −0.11 m/s (negative since flow is into the base pipe  202 ). The fluid  218  accelerates through the sand screen  212   b  sharply at about 0.5 meters. 
     In contrast, for the screen assembly  600 , flow through the second sand screen  212   b  ( FIG. 6 ) is spread across a larger portion of the base pipe  202  ( FIG. 6 ). More specifically, the radial velocity of the fluid flow is generally zero (moving right to left, e.g., uphole flow) until around 1.0 meters, at which point the fluid  218  ( FIG. 6 ) starts to traverse radially through the second screen  212   b  and into the base pipe  202  ( FIG. 6 ). As indicated in the plot  700 , the fluid  218  traverses the second screen  212   b  between about 1.0 meters and about 0.5 meters, thus spreading the fluid flux across a larger portion of the second screen and resulting in an influx hotspot  704  through the second screen  212   b  at a radial peak velocity of about −0.05 m/s. 
     The plot  700  indicates that the screen assembly  600  advantageously spreads the fluid flow across a larger section of the base pipe  202 , which correspondingly reduces the peak velocity of the fluid  218  entering the base pipe  202 . By reducing the peak velocity of the fluid  218  entering the base pipe  202  localized erosion of the second screen  212   b  may be drastically reduced, which may mitigate early failure of the screen  212   b.    
     While the foregoing description is directed generally to production operations, the principles of the present disclosure are equally applicable to injection operations. More specifically, fluids conveyed from a surface location to the screen assemblies  300 ,  600  of  FIGS. 3 and 6 , respectively, may be ejected into the surrounding annulus  120  through the upper and lower sand screens  212   a,b . The flux reducing assemblies  302 ,  602  of  FIGS. 3 and 6 , respectively, may operate to reduce the peak velocity of the fluid injected into the annulus  120  at the ends of the sand screens  212   a,b.    
     Moreover, while the flux reducing assemblies  302 ,  602  of  FIGS. 3 and 6 , respectively, are described herein as independently operable of one another, it is contemplated herein to combine the flux reducing assemblies  302 ,  602  in a common application. In such embodiments, the peak velocity of the fluid  218  entering and/or exiting the base pipe  202  may be reduced by urging the fluid  218  through the screens  212   a,b  at multiple locations while simultaneously urging the fluid  218  to traverse the screens  212   a,b  across a larger axial length of the screens  212   a,b  and thereby spread the volumetric flow over a larger area. 
     Embodiments disclosed herein include: 
     A. A method of reducing erosional peak velocity that includes arranging a sand control screen assembly in an open hole section of a wellbore, the sand control screen assembly including a base pipe defining a plurality of flow ports, a sand screen arranged about the base pipe, and a wellbore isolation device deployed within an annulus defined between the sand control screen assembly and an inner wall of the wellbore, circulating a fluid from a surrounding subterranean formation within the annulus, diverting the fluid through the sand screen and into the base pipe upon approaching the wellbore isolation device, and reducing a peak velocity of the fluid flowing through the sand screen with a peak flux reducing assembly arranged axially adjacent the wellbore isolation device. 
     B. A sand control screen assembly deployable within an open hole section of a wellbore and including a base pipe that defines a plurality of flow ports, a sand screen arranged about the base pipe, a wellbore isolation device deployable within an annulus defined between the sand control screen assembly and an inner wall of the wellbore, and a peak flux reducing assembly arranged axially adjacent the wellbore isolation device to reduce a peak velocity of fluids traversing the sand screen. 
     Each of embodiments A and B may have one or more of the following additional elements in any combination: Element 1: wherein the sand screen terminates at a housing arranged axially adjacent the wellbore isolation device, and the peak flux reducing assembly includes one or more housing flow ports defined in the base pipe radially beneath the housing and an impermeable section of the base pipe extends between the one or more housing flow ports and the plurality of flow ports, the method further comprising flowing a first incoming portion of the fluid through the sand screen at or near the plurality of flow ports nearest the housing, and flowing a second incoming portion of the fluid through the sand screen at or near the housing and through the one or more housing flow ports. Element 2: further comprising altering a flow rate of the first and second incoming portions of the fluid through the sand screen by adjusting at least one of i) a size of the one or more housing flow ports, and ii) an axial length of the impermeable section. Element 3: wherein the sand control screen assembly further includes a second sand screen arranged about the base pipe and terminating at a second housing arranged axially adjacent the wellbore isolation device, and wherein the peak flux reducing assembly further includes one or more second housing flow ports defined in the base pipe radially beneath the second housing and a second impermeable section of the base pipe extends between the one or more second housing flow ports and a second plurality of flow ports defined in the base pipe, the method further comprising flowing the fluid within the base pipe past an axial location of the wellbore isolation device, flowing a first exiting portion of the fluid out of the base pipe through the second sand screen via the one or more second housing flow ports, and flowing a second exiting portion of the fluid out of the base pipe through the second sand screen via the second plurality of flow ports nearest the second housing. Element 4: further comprising altering a flow rate of the first and second exiting portions of the fluid through the second sand screen by adjusting at least one of i) a size of the one or more second housing flow ports, and ii) an axial length of the second impermeable section. Element 5: wherein the peak flux reducing assembly includes a flow diverter extending axially from the wellbore isolation device and radially above an end of the sand screen within the annulus, and wherein the flow diverter progressively reduces a volumetric flow area of the annulus in an uphole direction at the end of the sand screen, the method further comprising impinging the fluid within the annulus on the flow diverter and thereby progressively urging the fluid through the sand screen along an axial length of the sand screen. Element 6: further comprising altering a flow rate of the fluid through the sand screen by adjusting at least one of i) a size of the flow diverter, ii) an axial length of the flow diverter, and iii) an angled face of the flow diverter. Element 7: wherein the sand control screen assembly further includes a second sand screen arranged about the base pipe axially adjacent the wellbore isolation device, and the peak flux reducing assembly further includes a second flow diverter extending axially from the wellbore isolation device and radially above an end of the second sand screen within the annulus, and wherein the second flow diverter progressively increases a volumetric flow area of the annulus in the uphole direction at the end of the second sand screen, the method further comprising flowing the fluid within the base pipe past an axial location of the wellbore isolation device, and flowing a portion of the fluid out of the base pipe through the second sand screen along an axial length of the second sand screen. Element 8: further comprising altering a flow rate of the fluid through the second and screen by adjusting at least one of i) a size of the second flow diverter, ii) an axial length of the second flow diverter, and iii) an angled face of the second flow diverter. Element 9: wherein circulating the fluid from the surrounding subterranean formation within the annulus comprises simultaneously circulating a portion of the fluid from the surrounding subterranean formation within the base pipe. 
     Element 10: wherein the peak flux reducing assembly comprises a housing arranged axially adjacent the wellbore isolation device, wherein the sand screen terminates at the housing, one or more housing flow ports defined in the base pipe radially beneath the housing, and an impermeable section of the base pipe extending between the one or more housing flow ports and the plurality of flow ports, wherein the impermeable section urges a first incoming portion of the fluid through the sand screen at or near the plurality of flow ports nearest the housing and a second incoming portion of the fluid through the sand screen at or near the housing and through the one or more housing flow ports. Element 11: wherein the impermeable section extends radially beneath a portion of the sand screen and radially beneath the housing. Element 12: wherein the sand control screen assembly further includes a second sand screen arranged about the base pipe and the peak flux reducing assembly further comprises a second housing arranged axially adjacent the wellbore isolation device, wherein the second sand screen terminates at the second housing, one or more second housing flow ports defined in the base pipe radially beneath the second housing, and a second impermeable section of the base pipe extending between the one or more second housing flow ports and a second plurality of flow ports defined in the base pipe. Element 13: wherein the second impermeable section extends radially beneath a portion of the second sand screen and radially beneath the second housing. Element 14: wherein the peak flux reducing assembly comprises a flow diverter extending from the wellbore isolation device radially above an end of the sand screen within the annulus, and wherein the flow diverter progressively reduces a volumetric flow area of the annulus in an uphole direction at the end of the sand screen. Element 15: wherein the sand control screen assembly further includes a second sand screen arranged about the base pipe axially adjacent the wellbore isolation device, and the peak flux reducing assembly further comprises a second flow diverter extending from the wellbore isolation device radially above an end of the second sand screen within the annulus, wherein the second flow diverter progressively increases a volumetric flow area of the annulus in the uphole direction at the end of the second sand screen. Element 16: wherein the peak flux reducing assembly comprises a housing arranged axially adjacent the wellbore isolation device, wherein the sand screen terminates at the housing, one or more housing flow ports defined in the base pipe radially beneath the housing, an impermeable section of the base pipe extending between the one or more housing flow ports and the plurality of flow ports, and a flow diverter extending from the wellbore isolation device radially above an end of the sand screen within the annulus. Element 17: further comprising a second sand screen arranged about the base pipe, wherein the peak flux reducing assembly further comprises a second housing arranged axially adjacent the wellbore isolation device, wherein the second sand screen terminates at the second housing, one or more second housing flow ports defined in the base pipe radially beneath the second housing, a second impermeable section of the base pipe extending between the one or more second housing flow ports and a second plurality of flow ports defined in the base pipe, and a second flow diverter extending from the wellbore isolation device radially above an end of the second sand screen within the annulus. 
     By way of non-limiting example, exemplary combinations applicable to A and B include: Element 1 with Element 2; Element 1 with Element 3; Element 3 with Element 4; Element 5 with Element 6; Element 5 with Element 7; Element 7 with Element 8; Element 10 with Element 11; Element 10 with Element 12; Element 12 with Element 13; Element 14 with Element 15; and Element 16 with Element 17. 
     Therefore, the disclosed systems and methods are well adapted to attain the ends and advantages mentioned as well as those that are inherent therein. The particular embodiments disclosed above are illustrative only, as the teachings of the present disclosure may be modified and practiced in different but equivalent manners apparent to those skilled in the art having the benefit of the teachings herein. Furthermore, no limitations are intended to the details of construction or design herein shown, other than as described in the claims below. It is therefore evident that the particular illustrative embodiments disclosed above may be altered, combined, or modified and all such variations are considered within the scope of the present disclosure. The systems and methods illustratively disclosed herein may suitably be practiced in the absence of any element that is not specifically disclosed herein and/or any optional element disclosed herein. While compositions and methods are described in terms of “comprising,” “containing,” or “including” various components or steps, the compositions and methods can also “consist essentially of” or “consist of” the various components and steps. All numbers and ranges disclosed above may vary by some amount. Whenever a numerical range with a lower limit and an upper limit is disclosed, any number and any included range falling within the range is specifically disclosed. In particular, every range of values (of the form, “from about a to about b,” or, equivalently, “from approximately a to b,” or, equivalently, “from approximately a-b”) disclosed herein is to be understood to set forth every number and range encompassed within the broader range of values. Also, the terms in the claims have their plain, ordinary meaning unless otherwise explicitly and clearly defined by the patentee. Moreover, the indefinite articles “a” or “an,” as used in the claims, are defined herein to mean one or more than one of the elements that it introduces. If there is any conflict in the usages of a word or term in this specification and one or more patent or other documents that may be incorporated herein by reference, the definitions that are consistent with this specification should be adopted. 
     As used herein, the phrase “at least one of” preceding a series of items, with the terms “and” or “or” to separate any of the items, modifies the list as a whole, rather than each member of the list (i.e., each item). The phrase “at least one of” allows a meaning that includes at least one of any one of the items, and/or at least one of any combination of the items, and/or at least one of each of the items. By way of example, the phrases “at least one of A, B, and C” or “at least one of A, B, or C” each refer to only A, only B, or only C; any combination of A, B, and C; and/or at least one of each of A, B, and C.