Patent Publication Number: US-11041348-B2

Title: Graphene oxide coated membranes to increase the density of water base fluids

Description:
CROSS-REFERENCE TO RELATED APPLICATIONS 
     This application is a continuation of and claims priority to U.S. patent application Ser. No. 16/599,308, filed Oct. 11, 2019, and entitled “Graphene Oxide Coated Membranes to Increase the Density of Water Base Fluids,” which is hereby incorporated by reference in its entirety for all purposes. 
    
    
     TECHNICAL FIELD 
     The present disclosure relates generally to systems and methods for servicing a wellbore extending from a surface of the earth and penetrating a subterranean formation; more specifically, the present disclosure relates to systems and methods for servicing a wellbore including recovering water from an aqueous based fluid; still more specifically, this disclosure relates to systems and methods for servicing a wellbore wherein water is recovered from an aqueous based fluid via contacting of the aqueous based fluid with a coated substrate including a porous substrate coated with a hydrophilic and oleophobic coating, whereby water is removed from the aqueous based fluid via passage through the coated substrate, and whereby a water concentration and a volume of the aqueous based fluid are reduced and a density of the aqueous based fluid is increased to provide a modified wellbore servicing fluid. 
     BACKGROUND 
     During wellbore servicing (e.g., drilling) operations, aqueous based fluids can have and/or can uptake water such that a water concentration is or becomes undesirably high and/or a density of the aqueous based fluid is or becomes undesirably low. Conventionally, the density of, for example, a drilling fluid is increased via the addition of a weighting agent, such as barite. Such addition of weighting agent typically increases the fluid volume. Over time this process may be deemed undesirable, for example, when storage apparatus for the fluid has a limited volume. 
     Accordingly, there exists a need for a system and method of recovering water from aqueous based fluids during wellbore servicing operations, whereby a water concentration of the water based fluid can be reduced (e.g., and a density increased and/or a volume decreased) and/or the water concentration (e.g., the density and/or volume) maintained. Desirably, the systems and methods enable recovery of potable water and/or the production of a reduced volume of waste material needing disposal. 
    
    
     
       BRIEF SUMMARY OF THE DRAWINGS 
       For a more complete understanding of this disclosure, reference is now made to the following brief description, taken in connection with the accompanying drawings and detailed description, wherein like reference numerals represent like parts. 
         FIG. 1A  is a schematic of a coated substrate, according to embodiments of this disclosure; 
         FIG. 1B  is a cross section view of the coated substrate of  FIG. 1A ; 
         FIG. 2  is a schematic of a system I for recovering water from a water base fluid, according to embodiments of this disclosure; 
         FIG. 3  is a schematic of another system II for recovering water from a water base fluid, according to embodiments of this disclosure; 
         FIG. 4  is a schematic cross section view of a water removal apparatus according to embodiments of this disclosure; 
         FIG. 5A  is a schematic of another system III for recovering water from a water base fluid, according to embodiments of this disclosure; 
         FIG. 5B  is a front cross section view of the water removal apparatus of  FIG. 5A ; 
         FIG. 6A  is a schematic of another system IV for recovering water from a water base fluid, according to embodiments of this disclosure; and 
         FIG. 6B  is a front cross section view of water removal apparatus of  FIG. 6A . 
     
    
    
     DETAILED DESCRIPTION 
     It should be understood at the outset that although an illustrative implementation of one or more embodiments are provided below, the disclosed systems and/or methods may be implemented using any number of techniques, whether currently known or in existence. The disclosure should in no way be limited to the illustrative implementations, drawings, and techniques illustrated below, including the exemplary designs and implementations illustrated and described herein, but may be modified within the scope of the appended claims along with their full scope of equivalents. 
     The terms “water based fluids” and “water base fluids” are utilized interchangeably herein, and refer to fluids including a base fluid selected from fresh water, seawater, saturated brine, formate brine, or a combination thereof. 
     As utilized herein, the term “hydrophilic” indicates “water attracting”, i.e., having more thermodynamically favorable interactions with water than with oil or other hydrophobic solvents. 
     As utilized herein, the term “oleophobic” indicates “oil repelling”, i.e., lacking an affinity to oil. 
     As utilized herein, the term “drilling fluids” includes drill-in fluids, such as brines. 
     Herein disclosed are systems and methods for servicing a wellbore extending from a surface of the earth and penetrating a subterranean formation. The herein disclosed systems and methods provide for removing water from an aqueous based wellbore servicing fluid by contacting the aqueous based wellbore servicing fluid with a coated substrate including a porous substrate coated with a hydrophilic and oleophobic coating. Via contact of the aqueous based wellbore servicing fluid with the coated porous substrate, water is removed from the aqueous based wellbore servicing fluid via passage through the porous substrate, whereby a water concentration and a volume of the aqueous based wellbore servicing fluid are reduced and a density of the aqueous based wellbore servicing fluid is increased to provide a modified aqueous based wellbore servicing fluid. 
     In embodiments, the herein disclosed systems and methods can be utilized to improve water base wellbore servicing (e.g., drilling) fluids management. For example, in embodiments, the disclosed systems and methods can be utilized (e.g., at a rig site) to reduce waste and manage drilling fluid density. In embodiments, the herein disclosed wellbore servicing systems and methods can be utilized to manage fluid volumes in a mud plant and potential fluid density and volumes at a rig site and provide for the production of heavier water based fluids with barite additions. 
     As detailed hereinbelow, coated substrates (e.g., graphene oxide coated membranes) can be utilized to increase the density of water based drilling fluids. Conventionally, increasing the density of a drilling fluid employs the addition of a weighting agent (such as barite), which typically increases the fluid volume. Over time, such a process may be deemed undesirable. Using a coated substrate of this disclosure (e.g., a coated membrane) to remove water from the aqueous based fluid will lower its volume as well as increase the fluid density. In some cases, it may be desirable to remove some water from the aqueous based wellbore servicing fluid to provide a modified aqueous based wellbore servicing fluid and add weighting material to the modified wellbore servicing fluid to maintain a constant fluid volume of the wellbore servicing fluid, while increasing the density thereof. 
     A method of servicing a wellbore extending from a surface of the earth and penetrating a subterranean formation according to this disclosure includes: removing water from an aqueous based wellbore servicing fluid by contacting the aqueous based wellbore servicing fluid with a coated substrate including a porous substrate coated with a hydrophilic and oleophobic coating. The contacting of the aqueous based wellbore servicing fluid with the coated substrate results in removal of water from the wellbore servicing fluid via passage of water through the porous substrate, whereby a water concentration and a volume of the aqueous based wellbore servicing fluid are reduced and a density of the aqueous based wellbore servicing fluid is increased to provide a modified aqueous based wellbore servicing fluid. 
     As depicted in  FIG. 1A , which is a schematic of a coated substrate  40 , according to embodiments of this disclosure, the coated substrate  40  includes a porous substrate  42  including pores  45  and coated by hydrophilic and oleophobic coating  41 . The porous substrate can be any suitable substrate which can be coated with the hydrophilic and oleophobic coating and allow passage of water therethrough. In embodiments, the substrate  42  includes a support material. Although referred to as a “porous” substrate  42 , a substrate of coated substrate  40  can be any permeable material (e.g., with or without “pores”) which can be coated with the hydrophilic and oleophobic coating  41  and allow passage of water therethrough. In embodiments, the porous substrate  42  includes a membrane, a particulate, a tube, or a combination thereof. In the embodiment of  FIG. 1A , porous substrate  42  includes a cylindrical tube. In embodiments, porous substrate  42  includes a membrane shaped into a cylindrical tube, a flat membrane, or a membrane in another configuration. In embodiments, the porous substrate includes pores  45  having an average diameter of greater than or equal to about 0.5 nm, 1 nm, 2 nm, 3 nm, 4 nm, 5 nm, 10 nm, 20 nm, 30 nm, 40 nm, or 50 nm, less than or equal to about 20 μm, 10 μm, or 1 μm, or in a range of from about 0.5 nm to about 20,000 nm, from about 5 nm to about 10,000 nm, or from about 50 nm to about 1,000 nm. In embodiments, the porous substrate includes a polymer, a ceramic, a zeolite, a molecular sieve, or a combination thereof. 
     As depicted in the embodiment of  FIG. 1A , the hydrophilic and oleophobic coating of coated substrate  40  can have a thickness T 1  in a range of from about 1 to about 100 nm, from about 1 to about 50 nm, or from about 1 to about 50 nm, from about 1 to about 10 nm, less than or equal to about 100, 50, 40, 30, 20, or 10 nm, and/or greater than or equal to about 1, 2, 3, 4, 5, 6, 7, 8, 9, or 10 nm. Also as depicted in the embodiment of  FIG. 1A , the porous substrate  42  of coated substrate  40  can have a thickness T 2  in a range of from about 0.2 mm to about 100 mm, from about 1 mm to about 50 mm, or from about 10 mm to about 25 mm, less than or equal to about 100 mm, 50 mm, or 25 mm, and/or greater than or equal to about 0.2 mm, 1 mm, or 10 mm. 
     With reference to  FIG. 1B , which is a cross section of the coated substrate  40  of  FIG. 1A , in embodiments, coated substrate  40  (e.g., a cylindrical or spherical porous substrate  42 ) has an inner diameter in a range of from about 1 mm to about 50 mm, from about 1 mm to about 25 mm, from about 5 mm to about 35 mm, or from about 10 mm to about 50 mm, less than or equal to about 50 mm, 40 mm, 35 mm, 30 mm, 20 mm, or 10 mm, and/or greater than or equal to about 1 mm, 2 mm, 3 mm, 4 mm, 5 mm, 6 mm, 7 mm, 8 mm, 9 mm, or 10 mm. 
     Water passes from one side of coated substrate  40  to another, generally from the coated side to the (e.g., porous) substrate side. For example, as depicted in  FIG. 1A  and  FIG. 1B , coated substrate  40  is configured for passage of water from an outside  44  to an inside  43  thereof, as illustrated by arrow A 1 . Alternatively, a substrate having a cylindrical tube shape is coated on an inside thereof with the hydrophilic and oleophobic coating  41 , and water is introduced into the inside  43  of coated substrate  40  and passes from inside  43  to outside  44  (e.g., in a direction opposite that indicated by arrow A 1 ). 
     As noted hereinabove, the coating  41  of this disclosure is hydrophilic and oleophobic. In embodiments, the hydrophilic and oleophobic coating  41  includes graphene oxide. The natural tendency is for water to migrate through the hydrophilic and oleophobic coated substrate  40  (e.g., a graphene oxide coated membrane) with little or no differential pressure applied to the coated substrate  40  itself. Without limitation, such a graphene coated membrane technology is offered by G20 Water Technologies, Ltd., of Manchester UK. In embodiments, the contacting of the aqueous based fluid with the coated substrate  40  is effected at a differential pressure across the coated substrate  40  of less than or equal to about 10, 9, 8, 7, 6, or 5 psi. 
     According to this disclosure, the aqueous based wellbore servicing fluid from which water is removed by contact with the coated substrate  40  can include a drilling fluid, a produced water, a drill-in fluid, a packer fluid, a spacer fluid, a cleaner fluid, an acidizing fluid, a filter cake breaking fluid, a fracturing fluid, a lost circulation pill, a recovered brine, or a combination thereof. In embodiments, the aqueous based wellbore servicing fluid is an aqueous based wellbore servicing fluid that has been recovered from a wellbore  60  and/or a formation  64  (described hereinbelow with reference to the embodiment of  FIG. 2 ). Such an aqueous based fluid will be referred to herein as a “spent” aqueous based wellbore servicing fluid. As utilized herein a “spent” aqueous based fluid includes a produced water recovered from a formation  64  and a wellbore servicing (e.g., drilling) fluid that has been recovered from the wellbore  60  (e.g., circulated downward through a drill string  61  extending from the surface  65  into the wellbore  60 , out an end  66  of the drill string  61  (e.g., out a drill bit  63  connected to end  66  of the drill string  61 ), and upward through an annular space  62  formed between the drill string  61  and the wellbore  60 ). Although shown as pumped via end  66  of drill string  61  and through a drill bit  63  in the embodiment of  FIG. 2 , in embodiments the wellbore servicing fluid is pumped through a bottom hole assembly (BHA) located at end  66  of drill string  61 , and the BHA can include, for example, a by-pass sub, a MWD tool, a mud motor, a logging tool, etc. In such embodiments, component  63  can include such a BHA. 
     As depicted in  FIG. 2 , which is a schematic of a system I for recovering water from a water base drilling fluid, according to embodiments of this disclosure, aqueous based wellbore servicing fluid can be introduced into a water removal or recovery apparatus  30  via a line  25  (which can be a pump outlet line, in embodiments) containing therein the coated substrate  40  (e.g., graphene oxide coated membrane(s)). Pump  20  can be utilized to pump aqueous based wellbore servicing fluid from an aqueous based fluid source, which can be, for example, an aqueous based fluid storage unit  10  into water removal apparatus  30 . Pump  20  can be fluidly connected with aqueous based fluid storage unit  10  via pump inlet line  15  and fluidly connected with water removal apparatus  30  via pump outlet line  25 . Water removed via passage through the coated substrate  40  can be removed from water removal apparatus  30  via one or more water outlet line(s)  35 , and modified aqueous based fluid (e.g., aqueous based fluid from which water has been removed) can be removed from water removal apparatus  30  via one or more modified aqueous based fluid outlet (or “return”) line(s)  36 . 
     In embodiments, the water removed from the aqueous based wellbore servicing fluid by the contacting thereof with the coated substrate  40  and passage through the porous substrate  42  coated with the hydrophilic and oleophobic coating  41  is potable water. In embodiments, the water removed from the aqueous based wellbore servicing fluid and from water removal apparatus  30  via water outlet line(s)  35  is potable water having a total dissolved solids (TDS) content of less than or equal to about 5000, 4000, 3000, 2000, 1000, 750, or 500 ppm, a hydrocarbon content of less than or equal to about 500, 400, 300, 200, 100, 90, 80, 70, 60, 50, 40, 30, 20, or 10 mg/L, and/or a salt content of less than or equal to about 5000, 4000, 3000, 2000, 1000, 900, 800, 700, 600, 500, 400, 300, 200, or 100 ppm. In embodiments, the TDS is determined by water evaporation using a precision analytical balance. In embodiments, the TDS is estimated via a TDS meter that estimates the TDS from the electrical conductivity. In embodiments, the hydrocarbon content of the water removed via water outlet line(s)  35  is determined by 40 CFR Part 136 Method 608.3, 624.1, and/or 625.1. In embodiments, the conductivity is determined by measuring the electrical conductivity. 
     The ability of the herein disclosed system and method to remove potable water from aqueous based wellbore servicing fluids can provide advantages over conventional water removal techniques. For example, the conventional method of filtering to remove water generally allows salts, some degree of hydrocarbons, dissolved solids and the like to pass through the filter along with the removed water. Such filtered water is generally not potable, and can be hazardous, thus presenting challenges for disposal thereof. Via the herein disclosed systems and methods, an amount of hazardous waste material (e.g., hazardous water and/or solid or semi-solid waste) can be reduced relative to conventional systems and methods of removing water from (and thus increasing the density of) aqueous based wellbore servicing fluids. Additionally, conventional filtration generally utilizes higher pressures than the herein disclosed systems and methods to separate water from an aqueous based fluid. 
     As depicted in the embodiment of  FIG. 2 , the aqueous based wellbore servicing fluid introduced into water removal apparatus  30  via line  25  can be introduced from an aqueous based fluid storage unit  10  (also referred to as a “water storage unit  10 ”). In embodiments, water storage unit  10  can include, for example, a mud pit. As noted hereinabove, in embodiment, the aqueous based wellbore servicing fluid from which water is to be removed in water removal apparatus  30  can be an aqueous based wellbore servicing fluid that has been recovered from the wellbore  60  and/or the formation  64  prior to contact with the coated substrate  40  including porous substrate  42  coated with the hydrophilic and oleophobic coating  41 . For example, with reference to the embodiment of  FIG. 2 , in embodiments, an aqueous based wellbore servicing fluid is introduced into aqueous based fluid storage unit  10  via a pathway  70  fluidly connected with wellbore  60  extending from a surface of the earth  65  and penetrating subterranean formation  64 . Alternatively, in embodiments, an aqueous based wellbore servicing fluid is introduced directly into water removal apparatus  30  (e.g., without a water storage unit  10 ). In embodiments, the modified aqueous based wellbore servicing fluid from which water has been removed in water removal apparatus  30  is returned into the wellbore  60 , for example via pathway  75  from aqueous based fluid storage apparatus  10  or directly from water removal apparatus  30 . 
     In embodiments, the aqueous based wellbore servicing fluid includes a drilling fluid and the drilling fluid is circulated downward through a drill string  61  extending from the surface of the earth  65  into the wellbore  60  in formation  64 , out a drill bit  63  connected to an end  66  of the drill string  61 , and upward through an annular space  62  formed between the drill string  61  and the wellbore  60 . 
     In embodiments, after the removing of the water therefrom, the aqueous based wellbore servicing fluid (e.g., the modified aqueous based wellbore servicing fluid in modified aqueous based fluid outlet line(s)  36 ) has a target density. Aqueous based wellbore servicing fluids, such as drilling fluids, generally have target rheologies (e.g., densities) that are needed for providing a desired function. For example, without limitation, aqueous based drilling fluids may have a target density needed to lift drill cuttings away from a drill bit  63  during drilling operations. In embodiments, a method of this disclosure can further include adding a weighting material and/or water to the aqueous based wellbore servicing fluid, after the removing of the water therefrom, to attain the target density. For example, in the embodiment of  FIG. 2 , one or more water and or weighting agent inlet lines  55  can be fluidly attached to aqueous based fluid storage unit  10  and/or directly into water removal apparatus  30 , whereby water and/or weighting agent(s) can be introduced thereto. Any weighting material known to those of skill in the art can be added to the aqueous based wellbore servicing fluid or the modified aqueous based wellbore servicing fluid to increase the density thereof to reach the desired target density. Such a weighting agent includes, without limitation, barite. 
     In embodiments, an amount of water removed in water removal apparatus  30  and an amount of weighting agent (e.g., barite) added to the aqueous based fluid (e.g., the modified aqueous based fluid from which water has been removed in water removal apparatus  30 ) added are accurately controlled. In embodiments, the method is utilized as a constant volume method, whereby an amount of water removed from water removal apparatus  30  via water outlet line(s)  35  and an amount of weighting agent (e.g., barite) added to the aqueous based fluid (e.g., the modified aqueous based fluid from which water has been removed in water removal apparatus  30 ) are controlled such that an amount of water to be removed is calculated and the process run until a constant volume of aqueous based fluid in aqueous based fluid storage unit  10  is achieved. After removing the water from the aqueous based wellbore servicing fluid in water removal apparatus  30 , a predetermined amount of weighting agent (e.g., barite) can be added to the system (e.g., to water removal apparatus  30 , modified aqueous based fluid outlet line  36 , and/or aqueous based fluid storage unit  10 ) to complete the density increase to the target density. 
       FIG. 3  is a schematic of another system II for recovering water from a water base drilling fluid, according to embodiments of this disclosure. The embodiment of  FIG. 3  is the same as that of  FIG. 2 , except a water or weighting material inlet line  55  is not utilized for introducing a weighting material (e.g., barite) into aqueous based fluid storage unit  10 . Via the system II, a fluid volume in the system can decrease as water is removed from the aqueous based wellbore servicing fluid via water removal apparatus  30 . 
     Water removal apparatus  30  can have a variety of configurations, so long as water can removed therein via contacting of the aqueous based fluid introduced thereto with a coated substrate  40 , as described herein, and water (e.g., that passes through the coated substrate(s)  40 ) and the water-reduced modified aqueous based fluid (e.g., the aqueous based fluid from which the water has been removed) can be removed therefrom. For example, in embodiments, system I of  FIG. 2  or system II of  FIG. 3  includes a water removal apparatus  30  as depicted in  FIG. 4 , which is a schematic of a water removal apparatus  30  according to embodiments of this disclosure. Water removal apparatus  30  of  FIG. 4  includes a coated substrate  40  having a cylindrical or tube shaped porous substrate  42  coated with hydrophilic and oleophobic coating  41 . In the embodiment of  FIG. 4 , porous cylindrical substrate  42  is coated on an outside thereof with the coating  41 . In this embodiment, coated cylindrical substrate  40  defines an inside  43  or “removed water flow section”  43  inside cylindrical porous substrate  42 , and an outside  44  or “aqueous based fluid flow section”  44  between coating  41  and wall (e.g., outer wall)  37 . The outer wall  37  and the coated substrate  40  can, in such embodiments, include concentric tubes or cylinders defining outside  44  of coated substrate tube  40  and inside  43  of coated substrate tube  40 . In this embodiment, hydrophilic and oleophobic coating  41  of coated substrate tube  40  attracts water from aqueous based fluid introduced into the aqueous based fluid flow section or outside  44  (e.g., via an inlet line connected therewith, which can, in embodiments, be a pump outlet line(s)  25 ), which water passes through cylindrical coated substrate  40  to the inside  43  of cylindrical coated substrate  40  which serves, in this arrangement, as a removed water flow section  43 . Accordingly, in the embodiment of  FIG. 4 , water flows from outside  44  to inside  43  of cylindrical coated substrate  40  in the direction indicated by arrow A 1 . In such embodiments, an aqueous based fluid inlet line(s) (e.g., a pump outlet line(s)  25 ) can be fluidly connected with and introduce aqueous based fluid into outside  44  of coated substrate  40 , while a removed water outlet line(s)  35  can be fluidly connected with and remove water from inside  44  of coated substrate  40 . 
     In alternative embodiments, the hydrophilic and oleophobic coating  41  of a cylindrical coated substrate  40  is coated on the inside surface of porous substrate  42 , in which embodiments, inside  43  of cylindrical coated substrate  40  can provide the aqueous based fluid flow section, and outside  44  of cylindrical coated substrate  40  can provide the removed water flow section. In such embodiments, water from the aqueous based fluid introduced into inside  43  (e.g., via an inlet line connected therewith, which can, in embodiments, be a pump outlet line(s)  25 ) can flow from inside  43  to outside  44 , in a direction opposite to that indicated by arrow A 1  in  FIG. 4 . In such embodiments, an aqueous based fluid inlet line (e.g., a pump outlet line(s)  25 ) can be fluidly connected with and introduce aqueous based fluid into inside  43  of coated substrate  40 , while a removed water outlet line(s) can be fluidly connected with and remove water from outside  44  of coated substrate  40 . In embodiments, a water removal apparatus  30  of this disclosure includes a plurality of cylindrical coated substrates  40 , with associated water inlet lines (e.g., pump outlet lines  25 ), removed water outlet lines  35 , and insides  43  and outsides  44  (which can provide aqueous based fluid flow sections and/or removed water flow sections). 
       FIG. 5A  is a schematic of another system III for recovering water from a water base fluid, according to embodiments of this disclosure. Water removal apparatus  30  (shown in side view cross section in  FIG. 5A ) can have one or more layers or “beds” of coated substrate, with two layers of coated substrate  40 , first coated substrate layer  40 A and second coated substrate layer  40 B, depicted in the embodiment of  FIG. 5A . In such embodiments, aqueous based fluid can be introduced (e.g., from aqueous based fluid source  10 , pump inlet line  15 , pump  20 , and pump outlet line  25 ) into one or more aqueous based fluid flow sections  26  of water removal apparatus  30  and water that passes from the aqueous based fluid, through the coated substrate layers  40 A,  40 B can be removed via one or more removed water flow sections  27 . The aqueous based fluid flow sections  26  provide contact of the aqueous based fluid introduced into water removal apparatus  30  with the coating  41  of first coated substrate layer  40 A and second coated substrate layer  40 B. The removed water sections  27  provide a flow path for water that passes through first coated substrate layer  40 A and second coated substrate layer  40 B, on a side of substrate  42  opposite the coating  41 . One aqueous based fluid flow section  26  and two removed water flow sections, including first water flow section  27 A and second water flow section  27 B, are depicted in the embodiment of  FIG. 5A .  FIG. 5B  shows a front view cross section of the water removal apparatus  30  of  FIG. 5A . A water removal apparatus  30  can include any number of coated substrates  40  (e.g., coated substrate layers, such as first coated substrate layer  40 A and second coated substrate layer  40 B of the embodiment of  FIGS. 5A and 5B ), aqueous based fluid flow sections  26 , and removed water flow sections  27  (e.g., the single aqueous based fluid flow section  26  and two water flow sections including first water flow section  27 A and second water flow section  27 B shown in the embodiment of  FIG. 5A  and  FIG. 5B ). 
       FIG. 6A  is a schematic of another system IV for recovering water from a water base fluid, according to embodiments of this disclosure.  FIG. 6B  is a front cross section view of water removal apparatus  30  of the embodiment of  FIG. 6A . Water removal apparatus  30  (shown in side view cross section in  FIG. 6A ) can include one or more cylindrical tubes (e.g., cylinders) of coated substrate (e.g., cylindrical coated membranes), with two, first cylindrical coated substrate  40 A and second cylindrical coated substrate  40 B) depicted in the embodiment of  FIG. 6A  and eight (first through eighth cylindrical coated substrates  40 A- 40 H) depicted in the embodiment of  FIG. 6B . In this embodiment, aqueous based fluid can be introduced from aqueous based fluid source  10 , pump inlet line  15 , pump  20 , and pump outlet line  25  into one or more aqueous based fluid flow sections  26  of water removal apparatus  30  and water that passes from the aqueous based fluid, through the coating  41  of first cylindrical coated substrate  40 A and water that passes from the aqueous based fluid through the coating  41  of the second cylindrical coated substrate  40 B, and so on, can be removed via one or more removed water flow sections  27 . Two removed water flow sections, first removed water flow section  27 A and second removed water flow section  27 B, are depicted in the embodiment of  FIG. 6A . In this embodiment, outsides  44  of the coated substrates  40  (e.g., outsides  44  of first cylindrical coated substrate  40 A and second cylindrical coated substrate  40 B, and so on) provide the aqueous based fluid flow sections  26 , while insides  43  of the coated substrates  40  (e.g., insides  43  of first cylindrical coated substrate  40 A and second cylindrical coated substrate  40 B) provide the removed water flow sections  27  (e.g., first removed water flow section  27 A inside first cylindrical coated substrate  40 A and second removed water flow section  27 B inside second cylindrical coated substrate  40 B, and so on).  FIG. 6B  shows a front cross section view of the water removal apparatus  30  of  FIG. 6A  including eight coated substrates  40 A- 40 H with associated insides  43  providing water flow sections  27 A- 27 H and outsides  44  providing water flow section  26 . A water removal apparatus  30  can include any number of coated substrates  40 . For example, a water removal apparatus can include one or a plurality of coated substrates  40 . In embodiments, a water removal apparatus  30  of this disclosure includes from 1 to 50, from 1 to 20, from 10 to 50, from 2 to 100, or more coated substrates  40 . 
     A water removal apparatus  30  can include any number of coated substrates  40  (e.g., cylindrical coated substrates or coated tubes, such as first cylindrical coated substrate  40 A and second cylindrical coated substrate  40 B, and so on, of the embodiment of  FIGS. 6A and 6B ), aqueous based fluid flow sections  26 , and removed water flow sections  27 . An aqueous based fluid inlet line, such as pump outlet line  25 , can be utilized to introduce the aqueous based fluid into aqueous based fluid flow section(s)  26 , a removed water outlet line  35  can be utilized to remove water from each of the removed water flow sections  27 , and a modified aqueous based fluid outlet line  36  can be utilized to remove modified (e.g., water-reduced) aqueous based fluid from the aqueous based fluid flow section(s)  26  (e.g., at an end thereof). For example, in the embodiment of  FIG. 5A  and  FIG. 5B , pump outlet line  25  can be utilized to introduce aqueous based fluid into aqueous based fluid flow section  26 , modified aqueous based fluid outlet line  36  can be utilized to remove modified aqueous based fluid from aqueous based fluid flow section  26  (e.g., at an opposite end thereof from the aqueous based fluid inlet at pump outlet  25 ), and first removed water outlet line  35 A and second removed water outlet line  35 B can be utilized to remove water from first removed water flow section  26 A and second removed water flow section  26 B, respectively. First removed water outlet line  35 A and second removed water outlet line  35 B can be manifolded into removed water outlet line  35 , in embodiments. In the embodiment of FIG.  6 A and  FIG. 6B , pump outlet line  25  and one or more aqueous based fluid inlet lines (e.g., first aqueous based fluid inlet line  25 A, second aqueous based fluid inlet line  25 B, and third aqueous based fluid inlet line  25 C depicted in  FIG. 6A ) can be utilized to introduce aqueous based fluid into aqueous based fluid flow section(s)  26 , first modified aqueous based fluid outlet line  36 A, second modified aqueous based fluid outlet line  36 B, and third aqueous based fluid outlet line  36 C, and so on, can be utilized to remove modified aqueous based fluid from aqueous based fluid flow section(s)  26  (e.g., at an opposite end thereof from the aqueous based fluid inlet at aqueous based fluid inlets  25 ), and first removed water outlet line  35 A and second removed water outlet line  35 B, and so on, can be utilized to remove water from first removed water flow section  27 A and second removed water flow section  27 B, and so on, respectively. The one or more modified aqueous based fluid outlet lines  36  (e.g., first modified aqueous based fluid outlet line  36 A, second modified aqueous based fluid outlet line  36 B, third modified aqueous based fluid outlet line  36 C, and so on) can be manifolded into modified aqueous based fluid outlet line  36 , in embodiments. Similarly, the one or more removed water outlet lines  35  (e.g., first removed water outlet line  35 A and second removed water outlet line  35 B, and so on) can be manifolded into removed water outlet line  35 , in embodiments. 
     One or more contaminated aqueous stream lines  25  can be utilized to introduce contaminated aqueous based fluid into each contaminated aqueous based fluid flow section  26 . One or more modified aqueous based fluid outlet lines  36  can be utilized to remove modified aqueous based fluid from each contaminated aqueous based fluid flow section  26 . One or more removed water outlet lines  35  can be utilized to removed treated water from each removed water flow section  27 . 
     Although aqueous based fluid flow section  26  of the embodiment of  FIG. 6A  and  FIG. 6B  is shown as a continuous section in  FIG. 6B  (i.e., because coated substrates  40  are depicted as not touching), in embodiments, coated substrate tubes (e.g., first cylindrical coated substrate  40 A, second cylindrical coated substrate  40 B, etc.) can be in contact with neighboring coated substrate tubes, and a plurality of aqueous based fluid inlet flow lines, e.g., aqueous based inlet flow lines  25 A,  25 B,  25 C, and so on) can be utilized to introduce the aqueous based fluid into disparate aqueous based fluid flow sections  26  of a water removal apparatus  30 , in embodiments. 
     In the embodiment of  FIG. 6A  and  FIG. 6B , water removal apparatus  30  is designed in a similar manner as a heat exchanger, wherein the coated substrate tubes  40  of the water removal apparatus  30  separate the flow of aqueous based fluid and the removed water that passes through the coating  41  (e.g., coated walls) and substrates  42  of the coated substrate tubes  40  the way the heat exchange tubes of a heat exchanger separate a heat exchanger fluid from a process fluid and heat passes through the walls of the heat exchanger tubes. The inside and the outside of the tubes act as the aqueous based fluid flow sections  26  and the removed water flow sections  27 , respectively, or vice versa. 
     A plethora of configurations of the coated substrate  40  (e.g., layers or sheets, as depicted in the embodiments of  FIGS. 5A and 5B , tubes or cylinders, as depicted in the embodiments of  FIGS. 6A and 6B ) are possible, and within the scope of this disclosure. For example, by way of further nonlimiting example, in alternative embodiments, the porous substrate  42  includes hollow particulates, and the particulate substrate is coated with the hydrophilic and oleophobic coating  41  to provide a coated substrate  40  including coated particulates. In such embodiments, water removal apparatus  30  can include a bed, layer, or containment of such coated particulates. In such embodiments, aqueous based fluid introduced into water removal apparatus  30 , for example via an aqueous based fluid inlet line such as pump outlet line  25  contacts the particulates of coated substrate  40 , water passes through the hydrophilic and oleophobic coating  41  of the coated particulates, and enters a hollow core, center, or region of the particulates. In such embodiments, the coated particulates having removed water sequestered therein can be regenerated (i.e., water removed therefrom), and be reused in water removal apparatus  30 . Regeneration can include heating, pressing, or the like to remove the water from the spent coated substrate particulates prior to re-use. 
     In embodiments, a method of this disclosure further includes cycling the coated porous substrate  40 / 40 A- 40 H through a backwash to clean an upstream surface thereof. Such cycling can be effected continuously, in embodiments. 
     Via the system and method of this disclosure, the aqueous based fluids (e.g., aqueous based drilling fluids in a mud plant) can be recycled several times through various density ranges. The density of the aqueous based wellbore servicing fluid in aqueous based wellbore servicing storage tank  10  can be alternately increased and decreased, as needed. The density of the aqueous based wellbore servicing fluid in aqueous based wellbore servicing fluid storage unit  10  can be increased by increasing an amount of water removed from the aqueous based wellbore servicing fluid in water removal apparatus  30  by increasing an amount of the aqueous based fluid introduced into water removal apparatus  30  via pump outlet line(s)  25 , and/or an amount of modified aqueous based wellbore servicing fluid removed from water removal apparatus  30  (and returned to aqueous based fluid storage unit  10 ) via water reduced aqueous based fluid outlet line(s)  36 ), and/or by increasing an amount of weighting agent and/or decreasing an amount of water introduced into aqueous based wellbore servicing fluid storage unit  10  (and/or directly into water reduced aqueous based fluid outlet line(s)  36  and/or into water removal apparatus  30 ). 
     The density of the aqueous based wellbore servicing fluid in aqueous based wellbore servicing fluid storage unit  10  can be reduced by decreasing an amount of water removed from the aqueous based wellbore servicing fluid in water removal apparatus  30  by decreasing an amount of the aqueous based fluid introduced into water removal apparatus  30  via pump inlet line(s)  15 , pump(s)  20 , and pump outlet line  25 ( s ), and/or an amount of modified aqueous based wellbore servicing fluid removed from water removal apparatus  30  (and returned to aqueous based fluid storage unit  20 ) via modified aqueous based fluid outlet line(s)  36 ), and/or reducing an amount of weighting agent and/or increasing an amount of water introduced into aqueous based fluid storage unit  10  (and/or directly into modified aqueous based fluid outlet line  36  and/or into water removal apparatus  30 ). 
     In embodiments, the aqueous based wellbore servicing fluid includes an aqueous based drilling fluid, and a method of servicing a wellbore  60  extending from a surface of the earth  65  and penetrating a subterranean formation  64 , includes: removing water (e.g., via water outlet line(s)  35 ) from the aqueous based drilling fluid by contacting the aqueous based drilling fluid (e.g., in water removal apparatus  30  after introduction thereto via pump inlet line  15 , pump  20 , and/or pump outlet line  25 ) with a coated substrate  40  including a porous substrate  42  coated with a hydrophilic and oleophobic coating  41 , whereby water is removed (e.g., via removed water outlet line(s)  35 ) from the aqueous based drilling fluid via passage through the coated substrate  40  having the porous substrate  42  coated with the hydrophilic and oleophobic coating  41 , whereby a water concentration and a volume of the aqueous based drilling fluid are reduced and a density of the aqueous based wellbore servicing fluid is increased; and optionally adding a weighting material and/or water (e.g., via one or more water and/or weighting agent inlet lines  55 ) to the aqueous based drilling fluid after the removing of the water therefrom (e.g., added directly to water removal apparatus  30 , water reduced, modified aqueous based wellbore servicing fluid outlet line(s)  36 , and/or aqueous based wellbore servicing fluid storage unit  10 , or a combination thereof). 
     In embodiments, the method further includes maintaining a substantially constant volume of the aqueous based drilling fluid in a mud pit (utilized as aqueous based fluid storage unit  10 ) containing same by controlling an amount of the water removed by the contacting of the aqueous based drilling fluid with the coated substrate  40  and an amount of the weighting material and/or the water optionally added to the aqueous based drilling fluid after the removing of the water therefrom. 
     As noted hereinabove, in embodiments aqueous based source  10  includes an aqueous based storage unit  10 . For example, in embodiments, the aqueous based fluid is an aqueous based drilling fluid, and the aqueous based drilling fluid is stored, prior to and/or after the removing of the water therefrom, in a mud pit  10 . In such embodiments, a weighting material can be added (e.g., via water and/or weighting agent inlet line(s)  55 ) to the mud pit  10  containing the aqueous based drilling fluid to increase the fluid density, as described hereinabove with reference to the embodiment of  FIG. 2 . Alternatively, the source of the aqueous based fluid includes the wellbore  60  (e.g., aqueous based fluid is introduced directly from wellbore  60  into water removal apparatus  30 ). As noted hereinabove, in embodiments, the aqueous based drilling fluid is recovered from the wellbore  60  prior to contact with the coated substrate  40  and the aqueous based wellbore drilling fluid is returned into the wellbore  60  after contact with the coated substrate  40 . 
     In embodiments, a method of servicing a wellbore  60  extending from a surface of the earth  65  and penetrating a subterranean formation  64  according to this disclosure includes: circulating an aqueous based wellbore servicing fluid from the surface  65 , into the wellbore  60 , and back to the surface  65 ; and maintaining a desired density of the aqueous based wellbore servicing fluid by: removing water from the aqueous based wellbore servicing fluid by contacting the aqueous based wellbore servicing fluid with a coated substrate  40  having a porous substrate  42  coated with a hydrophilic and oleophobic coating  41 , whereby water is removed from the aqueous based wellbore servicing fluid via passage through the coated substrate  40 , and whereby a water concentration and a volume of the aqueous based wellbore servicing fluid are reduced and a density of the aqueous based wellbore servicing fluid is increased; and optionally adding a weighting material and/or water (e.g., to aqueous based fluid source or storage unit  10  via one or more water and/or weighting agent inlet line(s))  55 ) to the aqueous based wellbore servicing fluid after the removing of the water therefrom (e.g., via removed water outlet line(s)  35 ). In some specific embodiments, as noted above, the hydrophilic and oleophobic coating  41  includes graphene oxide. In some such embodiments, the aqueous based wellbore servicing fluid is an aqueous based drilling fluid, and a water content of the aqueous based drilling fluid increases as it circulated from the surface  65 , into the wellbore  60 , and back to the surface  65 . 
     In embodiments, a method of servicing a wellbore  60  extending from a surface of the earth  65  and penetrating a subterranean formation  64  according to this disclosure includes: recovering a spent fluid from the wellbore  60 ; forming a concentrated composition by removing a portion of the water from the spent fluid recovered from the wellbore  60 , wherein the portion of the water is removed by contacting the spent fluid with a coated substrate  40  including a porous substrate  42  coated with a hydrophilic and oleophobic coating  41 , as described herein, whereby water is removed (e.g., via water removal line(s)  35 ) from the spent fluid via passage through the coated substrate  40  to provide the concentrated composition. In embodiments, the concentrated composition has a water concentration and a volume that are less than a water concentration and a volume of the spent fluid, respectively, and a density that is greater than a density of the spent fluid. The method can further include disposing of the concentrated composition at a location proximate the wellbore  60  and/or transporting the concentrated composition to a location remote from the wellbore  60  and disposing thereof. In some such embodiments, the spent fluid includes a spent aqueous based wellbore servicing fluid. In embodiments, the spent aqueous based wellbore servicing fluid includes a spent aqueous based drilling fluid. In embodiments, the spent fluid includes produced water. 
     In embodiments, the volume of the concentrated composition is at least 5, 10, 20, 30, or 40 percent less than a volume of the spent aqueous based wellbore servicing fluid recovered from the wellbore  60 . As described hereinabove, in embodiments, the water removed from the spent fluid via the passage through the porous substrate  42  (of coated substrate  40 ) is potable water. 
     The method can further include utilizing the water that is removed from the spent fluid via the passage through the coated substrate  40  (e.g., and removed from water removal apparatus  30  via removed water outlet line(s)  35 ) onsite or offsite as drinking water, wash water, irrigation water, cooling water, a component of an aqueous containing wellbore servicing fluid (e.g., an aqueous based or oil based wellbore servicing fluid), or a combination thereof. The water removal can be effected as detailed hereinabove. For example, in embodiments, the hydrophilic and oleophobic coating  41  utilized in this method includes graphene oxide. 
     Those of ordinary skill in the art will readily appreciate various benefits that may be realized by the present disclosure. For instance, in embodiments, the herein disclosed system and method enable real time adjustment of the water content of an aqueous based wellbore servicing fluid, whereby a density thereof can be adjusted to reach a target density. The herein disclosed system and method also enable the removal of water from an aqueous based wellbore servicing fluid whereby a volume of the aqueous based wellbore servicing fluid can be decreased and maintained at a desired constant volume and/or kept below a maximum desired amount (e.g., a maximum aqueous based fluid storage capacity or volume of an aqueous base fluid storage unit  10 , such as. for example, a mud pit). In embodiments, via the herein disclosed system and method, potable water can be produced from aqueous based wellbore servicing fluids, and the potable water utilized onsite (e.g., for drinking water, wash water, irrigation water, cooling water, a component of a new aqueous containing wellbore servicing fluid (e.g., an aqueous based or oil based wellbore servicing fluid), or a combination thereof) and/or sent off site. In embodiments, the removal of water from aqueous based wellbore servicing fluids as per this disclosure can result in a reduced amount of hazardous or un-environmentally friendly materials (liquids and/or solids or semi-solids) for which permits and/or further treatment are required for disposal. 
     Additional Disclosure 
     The following are non-limiting, specific embodiments in accordance with the present disclosure: 
     Embodiment A: A method of servicing a wellbore extending from a surface of the earth and penetrating a subterranean formation, comprising: removing water from an aqueous based wellbore servicing fluid by contacting the aqueous based wellbore servicing fluid with a porous substrate coated with a hydrophilic and oleophobic coating, whereby water is removed from the aqueous based wellbore servicing fluid via passage through the porous substrate, and whereby a water concentration and a volume of the aqueous based wellbore servicing fluid are reduced and a density of the aqueous based wellbore servicing fluid is increased to provide a modified aqueous based wellbore servicing fluid. 
     Embodiment B: The method of Embodiment A, wherein the hydrophilic and oleophobic coating comprises graphene oxide. 
     Embodiment C: The method of Embodiment A or Embodiment B, wherein the aqueous based wellbore servicing fluid is a drilling fluid. 
     Embodiment D: The method of any of Embodiment A through Embodiment C, wherein the aqueous based wellbore servicing fluid is recovered from the wellbore prior to contact with the porous substrate and wherein the modified aqueous based wellbore servicing fluid is returned into the wellbore. 
     Embodiment E: The method of any of Embodiment A through Embodiment D, wherein the porous substrate comprises a membrane, a particulate, a tube, or a combination thereof. 
     Embodiment F: The method of any of Embodiment A through Embodiment E, wherein the porous substrate comprises a polymer, a ceramic, a zeolite, a molecular sieve, or a combination thereof. 
     Embodiment G: The method of any of Embodiment A through Embodiment F, wherein the contacting is effected at a differential pressure across the coated porous substrate of less than or equal to about 10, 9, 8, 7, 6, or 5 psi. 
     Embodiment H: The method of any of Embodiment A through Embodiment G, wherein the water removed via passage through the porous substrate coated with the hydrophilic and oleophobic coating is potable water. 
     Embodiment I: The method of Embodiment H, wherein the potable water comprises a total dissolved solids (TDS) content, as measured by conductivity and/or water evaporation, of less than or equal to about 5000, 4000, 3000, 2000, 1000, 750, or 500 ppm, a hydrocarbon content, as measured by 40 CFR Part 136 Method 608.3, 624.1, and/or 625.1, of less than or equal to about 500, 400, 300, 200, 100, 90, 80, 70, 60, 50, 40, 30, 20, or 10 mg/L, and/or a salt content, as measured by electrical conductivity, of less than or equal to about 5000, 4000, 3000, 2000, 1000, 900, 800, 700, 600, 500, 400, 300, 200, or 100 ppm. 
     Embodiment J: The method of any of Embodiment A through Embodiment I, wherein, after the removing of the water therefrom, the aqueous based wellbore servicing fluid has a target density. 
     Embodiment K: The method of any of Embodiment A through Embodiment J further comprising adding a weighting material and/or water to the aqueous based wellbore servicing fluid, after the removing of the water therefrom, to attain a target density. 
     Embodiment L: A method of servicing a wellbore extending from a surface of the earth and penetrating a subterranean formation, the method comprising: removing water from the aqueous based drilling fluid by contacting the aqueous based drilling fluid with a porous substrate coated with a hydrophilic and oleophobic coating, whereby water is removed from the aqueous based drilling fluid via passage through the porous substrate, and whereby a water concentration and a volume of the aqueous based drilling fluid are reduced and a density of the aqueous based wellbore servicing fluid is increased; and optionally adding a weighting material and/or water to the aqueous based drilling fluid after the removing of the water therefrom. 
     Embodiment M: The method of Embodiment L further comprising maintaining a substantially constant volume of the aqueous based drilling fluid in a mud pit containing same by controlling an amount of the water removed by the contacting of the aqueous based drilling fluid with the porous substrate and an amount of the weighting material and/or the water optionally added to the aqueous based drilling fluid after the removing of the water therefrom. 
     Embodiment N: The method of Embodiment M, wherein the aqueous based drilling fluid is stored, prior to and/or after the removing of the water therefrom, in a mud pit, and/or wherein the weighting material is added to a mud pit containing the aqueous based drilling fluid. 
     Embodiment O: The method of any of Embodiment L through Embodiment N, wherein the aqueous based drilling fluid is recovered from the wellbore prior to contact with the porous substrate and wherein the aqueous based wellbore drilling fluid is returned into the wellbore after contact with the porous substrate. 
     Embodiment P: The method of Embodiment O, wherein the drilling fluid is circulated downward through a drill string extending from the surface into the wellbore, out a bottom hole assembly (BHA) connected to an end of the drill string, and upward through an annular space formed between the drill string and the wellbore. 
     Embodiment Q: A method of servicing a wellbore extending from a surface of the earth and penetrating a subterranean formation, the method comprising: circulating an aqueous based wellbore servicing fluid from the surface, into the wellbore, and back to the surface; and maintaining a desired density of the aqueous based wellbore servicing fluid by: removing water from the aqueous based wellbore servicing fluid by contacting the aqueous based wellbore servicing fluid with a porous substrate coated with a hydrophilic and oleophobic coating, whereby water is removed from the aqueous based wellbore servicing fluid via passage through the porous substrate, and whereby a water concentration and a volume of the aqueous based wellbore servicing fluid are reduced and a density of the aqueous based wellbore servicing fluid is increased; and optionally adding a weighting material and/or water to the aqueous based wellbore servicing fluid after the removing of the water therefrom. 
     Embodiment R: The method of Embodiment Q, wherein the hydrophilic and oleophobic coating comprises graphene oxide. 
     Embodiment S: The method of Embodiment Q or Embodiment R, wherein the aqueous based wellbore servicing fluid is an aqueous based drilling fluid, and wherein a water content of the aqueous based drilling fluid increases as it circulated from the surface, into the wellbore, and back to the surface. 
     Embodiment T: A method of servicing a wellbore extending from a surface of the earth and penetrating a subterranean formation, comprising: recovering a spent fluid from the wellbore; forming a concentrated composition by removing a portion of the water from the spent fluid recovered from the wellbore, wherein the portion of the water is removed by contacting the spent fluid with a porous substrate coated with a hydrophilic and oleophobic coating, whereby water is removed from the spent fluid via passage through the porous substrate to provide the concentrated composition, wherein the concentrated composition has a water concentration and a volume that are less than a water concentration and a volume of the spent fluid, respectively, and a density that is greater than a density of the spent fluid; and disposing of the concentrated composition at a location proximate the wellbore, transporting the concentrated composition to a location remote from the wellbore and disposing thereof, or disposing of a first portion of the concentrated composition at a location proximate the wellbore and transporting a second portion of the concentrated composition to a location remote from the wellbore and disposing thereof. 
     Embodiment U: The method of Embodiment T, wherein the volume of the concentrated composition is at least 5, 10, 20, 30, or 40 percent less than a volume of the spent aqueous based wellbore servicing fluid recovered from the wellbore. 
     Embodiment V: The method of Embodiment T or Embodiment U, wherein the spent fluid comprises a spent aqueous based wellbore servicing fluid. 
     Embodiment W: The method of any of Embodiment T through Embodiment V, wherein the spent aqueous containing wellbore servicing fluid comprises a spent aqueous based drilling fluid. 
     Embodiment X: The method of any of Embodiment T through Embodiment W, wherein the spent fluid comprises produced water. 
     Embodiment Y: The method of any of Embodiment T through Embodiment X, wherein the water removed from the spent fluid via the passage through the porous substrate is potable water. 
     Embodiment Z1: The method of any of Embodiment T through Embodiment Y further comprising utilizing the water that is removed from the spent fluid via the passage through the porous substrate onsite or offsite as drinking water, a component of an aqueous based wellbore servicing fluid, or a combination thereof. 
     Embodiment Z2: The method of any of Embodiment T through Embodiment Z1, wherein the hydrophilic and oleophobic coating comprises graphene oxide. 
     While embodiments have been shown and described, modifications thereof can be made by one skilled in the art without departing from the spirit and teachings of this disclosure. The embodiments described herein are exemplary only, and are not intended to be limiting. Many variations and modifications of the embodiments disclosed herein are possible and are within the scope of this disclosure. Where numerical ranges or limitations are expressly stated, such express ranges or limitations should be understood to include iterative ranges or limitations of like magnitude falling within the expressly stated ranges or limitations (e.g., from about 1 to about 10 includes, 2, 3, 4, etc.; greater than 0.10 includes 0.11, 0.12, 0.13, etc.). For example, whenever a numerical range with a lower limit, Rl, and an upper limit, Ru, is disclosed, any number falling within the range is specifically disclosed. In particular, the following numbers within the range are specifically disclosed: R=Rl+k*(Ru−Rl), wherein k is a variable ranging from 1 percent to 100 percent with a 1 percent increment, i.e., k is 1 percent, 2 percent, 3 percent, 4 percent, 5 percent, . . . 50 percent, 51 percent, 52 percent, . . . , 95 percent, 96 percent, 97 percent, 98 percent, 99 percent, or 100 percent. Moreover, any numerical range defined by two R numbers as defined in the above is also specifically disclosed. Use of the term “optionally” with respect to any element of a claim is intended to mean that the subject element is required, or alternatively, is not required. Both alternatives are intended to be within the scope of the claim. Use of broader terms such as comprises, includes, having, etc. should be understood to provide support for narrower terms such as consisting of, consisting essentially of, comprised substantially of, etc. 
     Accordingly, the scope of protection is not limited by the description set out above but is only limited by the claims which follow, that scope including all equivalents of the subject matter of the claims. Each and every claim is incorporated into the specification as an embodiment of the present disclosure. Thus, the claims are a further description and are an addition to the embodiments of the present disclosure. The discussion of a reference herein is not an admission that it is prior art, especially any reference that may have a publication date after the priority date of this application. The disclosures of all patents, patent applications, and publications cited herein are hereby incorporated by reference, to the extent that they provide exemplary, procedural, or other details supplementary to those set forth herein.