WELL DRILLING COMPOSITIONS.

Abstract

Drilling mud compositions are described that include a first concentration of powdered latex and a second concentration of SAS. The second concentration of SAS may be greater than or equal to the first concentration of latex. In some examples, the second concentration of SAS may be greater than the first concentration of latex. Drilling mud compositions may include an oil-based or a water-based carrier. One example technique involves dispersing a predetermined first amount of powdered latex and a predetermined second amount of SAS in a water-based carrier to form a water-based mud. Another example technique involves dispersing a predetermined first amount of powdered latex and a predetermined second amount of SAS in an oil-based carrier to form an oil-based mud.

Description

This application claims priority to and benefit from U.S. Provisional Patent Application No. 62 / 778,363, filed December 12, 2018, which is incorporated herein by reference in its entirety. TECHNICAL FIELD OF THE INVENTION This disclosure relates to drilling compositions, for example, compositions used for drilling natural resource wells. BACKGROUND OF THE INVENTION Wells can be drilled to extract natural resources such as oil, gas, or water. A well is surrounded by a formation, such as shale or clay, which can influence the stability of the wellbore. For example, the formation may exert pressure on the wellbore, or fluids from the formation may enter the wellbore. A formation may include permeable regions, and fluids introduced into the wellbore may enter the permeable regions, resulting in fluid loss. Such fluid loss can affect drilling efficiency, require the replacement of drilling fluids, and affect formation stability. Drilling compositions, such as drilling fluids or drilling muds, can be used to facilitate well drilling. The drilling fluid or mud can be distributed and circulated along a wellbore to provide functions such as cooling and lubricating drilling equipment, or to remove cuttings and clean the wellbore. In addition to performing these functions, drilling compositions can also help promote formation stability. BRIEF DESCRIPTION OF THE INVENTION This brief description is provided to introduce various concepts in a simplified manner, which are further described in the detailed description below. This brief description is not intended to identify necessary or essential features of the claimed subject matter, nor is it intended to limit the scope of the claimed subject matter. In aspects, this disclosure describes drilling mud compositions. The drilling mud compositions can be used in well drilling processes, for example, to form oil wells. In one aspect, sodium asphalt sulfonate (SAS), an asphalt salt, can be used to control fluid loss and lubricity of the wells. Lrn / nn / L7n7 / E / YiAi drilling mud compositions. In addition, SAS can seal shale microfractures, which can provide formation stability. Powder latex has been found to exhibit synergistic effects when combined with SAS, for example, rather than additive effects, and this combination promotes fluid loss control and formation lubricity and stability. For example, the addition of powder latex and SAS to drilling mud compositions provides relatively higher lubricity, lower fluid loss, and better sealing of shale microfractures and formation stability than the use of similar concentrations of SAS or powder latex alone. In some aspects, synergistic effects are promoted by using a concentration of SAS greater than or equal to that of the latex. In one aspect, this disclosure describes a drilling mud composition that includes a first concentration of powdered latex and a second concentration of SAS. The second concentration of SAS (by mass, e.g., lbm / bbl) may be greater than or equal to the first concentration of latex (by mass, e.g., lbm / bbl). In some embodiments, the second concentration of SAS (by mass) may be greater than the first concentration of latex (by mass). This brief description and the following detailed description provide examples and are intended solely for the purpose of explaining the disclosure. Accordingly, the foregoing brief description and the following detailed description should not be construed as restrictive in nature. Additional features or variations thereof may be provided beyond those set forth herein, for example, various combinations of features and subcombinations thereof described in the detailed description. BRIEF DESCRIPTION OF THE DRAWINGS Figure 1 is a graph illustrating the decrease in high temperature, high pressure (HTHP) fluid loss at 250°F for a water-based drilling mud composition that includes both sodium asphalt sulfonate (SAS) and powdered latex relative to compositions that do not include one or both of SAS or latex. Figure 2 is a graph illustrating the decrease in permeability plugging test (PPT) fluid loss at 250°F for water-based drilling mud compositions that include both SAS and powder latex and that have a higher mass concentration of SAS than powder latex relative to compositions that do not include one or both of SAS or latex. Figure 3 is a graph illustrating the decrease in PPT fluid loss at 325°F for water-based drilling mud compositions that include both SAS and powder latex and that have a higher mass concentration of SAS than powder latex relative to compositions that do not include one or both of SAS or latex. Figure 4 is a graph illustrating PPT fluid loss at 325°F for water-based drilling mud compositions that include both SAS and powder latex and that have a higher mass concentration of SAS than powder latex relative to compositions that do not include one or both of SAS or latex. Figure 5 is a graph illustrating the decrease in PPT fluid loss over time for water-based drilling mud compositions that include both SAS and powder latex and have a higher mass concentration of SAS than powder latex relative to compositions that do not include SAS or latex at different temperatures (250°F, 275°F, and 300°F). Figure 6 is a graph illustrating the decrease in PPT fluid loss at 275°F for water-based drilling mud compositions that include both SAS and different types of powder latex and that have a higher mass concentration of SAS than powder latex relative to compositions that do not include SAS. Figure 7 is a graph illustrating the decrease in PPT fluid loss at 275°F for oil-based drilling mud compositions that include both SAS and powder latex and that have SAS in a mass concentration that is greater than or equal to that of the powder latex relative to compositions that do not include one or both of SAS or latex. Figure 8 is a graph illustrating the decrease in PPT fluid loss at 300°F for oil-based drilling mud compositions that include both SAS and powder latex and that have SAS at a mass concentration that is equal to that of the powder latex relative to compositions that do not include one or both of SAS or latex. Figure 9 is a graph illustrating the decrease in PPT fluid loss at 300°F for oil-based drilling mud compositions that include both SAS and latex and that have SAS at a mass concentration that is equal to that of the powdered latex relative to compositions that do not include one or both of SAS or latex. Figure 10 is a graph illustrating the decrease in PPT fluid loss and pressure surge loss at 275°F for water-based drilling mud compositions that include both SAS and powder latex and that have SAS at a mass concentration that is greater than that of the powder latex relative to compositions that include other additives. Figure 11 is a graph illustrating the decrease in PPT fluid loss and pressure surge loss at 300°F for oil-based drilling mud compositions that include both SAS and powdered latex and that have SAS in a concentration in Len? nn / Lznz / E / YiAi mass that is greater than that of powdered latex in relation to compositions that include other additives. Figure 12 is a graph illustrating API and HTHP filtrate volumes at 375°F for water-based drilling mud compositions that include both SAS and powder latex and that have SAS at a mass concentration that is greater than that of powder latex relative to compositions that do not include one or both of SAS or latex. Figure 13 is a graph illustrating the variation in coefficient of friction with torque for oil-based drilling mud compositions that include a solid lubricant. Figure 14 is a graph illustrating the variation in coefficient of friction with Stribeck number for oil-based drilling mud compositions excluding and including a solid lubricant. Figure 15 is a graph illustrating the variation in coefficient of friction with Stribeck number for oil-based drilling mud compositions excluding and including a solid lubricant and a friction-reducing particulate material. Figure 16 is a graph illustrating the variation in coefficient of friction with Stribeck number for oil-based drilling mud compositions excluding and including a solid lubricant and an organophilic clay. Figure 17 is a graph illustrating the coefficient of friction over time for a base oil-based drilling mud composition. Figure 18 is a graph illustrating the coefficient of friction over time for a base oil drilling mud composition that includes a solid lubricant. Figure 19 is a graph illustrating the variation of the coefficient of friction with the Stribeck number for oil-based drilling mud compositions excluding a lubricant, including a solid lubricant, and including two different liquid lubricants. Figure 20 is a graph illustrating the variation of rise and fall of weight along a horizontal section with depth. DETAILED DESCRIPTION OF THE INVENTION It should be understood that the disclosure is not limited in its application to the details of construction and arrangement of components set forth in the following description or illustrated in the drawings. DEFINITIONS To more clearly define the terms used herein, the following definitions are provided. Unless otherwise indicated, the following definitions are applicable to this disclosure. If a term is used in this disclosure, but not specifically defined herein, the definition in ILJPAC Compendium of Chemical Terminology, 2nd Ed. (1997) may be applied, provided that that definition does not contradict any other disclosure or definition applied herein, or cause any claim to which such definition was applied to be indefinite or impermissible. To the extent that any definition or usage provided by any document incorporated herein by reference contradicts the definition or usage provided herein, the definition or usage provided herein shall govern. Although compositions and methods are described in terms of comprising various components or steps, the compositions and methods may also consist essentially of or consist of the various components or steps, unless otherwise indicated. The terms "a," "an," and "the" are intended to include plural alternatives, e.g., "at least one." The terms "including," "with," and "has," as used herein, are defined as comprising (i.e., open-ended language), unless otherwise specified. Various numerical ranges are disclosed herein. When applicant discloses or claims a range of any type, applicant intends to individually disclose or claim every possible number that such range could reasonably encompass, including the endpoints of the range as well as any subranges and combinations of subranges encompassed therein, unless otherwise specified. For example, in disclosing a population average particle size of from about 70 microns to about 100 microns, applicant intends to individually mention 70, 71, 72, 73, 74, 75, 76, 77, 78, 79, 80, ... , 98, 99, 100, even any individual integer between 70 and 100 inclusive, subranges and combinations of subranges encompassed therein, and these methods of describing such ranges are interchangeable.Furthermore, all numerical endpoints of the ranges disclosed herein are approximate unless otherwise excluded by proviso. As a representative example, if applicants disclose in one aspect of the disclosure that one or more drilling mud compositions have a plastic viscosity in a range of 20 cP to 30 cP, this range should be interpreted as encompassing viscosities in a range of about 20 cP to about 30 cP. Values ​​or ranges may be expressed herein as around, from around a particular value, and / or around another particular value. When such values ​​or ranges are expressed, other disclosed embodiments include the specific value mentioned, from a particular value, and / or to the other particular value. Similarly, Lrn? nn / Lznz / E / YiAi when values ​​are expressed as approximations, by use of the antecedent around, it will be understood that the particular value forms another embodiment. It will be further understood that there are a number of values ​​disclosed herein, and that each value is also disclosed herein as being around that particular value in addition to the value itself. In another aspect, use of the term around means ±20% of the stated value, ±15% of the stated value, ±10% of the stated value, ±5% of the stated value, ±3% of the stated value, or ±1% of the stated value. Applicant reserves the right to exclude any individual member of any group of values ​​or ranges, including any subranges or combinations of subranges within the group, that may be claimed according to a range or in any similar manner, if for any reason Applicant chooses to claim less than the full extent of the disclosure, for example, to account for a reference that may be unknown to Applicant at the time of filing. In addition, Applicant reserves the right to exclude any individual substituents, analogs, compounds, ligands, structures, or groups thereof, or any member of a claimed group, if for any reason Applicant chooses to claim less than the full extent of the disclosure, for example, to account for a reference that may be unknown to Applicant at the time of filing. The term latex refers to an emulsion of one or more polymers in a solvent such as water. The term powdered latex refers to a powder formed by drying or dehydrating latex. The term asphalt sultanate refers to a sulfonated asphalt formed by treating asphalt with a sulfonating agent. The term sodium asphalt sultanate (SAS) refers to a sodium salt of asphalt sultanate. The term "substituted," when used to describe a group, for example, when referring to a substituted analogue of a particular group, is intended to describe the compound or group in which any non-hydrogen moiety formally replaces the hydrogen in that group or compound, and is intended not to be limiting. A compound or group may also be referred to herein as "unsubstituted," or by equivalent terms such as "unsubstituted," which refers to the original group or compound. "Substituted" is intended not to be limiting and to include inorganic substituents or organic substituents as specified and as understood by one of ordinary skill in the art. Although any methods and materials similar or equivalent to those described herein can be used in the practice or testing of the invention, typical methods and materials are described herein. The Summary of this application is not intended to be used to construe the scope of the claims or to limit the scope of subject matter disclosed herein, but is provided for the purpose of complying with the requirements of 37 CFR § 1.72(b) so that the United States Patent and Trademark Office and the general public may readily determine, from a cursory inspection, the nature and substance of the technical disclosure. Furthermore, any heading employed herein is not intended to be used to construe the scope of the claims or to limit the scope of subject matter disclosed herein. Any use of the past tense to describe an example otherwise stated as constructive or prophetic is not intended to reflect that the constructive or prophetic example has actually been carried out. All publications and patents mentioned herein are incorporated herein by reference for the purpose of describing and disclosing, for example, constructs and methodologies described in the publications, which could be used in connection with the invention described herein. The publications discussed throughout the text are provided solely for disclosure prior to the filing date of this application. Nothing herein should be construed as an admission that the inventors are not entitled to anticipate such disclosure by virtue of the prior invention. The present disclosure relates generally to drilling compositions, for example, compositions used for drilling natural resource wells. The drilling compositions include powdered latex and at least one asphalt sulfonate salt, for example, sodium asphalt sulfonate (SAS). Latex is an emulsion of one or more polymers in water or an aqueous medium and can be natural or synthetic. In some examples, the latex includes an emulsion of a synthetic copolymer. For example, the latex may include an emulsion of a styrene-butadiene copolymer in an aqueous medium. Natural or synthetic latex may include dispersed polymer particles. The properties of the latex may depend, among other things, on the degree of crosslinking of the polymer. Powdered latex can be formed from latex, for example, by drying or dehydrating the latex to separate or remove water from the emulsion, leaving dispersed particles or agglomerates of one or more polymers. Powdered latex can therefore include a powder of polymer particles separated from an aqueous latex medium, for example, by drying. Drying can include spray drying. The properties of powder latex can be controlled by controlling the properties of the latex from which the powder latex is prepared. For example, the degree of crosslinking, the concentration, the density of the solvent, the drying rate, or other parameters can ultimately determine the properties of the powder latex. The powder latex is dispersible or soluble in water-based and oil-based carriers and is suitable for use in drilling mud compositions, e.g., water-based drilling mud compositions and oil-based drilling mud compositions. The powder latex may include at least one of a styrene butadiene copolymer or an ethylene vinyl acetate copolymer. In some aspects, the powder latex consists or consists essentially of a styrene butadiene copolymer. In some aspects, the powder latex consists or consists essentially of an ethylene vinyl acetate copolymer. The powder latex may have any suitable population average particle size and particle size distribution. For example, the powder latex may have a population average particle size in a range of about 0.150 microns to about 150 microns. In some aspects, the powder latex has a population average particle size in a range of about 70 microns to about 100 microns, or in a range of about 80 microns to about 90 microns.In some embodiments, the population average particle size may be around 85 micrometers. The population average particle size may be a D50 size as measured by laser diffraction. The D10, D50, and D90 values ​​represent the 10th percentile, 50th percentile, and 90th percentile of the particle size distribution (PSD), respectively, measured by volume. That is, for example, the D10 value on the particle size distribution curve is such that 10% of the particles are less than and 90% are greater than the particle size at the applicable measurement point. Similarly, the D50 and D90 values ​​are those values ​​on the particle size distribution curve such that 50% or 90%, respectively, of the particles are less than the particle size at the appropriate measurement point. For example, for a particular sample, if D50 = 90 pm, 50% of the particles are greater than 90 pm and 50% of the particles are less than 90 pm.Methods that may be used to determine the particle size distribution (PSD) of powdered latex materials for use in accordance with the present disclosure include any of the standard methods for determining particle size distributions of particulate materials in a particular size range (e.g., 0.1 to 200 pm), including, but not limited to, gravitational liquid settling methods as described in ISO 13317, and sieving / settling methods such as those described in ISO 11277, as well as spectral, acoustic, and laser diffraction methods, as appropriate, and combinations thereof. Asphalt refers to hydrocarbon materials that include bitumen components, for example, one or more of naphthene aromatic compounds, polar aromatic compounds, saturated hydrocarbons, or asphaltenes. Asphalt may be obtained from natural sources or may be obtained by refining petroleum by one or more of distillation, precipitation, cracking, oxidation, or other operations. Asphalt may include one or more of asphaltenes, maltenes, blown asphalt, straight-run oils, still bottoms, still dregs, cracking residues, asphaltic bitumens, or combinations thereof. Various high-molecular-weight asphalt species are commonly separated into four fractions: saturates, aromatics, resins, and asphaltenes. The asphaltene fraction is determined by a gravimetric method and is defined as the hexane-insoluble fraction of asphalt. The other fractions are separated by column chromatography with a silica column packing and by increasing the polarity of the solvent to elute the respective fractions. The asphaltene fraction is soluble in high-polarity solvents such as toluene. Asphalts vary significantly in composition and physical properties depending on the crude oil source and the refinery process. Asphalt can be oxidized to increase its softening point. It is insoluble in water. Natural asphalts such as Gilsonite® (American Gilsonite Company, Houston, TX), known generically as uintahite, asphalt, or asphaltite, are similar to petroleum asphalt and have similar properties. Gilsonite® is often used in drilling fluids due to its high softening point. Polymer-modified asphalts are petroleum asphalts that have been blended with synthetic polymers such as SBS, EVA, or rubber to improve their performance in certain applications, especially paving. Asphalt sulfonate (also known as sulfonated asphalt) can be formed by sulfonating asphalt with a sulfonating agent. Sulfonating agents may include one or more of fuming sulfuric acid, chlorosulfonic acid, concentrated sulfuric acid, or sulfur trioxide. Asphalt sulfonate can be prepared by forming a mixture of asphalt and a solvent and exposing the mixture to a sulfonating agent. The solvent may include hexane. After sulfonation, the resulting product can be neutralized to form a salt, followed by removal of the solvent. Neutralization can be performed with a basic compound, for example, sodium hydroxide or potassium hydroxide. Neutralization with sodium hydroxide forms sodium asphalt sulfonate, while neutralization with potassium hydroxide forms potassium asphalt sulfonate.Asphalt sulfonate can have different properties and include a mixture or combination of materials depending on the parameters of the sulfonation process, for example, the degree of sulfonation or the type of sulfonating agent used. lpív nn / Lznz / E / YiAi The term sodium asphalt sultanate (SAS) refers to a sodium salt of asphalt sultanate. Although the disclosure refers to SAS, in these examples, SAS may be combined or replaced with one or more other salts of asphalt sultanate, for example, a potassium salt, a calcium salt, a lithium salt, or other suitable asphalt sultanate salt. Unlike asphalt, which is neither anionic nor water-soluble, sodium asphalt sultanate may be anionic and water-soluble, for example, at least 70% or at least 80% soluble in water. For example, sodium asphalt sultanate may be produced by reacting asphalt (diluted with heptane) with sulfur trioxide to form the sulfonic acid. The acid may be neutralized with a caustic agent (50% NaOH) to form the sodium salt. This product is water soluble and no longer exhibits the softening point or other characteristics of asphalt. Soltex® (Drilling Specialties Company, The Woodlands, Texas) is an example of a sodium sultanate asphalt. It does not exhibit the typical properties of asphalt; it does not melt and does not have a softening point, unlike asphalt and other natural bituminous products, which soften and melt. Drilling compositions that include both powder latex and SAS may exhibit one or more of a lower fluid loss relative to compositions that do not include one or both of powder latex or SAS. Fluid loss can be determined by high temperature, high pressure (HTHP) fluid loss testing, permeability plugging (PPT) testing, or pressure kick loss, in accordance with protocols established by the American Petroleum Institute (API). Drilling compositions that include both powder latex and SAS may provide improved lubrication, e.g., a lower coefficient of friction, relative to compositions that do not include one or both of latex or SAS. Drilling compositions according to the disclosure may also promote formation stability and cuttings removal.The synergistic effects resulting from the combination of powdered latex and SAS apply to drilling mud compositions that include oil-based or water-based carriers. Without being limited by theory, chemical coupling or network formation may result from the combination of powdered latex and SAS, which can result in synergy. In aspects, compositions that include both powder latex and SAS, and that have a higher mass concentration of SAS than that of powder latex, may exhibit lower fluid loss, greater lubricity, and greater formation stability relative to compositions that include other relative concentrations of SAS and powder latex. According to one aspect, a drilling mud composition includes a first concentration of powdered latex and a second concentration of SAS. In some aspects, the second concentration of SAS may be greater than or equal to the first latex concentration. In some such aspects, the second concentration of SAS may be greater than the first latex concentration. For example, the second SAS concentration may be greater than the first latex concentration by a predetermined threshold, for example, by at least 0.1 pounds per barrel (Ibm / bbl), by at least 0.25 Ibm / bbl, by at least 0.5 Ibm / bbl, by at least 1.0 Ibm / bbl, by at least 1.5 Ibm / bbl, by at least 2 Ibm / bbl, by at least 2.5 Ibm / bbl, by at least 3 Ibm / bbl, by at least 3.5 Ibm / bbl, by at least 4 Ibm / bbl, or by at least 5 Ibm / bbl. In other examples, the second SAS concentration may be substantially the same as the first latex concentration.In still other examples, the second concentration of SAS may be lower than the first concentration of latex. According to one aspect, a drilling mud composition includes a first concentration of powdered latex and a second concentration of SAS, wherein the second concentration of SAS is greater than or equal to the first concentration of latex. The powdered latex and SAS may be dispersed or solubilized in a carrier, for example, a water-based carrier or an oil-based carrier, to form a drilling mud composition. In some examples, an additive composition for adding to a drilling mud composition or to a carrier composition may include powdered latex and SAS according to the disclosure. The additive composition may also include one or more additives, for example, one or more of asphalt, Gilsonite® (or uintahite), lignite, or any other suitable drilling composition additive. In some aspects, the drilling mud composition includes a water-based carrier and a second concentration of SAS that is greater than or equal to a first concentration of powdered latex. In some such aspects, the second concentration of SAS in the drilling mud composition may be greater than the first latex concentration. Drilling mud compositions that include a water-based carrier according to such aspects may exhibit lower fluid loss than compositions that do not include one or both of powdered latex or SAS. For example, in some such aspects, the drilling mud composition has an average high temperature, high pressure (HTHP) fluid loss at 250°F and 500 pounds per square inch (psi) of less than or about 20 mL when evaluated in accordance with the American Petroleum Institute (API) Test 13B-1.In some such aspects, the drilling mud composition may have an average HTHP fluid loss at 250°F and 500 psi of less than or about 18 mL, or less than or about 15 mL, or less than or about 12 mL. In some such aspects, the drilling mud composition has an average permeability plugging test (PPT) loss at 250°F with a 12 micron filter disc of less than or about 18.0 mL when evaluated in accordance with API Test 13B-1. In some such aspects, the drilling mud composition has an average PPT loss of less than or about 16 mL, or less than or about 15 mL, or less than or about 12 mL. Drilling mud compositions that include a water-based carrier according to such aspects may exhibit greater lubrication than compositions that do not include one or both of powdered latex or SAS. For example, in some such aspects, the drilling mud composition has a coefficient of friction of less than or about 0.40 at a torque of 250 lb-ft. In some such aspects, the drilling mud composition may have a coefficient of friction of less than or about 0.35, or less than or about 0.30, or less than or about 0.25. Drilling mud compositions including a water-based carrier according to the disclosure may exhibit rheological properties (e.g., one or more of plastic viscosity, yield strength, or gel strength) suitable for drilling. For example, a drilling mud composition according to some such aspects has a plastic viscosity at 120°F in a range of about 10 cP to about 30 cP when evaluated according to the American Petroleum Institute (API) Test 13B-1. In some such aspects, the drilling mud composition has a plastic viscosity in a range of about 10 cP to about 15 cP, or about 10 cP to about 20 cP, or 15 cP to about 20 cP, or about 15 cP to about 30 cP, or about 20 cP to about 30 cP. In some such aspects, the drilling mud composition has a yield strength at 120°F in a range of about 10 lb / 100 ft2 to about 45 lb / 100 ft2 when evaluated in accordance with the American Petroleum Institute (API) Test 13B-1. In some such aspects, the drilling mud composition has a yield strength at 120°F in a range of from about 10 lb / 100 ft2 to about 20 lb / 100 ft2, or from about 20 lb / 100 ft2 to about 45 lb / 100 ft2, or from about 10 lb / 100 ft2 to about 30 lb / 100 ft2, or from about 15 lb / 100 ft2 to about 20 lb / 100 ft2, or from about 15 lb / 100 ft2 to about 30 lb / 100 ft2, or from about 30 lb / 100 ft2 to about 45 lb / 100 ft2. In some such aspects, the drilling mud composition has a 10 second gel strength at 120°F in a range of about 2.0 lb / 100 ft2 to about 6.5 lb / 100 ft2 when evaluated in accordance with American Petroleum Institute (API) Test 13B-1. In some such aspects, the drilling mud composition has a 10 second gel strength at 120°F in a range of about lpív nn / Lznz / E / YiAi 2.5 lb / 100 ft2 to about 6.5 lb / 100 ft2, or from about 2.0 to about 3.0 lb / 100 ft2, or from about 5.0 to about 6.5 lb / 100 ft2, or from about 5.5 to about 6.5 lb / 100 ft2. In some such embodiments, the drilling mud composition has a 10-minute gel strength at 120°F in the range of about 2 lb / 100 ft2 to about 12 lb / 100 ft2 when evaluated in accordance with the American Petroleum Institute (API) Test 13B-1. In some such aspects, the drilling mud composition has a 10 minute gel strength at 120°F in a range of from about 2 lb / 100 ft2 to about 5 lb / 100 ft2, or from about 2 lb / 100 ft2 to about 10 lb / 100 ft2, or from about 3 lb / 100 ft2 to about 10 lb / 100 ft2, or from about 5 lb / 100 ft2 to about 10 lb / 100 ft2, or from about 5 lb / 100 ft2 to about 12 lb / 100 ft2. Drilling mud compositions that include a water-based carrier may include any suitable first powder latex concentration and second SAS concentration. In some such aspects, the second SAS concentration may be greater than or equal to the first powder latex concentration. In some such aspects, the first powder latex concentration is at least 1 pound per barrel (Ibm / bbl) and the second SAS concentration is at least 2 Ibm / bbl. In some such aspects, the first powder latex concentration may be in a range of about 1.5 to about 2.5 Ibm / bbl, and the second SAS concentration may be in a range of about 2.5 to about 3.5 Ibm / bbl. In some such aspects, the first powder latex concentration may be about 2 Ibm / bbl, and the second SAS concentration may be about 3 Ibm / bbl.In some such aspects, the first powder latex concentration may be about 1.5 lbm / bbl, and wherein the second SAS concentration may be about 4.5 lbm / bbl. In some such aspects, the first powder latex concentration may be about 1.2 lbm / bbl, and wherein the second SAS concentration may be about 4.8 lbm / bbl. In some such aspects, the first powder latex concentration may be about 1.8 lbm / bbl, and wherein the second SAS concentration may be about 4.2 lbm / bbl. Drilling mud compositions including water-based carriers according to the disclosure may be formed by any suitable technique. In aspects, one technique includes dispersing a first predetermined amount of powdered latex and a second predetermined amount of SAS in a water-based carrier to form a water-based mud. The water-based mud may include any drilling composition according to the disclosure that includes a water-based carrier. lpív nn / Lznz / E / YiAi In some aspects, the drilling mud composition includes an oil-based carrier and a second concentration of SAS that is greater than or equal to a first concentration of powdered latex. In some such aspects, the second concentration of SAS in the drilling mud composition may be greater than the first latex concentration. Drilling mud compositions that include an oil-based carrier according to such aspects may exhibit lower fluid loss than compositions that do not include one or both of powdered latex or SAS. For example, in some such aspects, the drilling mud composition that includes an oil-based carrier has an average permeability plugging test (PPT) fluid loss at 300°F with a 55 micron filtration disc of less than or about 1.06 mL when evaluated in accordance with the American Petroleum Institute (API) Test 13B-2.In some such aspects, the drilling mud composition including an oil-based carrier has an average PPT fluid loss at 275°F of less than or about 3.3 mL, or less than or about 3.0 mL, or less than or about 2.5 mL. In some such aspects, the drilling mud composition including an oil-based carrier has an average PPT fluid loss at 300°F with a 40 micron filtration disc of less than or about 3.3 mL, or less than or about 3.15 mL, or less than or about 3.00 mL. Drilling mud compositions that include an oil-based carrier according to such aspects may exhibit greater lubrication than compositions that do not include one or both of powdered latex or SAS. Drilling mud compositions that include an oil-based carrier according to the disclosure may exhibit rheological properties suitable for drilling. For example, a drilling mud composition according to some such aspects has a plastic viscosity at 120°F in a range of about 10 cP to about 30 cP when evaluated in accordance with API Test 13B-2. In some such examples, a drilling mud composition may have a plastic viscosity in a range of about 10 cP to about 15 cP, or in a range of about 12 cP to about 20 cP, or in a range of about 15 cP to about 20 cP, or in a range of about 15 cP to about 25 cP, or in a range of about 15 cP to about 30 cP. In some such aspects, the drilling mud composition has a yield strength at 120°F in a range of from about 5 lb / 100 ft2 to about 12 lb / 100 ft2 when evaluated in accordance with API Test 13B-2. In some such aspects, the drilling mud composition has a yield strength at 120°F in a range of from about 5 lb / 100 ft2 to about 10 lb / 100 ft2, or from about 5 lb / 100 ft2 to about 8 lb / 100 ft2, or from about 8 lb / 100 ft2 to about 12 lb / 100 ft2, or from about 5 lb / 100 ft2 to about 6 lb / 100 ft2. In some such aspects, the drilling mud composition has a 10 second gel strength at 120°F in a range of about 2 lb / 100 ft2 to about 12 lb / 100 ft2 when evaluated in accordance with API Test 13B-2. In some such aspects, the drilling mud composition has a 10 second gel strength at 120°F in a range of about 2 lb / 100 ft2 to about 11 lb / 100 ft2, or in a range of about 2 lb / 100 ft2 to about 10 lb / 100 ft2, or in a range of about 5 lb / 100 ft2 to about 12 lb / 100 ft2, or in a range of about 2 lb / 100 ft2 to about 5 lb / 100 ft2. In some such embodiments, the drilling mud composition has a 10-minute gel strength at 120°F in the range of about 2 lb / 100 ft2 to about 40 lb / 100 ft2 when evaluated in accordance with API Test 13B-2. In some such aspects, the drilling mud composition has a 10 minute gel strength at 120°F in a range of from about 2 lb / 100 ft2 to about 10 lb / 100 ft2, or from about 2 lb / 100 ft2 to about 20 lb / 100 ft2, or from about 10 lb / 100 ft2 to about 30 lb / 100 ft2, or from about 10 lb / 100 ft2 to about 20 lb / 100 ft2, or from about 20 lb / 100 ft2 to about 30 lb / 100 ft2, or from about 10 lb / 100 ft2 to about 40 lb / 100 ft2. Drilling mud compositions that include an oil-based carrier may include any suitable first powder latex concentration and second SAS concentration. In some such aspects, the second SAS concentration may be greater than or equal to the first powder latex concentration. For example, in some such aspects, the first powder latex concentration may be at least about 1 pound per barrel (lbm / bbl), and the second SAS concentration may be at least about 1 lbm / bbl. In some such aspects, the first powder latex concentration may be at least about 2 lbm / bbl, and the second SAS concentration may be at least about 2 lbm / bbl. In some such aspects, the first powder latex concentration may be at least about 1 lbm / bbl, and the second SAS concentration may be at least about 2 lbm / bbl.In some such aspects, the first powder latex concentration may be at least about 1 lbm / bbl, and the second SAS concentration may be at least about 3 lbm / bbl. In some such aspects, the first powder latex concentration may be at least about 1 lbm / bbl, and the second SAS concentration may be at least about 4 lbm / bbl. In some such aspects, the first powder latex concentration may be at least about 1.5 lbm / bbl, and the second SAS concentration may be at least about 2.5 lbm / bbl. In some such aspects, the first powder latex concentration may be at least about 1.2 lbm / bbl, and the second SAS concentration may be at least about 4.8 lbm / bbl. In some of these aspects, the first concentration of powdered latex may be at least about 1.5 lbm / bbl, and the second SAS concentration may be at least about 4.5 lbm / bbl. In some such aspects, the first powder latex concentration may be about 1 lbm / bbl, and the second SAS concentration may be about 3 lbm / bbl. In some such aspects, the first powder latex concentration may be about 1.2 lbm / bbl, and the second SAS concentration may be about 4.8 lbm / bbl. In some such aspects, the first powder latex concentration may be about 1.5 lbm / bbl, and the second SAS concentration may be about 4.5 lbm / bbl. In some such aspects, the first powder latex concentration may be about 1.8 lbm / bbl, and the second SAS concentration may be about 4.2 lbm / bbl.In some such aspects, the first powder latex concentration may be about 2 lbm / bbl, and the second SAS concentration may be about 3 lbm / bbl. In some such aspects, the first powder latex concentration may be in a range of about 1.5 to about 2.5 lbm / bbl, and the second SAS concentration may be in a range of about 1.5 to about 2.5 lbm / bbl. In some such aspects, the first powder latex concentration may be about 2 lbm / bbl, and wherein the second SAS concentration may be about 2 lbm / bbl. Drilling mud compositions including oil-based carriers according to the disclosure may be formed by any suitable technique. In aspects, one technique includes dispersing a first predetermined amount of powdered latex and a second predetermined amount of SAS in an oil-based carrier to form an oil-based mud. The oil-based mud may include any drilling composition according to the disclosure that includes an oil-based carrier. Drilling mud compositions according to the disclosure may include a drilling mud composition that is ready to use or may relate to a drilling mud additive composition for adding to a carrier or drilling mud prior to use. For example, the drilling mud additive compositions may include a mixture of powdered latex and SAS. For example, such drilling mud additive compositions may include mixtures of powdered latex and SAS such that adding a predetermined amount of drilling mud additive compositions to a carrier results in a drilling mud composition that includes concentrations of powdered latex and SAS according to the disclosure. Mixtures of powdered latex and SAS (and including optional additional components according to the disclosure) may be described as a solid lubricant, a solid-state lubricant, or a solid-type lubricant, because such mixtures may be substantially solid compared to conventional liquid lubricants. Thus, in embodiments, the drilling mud additive compositions may include a solid lubricant composition. For example, the drilling mud additive composition or solid lubricant composition may include SAS and powdered latex. In some embodiments, the drilling mud additive composition or solid lubricant composition consists essentially of SAS and powdered latex. In some embodiments, the drilling mud additive composition or solid lubricant composition consists of SAS and powdered latex. Drilling mud additive compositions may include SAS and powdered latex as a 50 / 50 SAS-latex blend, a 60 / 40 SAS-latex blend, a 70 / 30 SAS-latex blend, an 80 / 20 SAS-latex blend, or a 90 / 10 SAS-latex blend. The ratio refers to the relative concentrations of SAS and latex, and the blends may optionally include other components or additives. Drilling compositions according to the disclosure may provide one or more of improved fluid loss control, plug test performance, formation stability, and lubricity, and may reduce logistics and material handling at a drilling site. EXAMPLES The invention is further illustrated by the following examples, which should not be construed in any way as limitations upon the scope of the present invention. Various other aspects, embodiments, modifications, and equivalents thereof may occur to one of ordinary skill in the art upon reading the disclosure herein without departing from the spirit of the present invention or the scope of the appended claims. General considerations Fluid loss was determined using high temperature, high pressure (HTHP) fluid loss and permeability plugging test (PPT) protocols in accordance with the American Petroleum Institute (API) Test Set 13B-1 for compositions including a water-based carrier and Test Set 13B-2 for compositions including an oil-based carrier. Unless otherwise specified, latex blend or SAS-latex refers to a blend of SAS and XP-211 styrene butadiene copolymer latex, also known as Axilat™ PSB 150 (Synthomer, Roebuck, South Carolina). Len? nn / Lznz / E / YiAi EXAMPLE 1 The properties of water-based drilling mud compositions including different concentrations of powdered latex and sodium asphalt sulfonate (SAS) were evaluated. One base mud composition included 7.0 pounds per barrel (lbm / bbl) of bentonite, 2 lbm / bbl of polyanionic cellulose, 0.75 lbm / bbl of a biopolymer, 10 lbm / bbl of Rev Dust™ inert particulate material (Milwhite, Inc., Brownsville, Texas), 0.5 lbm / bbl of caustic soda, and 2 lbm / bbl of sodium sulfite. The base composition had a density of 8.6 lbm / gal. Four samples were prepared: A1) base, B1) base with 6 lbm / bbl of SAS, C1) base with 4 lbm / bbl of powdered latex, and D1) base with 3 lbm / bbl of SAS and 2 lbm / bbl of powdered latex (60 / 40 or 1.5:1 SAS-latex blend). The samples were hot rolled for 16 hours at 250°F. The rheological properties of the samples, such as plastic viscosity, yield strength, and gel strength, were determined using a rotational viscometer and are presented in TABLE 1. Table 1 lpív nn / Lznz / E / YiAi Rheology (120°F) A1 (Base) B1 (SAS) C1 (Latex) D1 (SAS-Latex 60 / 40) Viscosity at 600 rpm (cP) 41.50 37.50 44.00 38.10 Viscosity at 300 rpm (cP) 26.50 24.10 28.10 24.60 Viscosity at 200 rpm (cP) 20.00 18.70 21.80 18.90 Viscosity at 100 rpm (cP) 12.90 12.10 14 12.50 Viscosity at 6 rpm (cP) 1.90 1.90 2.40 2.20 Viscosity at 3 rpm (cP) 1.40 1.30 1.90 1.70 Plastic Viscosity (cP) 15.00 13.40 15.90 13.50 Yield Strength (lb / 100 sq ft) 11.50 10.70 12.20 11.10 Gel Strength (lb / 100 sq ft) (10 sec / 10 min) 2.1 / 2.7 2.0 / 3.5 2.4 / 3.0 2.3 / 2.5 API Filtration (mL) 8.10 8.22 7.43 6.93 pH 8.27 7.81 8.51 7.94 The HTHP fluid loss and pressure surge loss for the four samples were determined using API Test Suite 13B-1. The results are presented in Table 2. Table 2 HTHP Fluid Loss (mL) at 250°F A1 (Base) B1 (SAS) C1 (Latex) D1 (SAS Latex 60 / 40) Minutes 1 3.18 2.28 2.35 17.10 5 7.36 4.93 5.23 3.95 7.5 10.74 6.10 6.47 4.79 10 12.64 7.15 7.54 5.48 15 14.74 8.91 9.36 6.87 20 16.65 10.42 10.87 7.88 25 18.27 11.80 12.24 8.65 30 19.56 13.08 13.51 9.42 HTHP Loss (mL) 39.12 26.16 27.02 18.84 Pressure Surge Loss 0.0 0.0 0.0 0.1 The HTHP test results are illustrated in Figure 1. Figure 1 is a graph illustrating the decrease in high temperature, high pressure (HTHP) fluid loss at 250°F for a water-based drilling mud composition that includes both sodium asphalt sulfonate (SAS) and powdered latex relative to compositions that did not include one or both of SAS or latex. Sample D1 exhibited a reduction in HTHP loss of 28% relative to Sample B1, and 30% relative to Sample C1. The coefficient of friction (CoF) was determined for samples A1 through D1. The CoF can be determined by any of several means, including a lubricity tester (OFI Test Equipment, Houston, TX), a lubricity evaluation monitor (OFI Test Equipment, Houston, TX), or a tribometer (Nanovea, Irvine, CA). Scaled results (100 x CoF) are presented in Table 3. Table 3 lpív nn / Lznz / E / YiAi Torque (in-lb) A1 (Base) B1 (SAS) C1 (Latex) D1 (SAS-Latex 60 / 40) IOOxCoF 100 4.1 2.5 20.2 17.1 150 3.1 9.5 29.3 25.1 200 3.4 7.2 37.3 31.5 250 8.0 5.0 43.1 38.6 300 5.9 43.4 45.4 350 47.1 400 66.0 Sample D1 (SAS-latex 60 / 40) exhibited a CoF that was generally lower than samples B1 (SAS) and C1 (latex), for example, at a torque of 250 in-lb. EXAMPLE 2 The properties of water-based drilling mud compositions including different concentrations of powdered latex and sodium asphalt sulfonate (SAS) were evaluated. The base mud composition included 7.0 lbm / bbl of bentonite, 2 lbm / bbl of polyanionic cellulose, 0.75 lbm / bbl of a biopolymer, 10 lbm / bbl of Rev Dust™ inert particulate material (Milwhite, Inc., Brownsville, Texas), 0.5 lbm / bbl of caustic soda, 2 lbm / bbl of sodium sulfite, and 20 lbm / bbl of barite. The base composition had a density of 9.0 lbm / gal. Six samples were prepared: A2) base, B2) base with 6 lbm / bbl of SAS, C2) base with 6 lbm / bbl of powdered latex, D2) base with 1.5 lbm / bbl of SAS and 4.5 lbm / bbl of powdered latex (25 / 75 or 1:3 SAS-latex blend), E2) base with 3.0 lbm / bbl of SAS and 3.0 lbm / bbl of powdered latex (50 / 50 or 1:1 SAS-latex blend), and F2) base with 4.5 lbm / bbl of SAS and 1.5 lbm / bbl of powdered latex (75 / 25 or 3:1 SAS-latex blend). The samples were hot rolled for 16 hours at 250°F. The rheological properties of the samples were determined and are presented in TABLE 4. lpív nn / Lznz / E / YiAi Table 4 Rheology (120°F) A2 (Base) B2 (SAS) C2 (Latex) D2 (SAS Latex 25 / 75) E2 (SAS Latex 50 / 50) F2 (SAS Latex 75 / 25) Viscosity @ 600 rpm (cP) 74.90 65.50 81.00 68.40 81.60 75.20 Viscosity @ 300 rpm (cP) 51.20 45.50 24.10 46.70 55.10 51.10 Viscosity @ 200 rpm (cP) 41.00 40.50 18.70 37.60 45.30 43.20 Viscosity @ 100 rpm (cP) 27.90 24.50 12.10 26 31 29.70 Viscosity at 6 rpm (cP) 6.90 6.00 1.90 7.00 8.20 7.60 Viscosity at 3 rpm (cP) 4.80 4.20 1.30 5.80 6.60 6.00 Plastic Viscosity (cP) 23.70 20.50 13.40 21.70 26.50 24.10 Yield Strength (lb / 100 sq ft) 27.50 15.60 10.70 25.00 28.60 27.00 Gel Strength (lb / 100 sq ft) (10 sec / 10 min) 5.1 / 12.0 3.3 / 9.5 2.0 / 3.5 5.9 / 11.3 6.5 / 12.7 5.8 / 11.7 PPT fluid loss and pressure surge loss for the six samples were determined at 250°F and with a 12-micrometer disk, using API Test Set 13B-1. The results are presented in Table 5. Table 5 PPT Fluid Loss at 250°F A2 (Base) B2 (SAS) C2 (Latex) D2 (SAS Latex 25 / 75) E2 (SAS Latex 50 / 50) F2 (SAS Latex 75 / 25) Minutes 1 2.97 2.97 1.59 2.88 2.02 1.75 5 5.07 4.72 3.79 4.89 4.01 3.45 7.5 5.99 5.51 4.81 5.87 4.73 4.53 10 6.58 6.26 5.38 6.66 5.39 5.00 15 8.15 7.46 6.35 7.86 6.77 5.97 20 9.03 8.39 7.77 9.01 7.90 6.96 25 10.24 9.71 8.79 9.85 8.63 7.92 30 11.02 10.28 9.56 10.63 9.66 8.70 PPT (mL) 22.04 20.56 19.12 21.26 19.32 17.40 Surge Pressure Loss (mL) 2.2 0.0 0.0 0.1 0.0 0.0 Figure 2 is a graph illustrating the decrease in permeability plugging test (PPT) fluid loss at 250°F for water-based drilling mud compositions that include both SAS and powder latex and that have a higher concentration of SAS than powder latex relative to compositions that do not include one or both of SAS or latex. Sample F2 (SAS-latex 75 / 25) exhibited a reduction in PPT loss relative to both samples B2 (SAS) and C2 (latex) and also relative to samples D2 (SAS-latex 25 / 75) and E2 (SAS-latex 50 / 50). EXAMPLES The properties of water-based drilling mud compositions including different concentrations of powdered latex and sodium asphalt sulfonate (SAS) were evaluated. The base mud composition included 7.0 lbm / bbl of bentonite, 2 lbm / bbl of polyanionic cellulose, 0.75 lbm / bbl of a biopolymer, 10 lbm / bbl of Rev Dust™ inert particulate material (Milwhite, Inc., Brownsville, Texas), 0.5 lbm / bbl of caustic soda, 2 lbm / bbl of sodium sulfite, and 20.6 lbm / bbl of barite. The base composition had a density of 9.0 lbm / gal. Six samples were prepared: A3) base, B3) base with 6 lbm / bbl of SAS, C3) base with 6 lbm / bbl of powdered latex, D3) base with 1.5 lbm / bbl of SAS and 4.5 lbm / bbl of powdered latex (SAS-latex mixture 25 / 75 or 1:3), E3) base with 3.0 lbm / bbl of SAS and 3.0 lbm / bbl of powdered latex (SAS-latex mixture 50 / 50 or 1:1), F3) base with 4.5 lbm / bbl of SAS and 1.5 lbm / bbl of powdered latex (SAS-latex mixture 75 / 25 or 3:1), G3) base with 3.6 lbm / bbl of SAS and 2.4 lbm / bbl of powdered latex (SAS-latex mixture 75 / 25 or 3:1), of powdered latex (60 / 40 or 1.5:1 SAS-latex blend), H3) base with 4.2 lbm / bbl of SAS and 1.8 lbm / bbl of powdered latex (70 / 30 or 2.33:1 SAS-latex blend). The samples were hot rolled for 16 hours at 250°F. The rheological properties of samples A3 to F3 were determined and are presented in TABLE 6. lpív nn / Lznz / E / YiAi Lrn? nn / Lznz / E / YiAi Table 6 Rheology at 120°F A3 (base) B3 (SAS) C3 (latex) D3 (SASlatex 25 / 75) E3 (SASlatex 50 / 50) F3 (SASlatex 75 / 25) Viscosity at 600 rpm (cP) 74.90 65.50 81.00 68.40 81.60 75.20 Viscosity at 300 rpm (cP) 51.20 45.50 24.10 46.70 55.10 51.10 Viscosity at 200 rpm (cP) 41.00 40.50 18.70 37.60 45.30 43.20 Viscosity at 100 rpm (cP) 27.90 24.50 12.10 25.90 31.30 29.70 Viscosity at 6 rpm (cP) 6.90 6.00 1.90 7.00 8.20 7.60 Viscosity at 3 rpm (cP) 4.80 4.20 1.30 5.80 6.60 6.00 Plastic Viscosity (cP) 23.70 20.50 13.40 21.70 26.50 24.10 Yield Strength (lb / 100 sq ft) 27.50 15.60 10.70 25.00 28.60 27.00 Gel Strength (lb / 100 sq ft) (10 sec / 10 min) 5.1 / 12.0 3.3 / 9.5 2.0 / 3.5 5.9 / 11.3 6.5 / 12.7 5.8 / 11.7 The coefficient of friction (CoF) was determined for samples A3 to H3. The scaled results (100 x CoF) are presented in Table 7. Table 7 Torque (puigib) A3 (base) B3 (SAS) C3 (latex) D3 (SASlatex 25 / 75) E3 (SASlatex 50 / 50) F3 (SASlatex 75 / 25) G3 (SASlatex 60 / 40) H3 (SASlatex 70 / 30) CoFx 100 100 17.8 17.5 14.8 16.6 16.50 15.30 16.6 14.00 150 25.4 24.4 23.4 23.9 23.50 22.40 24.1 22.60 200 31.9 31.8 30.7 31.1 31.50 29.80 31.1 30.70 250 41.2 40.2 39.2 37.8 39.70 37.20 38.8 38.60 300 52.7 48.0 47.4 45.4 47.70 44.40 47.0 45.10 350 67.80 60 55.7 54 56 51.80 55 53.70 400 63.7 62 63.00 65 62.90 450 65.7 71.30 Samples F3 (SAS-latex 75 / 25), G3 (SAS-latex 60 / 40), and H3 (SAS-latex 70 / 30) exhibited a CoF that was generally lower than samples B1 (SAS) and C1 (latex), for example, at a torque of 250 in-lb. EXAMPLE 4 The properties of water-based drilling mud compositions including different concentrations of powder latex and sodium asphalt sulfonate (SAS) were evaluated. A base composition similar to that in EXAMPLE 3 was prepared. Four samples were prepared: A4) base, B4) base with 6 lbm / bbl of SAS, C4) base with 6 lbm / bbl of powder latex, and D4) base with 4.8 lbm / bbl of SAS and 1.2 lbm / bbl of powder latex (80 / 20 or 4:1 SAS-latex blend). The samples were hot rolled for 16 hours at 250°F. The rheological properties of samples A4 through D4 were determined and are presented in TABLE 8. Table 8 lpív nn / Lznz / E / YiAi Rheology at 120°F A4 (base) B4 (SAS) C4 (latex) D4 (SASlatex 80 / 20) Viscosity at 600 rpm (cP) 94.30 79.00 87.90 38.10 Viscosity at 300 rpm (cP) 64.80 54.60 61.60 24.60 Viscosity at 200 rpm (cP) 51.50 43.70 52.10 18.90 Viscosity at 100 rpm (cP) 35.60 30.50 36.70 12.50 Viscosity at 6 rpm (cP) 7.80 7.50 10.50 2.20 Viscosity at 3 rpm (cP) 6.10 5.70 8.30 1.70 Plastic Viscosity (cP) 29.50 24.40 26.30 13.50 Yield Strength (lb / 100 sq ft) 35.30 30.20 35.30 11.10 Gel Strength (lb / 100 sq ft) (10 sec / 10 min) 6.4 / 13.8 6.1 / 12.4 8.5 / 17.9 2.3 / 2.5 The PPT fluid loss and pressure surge loss for the four samples were determined at 325°F using API Test Set 13B-1. The results are presented in Table 9. Table 9 PPT Fluid Loss at 325°F A4 (Base) B4 (SAS) C4 (Latex) D4 (SAS-Latex 80 / 20) Minutes 1 4.60 4.67 3.80 2.76 5 8.16 7.76 6.47 5.84 7.5 9.40 9.15 8.11 7.03 10 10.70 10.49 9 8.39 15 13.31 12.09 11.04 10.07 20 15.21 13.67 12.73 11.65 25 17.05 15.31 14.19 12.88 30 18.10 16.65 15.60 13.86 PPT (mL) 36.20 33.30 31.20 27.72 Pressure Surge Loss (mL) 3.0 3.7 1.7 0.6 Figure 3 is a graph illustrating the decrease in PPT fluid loss at 325°F for water-based drilling mud compositions that include both SAS and powder latex and that have a higher concentration of SAS than powder latex relative to compositions that do not include one or both of SAS or latex. Figure 4 is a graph illustrating PPT fluid loss at 325°F for water-based drilling mud compositions that include both SAS and powder latex and that have a higher concentration of SAS than powder latex relative to compositions that do not include one or both of SAS or latex. Sample D4 with the 80 / 20 SAS-latex blend generally exhibited a decrease in PPT compared to samples A4 (base), B4 (SAS), and C4 (latex). EXAMPLES The properties of water-based drilling mud compositions including different concentrations of powdered latex and sodium asphalt sulfonate (SAS) were evaluated. The PPT fluid loss for base sample A4 of EXAMPLE 4 and sample D4 including an 80 / 20 SAS-latex mixture was determined at 250°F, 275°F, and 300°F. The PPT loss and pressure surge loss for samples A4 and D4 are presented in TABLE 10. Table 10 PPT Fluid Loss A4 (base) D4 (SASlatex 80 / 20) A4 (base) D4 (SASlatex 80 / 20) A4 (base) D4 (SASlatex 80 / 20) Temperature 250°F 250°F 275°F 275°F 300°F 300°F Minutes 1 3.31 1.11 3.32 2.66 3.83 2.80 5 6.59 3.99 6.74 5.69 7.87 6.16 7.5 7.92 4.99 8.41 6.65 9.90 8.06 10 9.16 5.96 9.59 8.15 11.61 9.11 15 11.05 8.12 12.05 10.27 14.15 11.61 20 12.67 10.34 14.24 12.05 16.54 13.63 25 14.37 10.73 16.09 13.60 18.74 15.40 30 15.77 12.50 17.63 14.49 20.32 16.96 PPT 31.54 25.00 35.26 28.98 40.64 33.92 Pressure surge loss 0.9 0.0 0.0 0.0 0.0 0.00 Figure 5 is a graph illustrating the decrease in PPT fluid loss for water-based drilling mud compositions that include both SAS and powder latex and have a higher concentration of SAS than powder latex relative to compositions that do not include SAS or latex at different temperatures (250°F, 275°F, and 300°F). As seen in TABLE 10 and Figure 5, the mud with the 80 / 20 SAS-latex mixture remained stable between 250°F and 300°F. EXAMPLE 6 The properties of water-based drilling mud compositions including the same SAS-latex ratio, but different types of powdered latex, were evaluated. A base composition similar to that of EXAMPLE 3 was prepared. Four samples were prepared: A6) base, B6) base with 4.8 Ibm / bbl of SAS and 1.2 Ibm / bbl of powdered latex type A (a styrene butadiene copolymer, Axilat™ PSB 150, also known as XP-211, Synthomer, Roebuck, South Carolina) (80 / 20 or 4:1 SAS-latex blend), C6) base with 4.8 Ibm / bbl of SAS and 1.2 Ibm / bbl of latex in polyurethane foam B (VAE-RS 1220, Riteks, Houston, Texas) Table 11 lpív nn / Lznz / E / YiAi Rheology at 120°F A6 (base) B6 (SAS-latex A 80 / 20) C6 (SAS-latex B 80 / 20) D6 (SAS-latex C 80 / 20) Viscosity at 600 rpm (cP) 68.7 61.0 55.6 52.6 Viscosity at 300 rpm (cP) 47.4 41.4 38.1 35.7 Viscosity at 200 rpm (cP) 38.1 33.4 31.0 29.2 Viscosity at 100 rpm (cP) 26.4 23.2 21.5 19.5 Viscosity at 6 rpm (cP) 7.1 6.8 6.2 5.5 Viscosity at 3 rpm (cP) 6.0 5.7 5.0 4.1 Plastic Viscosity (cP) 21.3 19.6 17.5 16.9 Yield Strength (lb / 100 ft2) 26.1 21.8 20.6 18.8 Gel Strength (lb / 100 ft2) (10 seconds / 10 minutes) 5.7 / 13.1 5.2 / 10.6 4.7 / 9.2 The PPT fluid loss and pressure surge loss for samples A6 through D6 were determined at 275°F and are presented in TABLE 12. Table 12 PPT fluid loss at 275°F A6 (base) B6 (SAS-latex A 80 / 20) C6 (SAS-latex B 80 / 20) D6 (SAS-latex C 80 / 20) Minutes 1 3.83 2.80 3.34 2.99 5 7.87 6.16 6.43 6.62 7.5 9.90 8.06 7.67 9.75 10 11.61 9.11 9.05 8.87 15 14.15 11.61 11.64 1.12 20 16.59 13.63 12.76 12.95 25 18.74 15.40 14.24 14.54 30 20.32 16.96 15.24 15.42 PPT (mL) 40.64 33.92 30.48 30.84 Pressure Surge Loss (mL) 0.0 0.0 1.2 0.6 Figure 6 is a graph illustrating PPT fluid loss at 275°F for water-based drilling mud compositions that include both SAS and different types of powder latex and that have a higher concentration of SAS than powder latex relative to compositions that do not include SAS. The different types of powdered latex in SAS-latex blends exhibited generally similar properties and exhibited a generally similar reduction in PPT loss. EXAMPLE 7 The properties of oil-base drilling mud compositions including different concentrations of SAS and latex were evaluated. The base mud composition included 5.0 lbm / bbl of oleophilic clay, 6.0 lbm / bbl of a primary emulsifier, 6.0 lbm / bbl of an oil wetting agent, 0.5 lbm / bbl of Rev Dust™ inert particulate material (Milwhite, Inc., Brownsville, Texas), 25% calcium chloride, 144.3 lbm / bbl of barite, 6.0 lbm / bbl of lime, and had an oil-to-water ratio of 85 / 15. The base composition had a density of 11.0 lbm / gal. Five samples were prepared: A7) base, B7) base with 2.0 lbm / bbl of powdered latex, C7) base with 4.0 lbm / bbl of SAS, D7) base with 3.0 lbm / bbl of SAS and 1.0 lbm / bbl of powdered latex (75 / 25 or 3:1 SAS-latex blend), and E7) base with 2.0 lbm / bbl of SAS and 2.0 lbm / bbl of powdered latex (50 / 50 or 1:1 SAS-latex blend). The samples were hot rolled for 16 hours at 250°F. The rheological properties of samples A7 through E7 were determined and are presented in TABLE 13. lpív nn / Lznz / E / YiAi Table 13 Rheology at 120°F A7 (base) B7 (latex) C7 (SAS) D7 (SASlatex 75 / 25) E7 (SASlatex 50 / 50) Viscosity at 600 rpm (cP) 63.6 65.0 54.5 60.1 64.7 Viscosity at 300 rpm (cP) 36.4 40.1 29.6 33.0 35.3 Viscosity at 200 rpm (cP) 30.6 32.3 23.0 22.8 24.7 Viscosity at 100 rpm (cP) 20.0 21.5 13.1 12.8 14.3 Viscosity at 6 rpm (cP) 10.4 10.8 3.2 3.2 5.7 Viscosity at 3 rpm (cP) 9.5 10.7 2.7 2.2 5.3 Plastic Viscosity (cP) 27.2 24.9 25.0 27.1 29.4 Yield Strength (lb / 100 sq ft) 9.2 15.2 4.6 5.9 5.9 Gel Strength (lb / 100 sq ft) (10 sec / 10 min) 17.3 / 34.3 8.4 / 32.8 2.6 / 24.2 2.7 / 27.1 10.6 / 35.9 Electrical Stability (V) 1480 1548 1500 992 965 The PPT fluid loss and pressure surge loss for samples A7 through E7 were determined at 275°F and are presented in TABLE 14. Table 14 PPT fluid loss at 275°F A7 (base) B7 (latex) C7 (SAS) D7 (SAS-latex 75 / 25) E7 (SAS-latex 50 / 50) Minutes 1 1.05 1.01 0.47 0.34 0.42 5 1.20 1.73 0.76 0.63 0.72 7.5 2.40 2.08 0.95 0.74 0.84 10 2.57 2.34 1.07 0.88 1.00 15 3.44 2.78 1.28 1.10 1.21 20 3.97 3.19 1.44 1.25 1.37 25 4.32 3.59 1.59 1.38 1.57 30 4.69 3.91 1.68 1.51 1.65 PPT (mL) 9.38 7.82 3.36 3.02 3.30 Pressure Surge Loss (mL) 0.0 0.6 0.4 0.1 0.2 Figure 7 is a graph illustrating the decrease in PPT fluid loss at 275°F for oil-based drilling mud compositions that include both SAS and powder latex and that have SAS at a concentration that is greater than or equal to that of the powder latex relative to compositions that do not include one or both of SAS or latex. Samples D7 (SAS-latex 75 / 25) and E7 (SAS-latex 50 / 50) exhibited lower PPT loss and pressure shock loss relative to samples A7 (base), B7 (latex), and C7 (SAS). EXAMPLES The properties of oil-base drilling mud compositions including different concentrations of SAS and latex were evaluated. The base mud composition included 4.3 lbm / bbl of oleophilic clay, 4.25 lbm / bbl of a primary emulsifier, 0.8 lbm / bbl of an oil wetting agent, 1.0 lbm / bbl of a secondary emulsifier, 21.50 lbm / bbl of calcium chloride, 53 lbm / bbl of barite, 1.86 lbm / bbl of lime, and had an oil-to-water ratio of 85 / 15. The base composition had a density of 9.33 lbm / gal. Four samples were prepared: A8) base, B8) base with 2.0 lbm / bbl of powdered latex, C8) base with 4.0 lbm / bbl of SAS, D8) base with 2.0 lbm / bbl of SAS and 2.0 lbm / bbl of powdered latex (50 / 50 or 1:1 SAS-latex blend). The samples were hot rolled for 16 hours at 250°F. The rheological properties of samples A8 through D8 were determined and are presented in TABLE 15. Table 15 Rheology at 120°F A8 (base) B8 (latex) C8 (SAS) D8 (SASlatex 50 / 50) Viscosity at 600 rpm (cP) 63.6 65.0 54.5 64.7 Viscosity at 300 rpm (cP) 36.4 40.1 29.6 35.3 Viscosity at 200 rpm (cP) 30.6 32.3 23.0 24.7 Viscosity at 100 rpm (cP) 20.0 21.5 13.1 14.3 Viscosity at 6 rpm (cP) 10.4 10.8 3.2 5.7 Viscosity at 3 rpm (cP) 9.5 10.7 2.7 5.3 Plastic Viscosity (cP) 27.2 24.9 25.0 29.4 Yield Strength (lb / 100 sq ft) 9.2 15.2 4.6 5.9 Gel Strength (lb / 100 sq ft) (10 sec / 10 min) 17.3 / 34.3 18.4 / 32.8 2.6 / 24.2 10.6 / 35.9 Electrical Stability (V) 1480.0 1548.0 1500.0 965.0 The PPT fluid loss and pressure surge loss for samples A8 through D8 were determined at 300°F and are presented in TABLE 16. lpív nn / Lznz / E / YiAi Table 16 PPT Fluid Loss at 300°F A8 (Base) B8 (Latex) C8 (SAS) D8 (SAS-Latex 50 / 50) Minutes 1 0.89 0.35 0.48 0.30 5 1.40 0.68 0.91 0.63 7.5 1.79 0.94 1.39 0.85 10 1.90 1.04 1.51 1.07 15 2.11 1.25 1.72 1.23 20 2.23 1.36 1.84 1.37 25 2.40 1.51 1.96 1.49 30 2.52 1.66 2.07 1.57 PPT (mL) 5.04 3.32 4.14 3.14 Pressure surge loss (mL) 1.1 0.1 0.2 0.0 Figure 8 is a graph illustrating the decrease in PPT fluid loss at 300°F for oil-based drilling mud compositions that include both SAS and powder latex and that have SAS at a concentration that is equal to that of the powder latex relative to compositions that do not include one or both of SAS or latex. Sample D8 (50 / 50 SAS-latex blend) showed less PPT loss compared to samples A8 (base), B8 (latex) and C8 (SAS). EXAMPLE 9 The properties of oil-base drilling mud compositions including different concentrations of SAS and latex were evaluated. The base mud composition included 4.0 lbm / bbl of oleophilic clay, 5 lbm / bbl of a primary emulsifier, 4 lbm / bbl of an oil-wetting agent, 25% calcium chloride, 302 lbm / bbl of barite, 4 lbm / bbl of lime, and had an oil-to-water ratio of 85 / 15. The base composition had a density of 13.6 lbm / gal. Four samples were prepared: A9) base, B9) base with 4.0 lbm / bbl of powdered latex, C9) base with 4.0 lbm / bbl of SAS, D9) base with 2.0 lbm / bbl of SAS and 2.0 lbm / bbl of powdered latex (50 / 50 or 1:1 SAS-latex blend). The samples were hot rolled for 16 hours at 250°F. The rheological properties of samples A9 through D9 were determined and are presented in TABLE 17. lpív nn / Lznz / E / YiAi Table 17 Rheology at 120°F A9 (base) B9 (latex) C9 (SAS) D9 (SASlatex 50 / 50) Viscosity at 600 rpm (cP) 142.7 185.0 138.2 161.4 Viscosity at 300 rpm (cP) 84.6 108.9 74.4 95.8 Viscosity at 200 rpm (cP) 64.7 81.2 60.4 74.1 Viscosity at 100 rpm (cP) 41.1 50.9 35.5 46.5 Viscosity at 6 rpm (cP) 12.8 14.8 10.3 14.1 Viscosity at 3 rpm (cP) 10.7 12.9 9.2 12.2 Plastic Viscosity (cP) 58.1 76.1 54.4 65.6 Yield Strength (lb / 100 sq ft) 26.5 32.8 22.5 30.2 Gel Strength (lb / 100 sq ft) (10 sec / 10 min) 11.7 / 14.5 14 / 18.2 5.6 14.2 13.1 / 16.4 Electrical Stability (V) 339.0 399.0 400.0 428.0 The PPT fluid loss and pressure surge loss for samples A9 through D9 were determined at 300°F and are presented in TABLE 18. Table 18 PPT Fluid Loss at 300°F A9 (Base) B9 (Latex) C9 (SAS) D9 (SAS-Latex 50 / 50) Minutes 1 0.24 0.12 0.24 0.11 5 0.49 0.22 0.41 0.21 7.5 0.77 0.30 0.49 0.25 10 0.85 0.36 0.53 0.28 15 0.95 0.44 0.66 0.38 20 1.04 0.59 0.73 0.45 25 1.14 0.66 0.76 0.50 30 1.22 0.71 0.84 0.53 PPT (mL) 2.44 1.42 1.68 1.06 Pressure surge loss (mL) 0.0 0.0 0.2 0.0 Figure 9 is a graph illustrating the decrease in PPT fluid loss at 300°F for oil-based drilling mud compositions that include both SAS and latex and that have SAS at a concentration that is equal to that of powdered latex relative to compositions that do not include one or both of SAS or latex. Sample D9 (50 / 50 SAS-latex blend) showed less PPT loss compared to samples A9 (base), B9 (latex) and 09 (SAS). EXAMPLE 10 The properties of water-based drilling mud compositions including various additives were determined. One base mud composition included 7.0 pounds per barrel (lbm / bbl) of bentonite, 2 lbm / bbl of polyanionic cellulose, 0.75 lbm / bbl of a biopolymer, 10 lbm / bbl of Rev Dust™ inert particulate material (Milwhite, Inc., Brownsville, Texas), 0.5 lbm / bbl of caustic soda, and 2 lbm / bbl of sodium sulfite. The base composition had a density of 9.5 lbm / gal. Ten samples were prepared: A10) base, B10) base with 6 lbm / bbl of SAS mixed with causticized lignite (Soltex®, Drilling Specialties Company, The Woodlands, Texas), C10) base with 6 lbm / bbl of asphalt 1 (Anco Phalt™, Anchor Drilling Fluids, Tulsa, Oklahoma), D10) base with 6 lbm / bbl of asphalt 2 (Asphasol Supreme™, MI Swaco, Houston, Texas), E10) base with 6 lbm / bbl of asphalt 3 (Baro-Trol® Plus, Halliburton, Houston, Texas), F10) base with 6 lbm / bbl of asphalt 4 (Martrol, Marbar SRL, Buenos Aires, Argentina), G10) base with 6 lbm / bbl of asphalt 5 (NewPhalt™, Newpark Drilling Fluids, The Woodlands, Texas), H10) base with 6 lbm / bbl of gilsonite 1 (Super-Bore-Trol™, Servicios Petroleros ZV, Monterrey, Mexico) 110) base with 6 lbm / bbl of gilsonite 2 (Super Shield™, Patriot, Kenner, LA) and J10) base with 4.8 lbm / bbl of SAS and 1.2 lbm / bbl of powdered latex (latex blend) (80 / 20 or 4:1 SAS-latex blend). The samples were hot rolled for 16 hours at 250°F.The PPT loss and pressure surge loss of the samples were determined at 275°F and are presented in TABLE 19. Table 19 PPT Fluid Loss at 275°F A10 B10 C10 D10 E10 F10 G10 H10 110 J10 Minutes 1 3.98 2.14 2.24 3.66 4.31 4.17 4.04 2.86 3.34 1.70 5 7.02 4.30 4.51 6.30 6.27 6.70 6.04 5.22 5.73 4.10 7.5 8.53 5.05 5.21 7.47 7.28 7.89 7.18 6.08 6.66 4.80 10 9.38 5.83 5.85 8.35 7.89 8.93 7.80 6.84 7.53 5.50 15 11.43 7.48 6.83 10.25 8.82 10.10 8.87 7.67 8.61 6.83 20 12.99 8.44 8.61 11.79 9.86 11.65 9.90 9.09 9.49 7.56 25 14.42 9.30 9.24 13.30 10.85 11.93 10.93 10.06 10.75 8.83 30 15.32 10.38 9.92 13.97 11.47 13.05 11.96 10.92 11.67 9.45 PPT (mL) 39.12 20.76 19.84 27.94 22.94 26.10 23.92 21.84 23.34 18.90 Pressure Surge Loss (mL) 2.8 0.5 1.2 2.5 5.4 4.5 4.3 2.3 3.1 0.2 Figure 10 is a graph illustrating the decrease in PPT fluid loss and pressure surge loss at 275°F for water-based drilling mud compositions that include both SAS and powder latex and that have SAS at a concentration that is greater than that of the powder latex relative to compositions that include other additives. Sample J10, which included the SAS-latex blend, exhibited lower PPT loss and pressure surge loss than all other samples. EXAMPLE 11 The properties of oil-base drilling mud compositions including different additives were determined. The base mud composition included 9.0 lbm / bbl of oleophilic clay, 4.0 lbm / bbl of a primary emulsifier, 6.0 lbm / bbl of an oil wetting agent, 20 lbm / bbl of Rev Dust™ inert particulate material (Milwhite, Inc., Brownsville, Texas), 161.2 lbm / bbl of barite, 6.0 lbm / bbl of lime, 2.0 lbm / bbl of sodium sulfite, and had an oil-to-water ratio of 85 / 15. The base composition had a density of 11.0 lbm / gal. Ten samples were prepared: A11) base, B11) base with 2 lbm / bbl of gilsonite 1 (BARABLOK™ seepage control additive, Halliburton, Houston, Texas), C11) base with 2 lbm / bbl of asphalt 1 (BARO-TROL® PLUS shale stabilizer, Halliburton, Houston, Texas), D11) base with 2 lbm / bbl of asphalt 2 (Carbo-Trol™ fluid loss reducer, Baker Hughes, Houston, Texas), E11) base with 2 lbm / bbl of gilsonite 2 (Ecco-Block™ seepage control agent, Baker Hughes, Houston, Texas), F11) base with 1.6 lbm / bbl of SAS and 0.4 lbm / bbl of latex powder (80 / 20 or 4:1 SAS-latex blend), G11) base with 2 lbm / bbl of gilsonite 3 (Gilsonite® HT, American Gilsonite Company, Houston, TX), H11) base with 2 lbm / bbl of SAS, 111) base with 6 lbm / bbl of asphalt 3 (xylan), and J11) base with 4.8 lbm / bbl of gilsonite 4 (Versatrol™, MI Swaco, Houston, Texas). The samples were hot rolled for 16 hours at 250°F. The rheological properties of the samples were determined at 150°F and are presented in TABLE 20. Table 20 PPT Fluid Loss at 300°F A11 B11 C11 D11 E11 F11 G11 H11 111 J11 Viscosity at 600 rpm (cP) 47.9 48.9 50.8 48.4 52.4 50.3 51.8 54.4 59.5 49.9 Viscosity at 300 rpm (cP) 27.6 26.3 31.0 28.8 31 27.7 30 32.2 29.6 28.9 Viscosity at 200 rpm (cP) 19.7 18.2 24.5 20.1 23.9 18.5 23.5 23.2 29.6 28.9 Viscosity at 100 rpm (cP) 13.5 12.0 16.2 13.7 14.9 12 14.7 14.6 13.7 13.1 Viscosity at 6 rpm (cP) 5.9 4.7 6.1 5.6 5.8 4.6 5.9 4.8 5.5 5.1 Viscosity at 3 rpm (cP) 5.5 4.3 5.7 5.4 5.4 4.2 5.5 4.6 5.2 4.8 Plastic Viscosity (cP) 20.3 22.6 19.8 19.6 21.4 22.6 21.8 22.2 20.3 21 Yield Strength (lb / 100 ft2) 7.3 3.7 11.2 9.2 9.6 5.1 8.2 10 9.3 7.9 Gel Strength (lb / 100 sq ft) (10 sec / 10 min) 7.4 / 9.9 6.8 / 8.9 8.2 / 11.1 7.6 / 10.7 7.5 / 9.9 7.2 / 11.6 7.7 / 10.4 6.9 / 11.7 7.3 / 10.3 7.1 / 10.3 Electrical Stability (V) 1367 1513 1325 1364 1403 1804 1558 1944 1643 1680 Sample F11 including the SAS-latex mixture exhibited higher electrical stability than all other samples except sample H11 including SAS. The PPT loss and pressure surge loss of the samples were determined at 300°F and are presented in TABLE 21. ltíw nn / Lznz / E / YiAi Table 21 PPT Fluid Loss at300°F A11 B11 C11 D11 E11 F11 G11 H11 111 J11 Minutes 1 2.23 1.63 1.43 1.48 1.62 1.20 1.74 1.50 1.44 1.40 5 2.76 2.32 2.65 2.62 2.16 1.87 2.67 1.94 2.13 1.88 7.5 3.26 2.85 3.15 3.02 2.57 2.14 3.07 2.46 2.48 2.32 10 3.62 3.06 3.87 3.49 2.74 2.55 3.87 2.68 2.74 2.59 15 3.95 3.39 4.54 3.99 3.01 2.76 3.67 2.95 3.11 2.96 20 4.21 3.59 4.97 4.45 3.24 3.01 4.03 3.24 PPT 3.45 3.22 25 4.51 3.85 5.37 4.82 3.52 3.24 4.35 3.52 3.70 3.45 30 4.77 4.09 5.73 5.09 3.83 3.50 4.70 (mL) 9.54 8.18 11.46 10.18 7.66 7.00 9.40 7.60 8.14 7.30 Pressure Surge Loss (mL) 3.10 2.41 1.09 1.58 2.31 1.53 2.43 1.92 1.70 1.60 Figure 11 is a graph illustrating the decrease in PPT fluid loss and pressure surge loss at 300°F for oil-based drilling mud compositions that include both SAS and powder latex and that have SAS at a concentration that is greater than that of the powder latex relative to compositions that include other additives. Sample F11, which included the SAS-latex blend, exhibited lower PPT loss and pressure shock loss than all other samples. EXAMPLE 12 The properties of water-based drilling mud compositions including different concentrations of SAS and latex powder were evaluated. A base mud composition included 5.0 pounds per barrel (lbm / bbl) of bentonite, 17.5 lbm / bbl of potassium chloride, 0.5 lbm / bbl of HTHP polymer 1, HTHP polymer 2, 25% of a diluent, 50 lbm / bbl of calcium carbonate, and 0.75 lbm / bbl of caustic. The base composition had a density of 10.0 lbm / gal. Three samples were prepared: A12) base, B12) base with 6 lbm / bbl of SAS and C12) base with 4.8 lbm / bbl of SAS and 1.2 lbm / bbl of powdered latex (SAS-latex blend 80 / 20 or 4:1). The samples were hot rolled for 16 hours at 250°F. The rheological properties of samples A12 to C12 were determined and are presented in TABLE 22. Table 22 Rheology at 120°F A12 (base) B12 (SAS) C12 (SAS Latex 80 / 20) Viscosity at 600 rpm (cP) 90.2 103.1 99.1 Viscosity at 300 rpm (cP) 62.4 78.4 70.4 Viscosity at 200 rpm (cP) 49.4 61.1 56.8 Viscosity at 100 rpm (cP) 34.6 43.1 40.1 Viscosity at 6 rpm (cP) 6.7 9.5 8.1 Viscosity at 3 rpm (cP) 4.4 7.3 5.9 Plastic Viscosity (cP) 27.8 29.7 28.7 Yield Strength (lb / 100 sq ft) 34.6 43.7 41.7 Gel Strength (lb / 100 ft2) (10 sec / 10 min) 3.2 / 5.3 9.0 / 6.1 6.3 / 5.1 Len? nn / Lznz / E / YiAi The HTHP fluid loss and API loss for samples A12 through C12 were determined at 375°F and are presented in TABLE 23. Table 23 HTHP Fluid Loss at 375°F A12 (Base) B12 (SAS) C12 (SAS-Latex 80 / 20) Minutes 1 3.68 3.40 3.31 5 5.82 5.39 5.23 7.5 6.83 6.30 6.19 10 7.35 7.11 6.91 15 8.69 8.45 8.32 20 9.82 9.68 9.48 25 10.79 10.68 10.46 30 11.60 11.50 11.25 HTHP (mL) 23.20 23.00 22.50 API Filtrate (mL) 3.4 4.1 3.1 Figure 12 is a graph illustrating API and HTHP filtrate volumes at 375°F for water-based drilling mud compositions that include both SAS and powder latex and that have SAS at a concentration that is greater than that of the powder latex relative to compositions that do not include one or both of SAS or latex. Sample C12 with the SAS-latex blend exhibited lower HTHP loss and lower API loss than the other samples. EXAMPLE 13 The properties of water-based drilling compositions including different concentrations of SAS, powdered latex, and liquid latex were determined. A base mud composition included 7.0 pounds per barrel (lbm / bbl) of bentonite, 17.5 lbm / bbl of potassium chloride, 2 lbm / bbl of Drispac® SL polymer (Drilling Specialties Company, The Woodlands, TX), 0.75 lbm / bbl of Flowzan® biopolymer (Drilling Specialties Company, The Woodlands, TX), and 0.75 lbm / bbl of caustic agent. The base composition had a density of 9.2 lbm / gal / L. Four samples were prepared: A13) base, B13) base with 6 lbm / bbl of SAS, C13) base with 4.8 lbm / bbl of SAS and 1.2 lbm / bbl of powdered latex (SAS-latex mixture 80 / 20 or 4:1), and D13) base with 9 lbm / bbl of liquid latex. The samples were hot rolled for 16 hours at 150°F. The rheological properties and shale recovery of samples A13 to D13 were determined and are presented in TABLE 24. lpív nn / Lznz / E / YiAi Table 24 Rheology at 120°F A13 (Base) B13 (SAS) C13 (SAS Latex Powder 80 / 20) D13 (Liquid Latex) Viscosity at 600 rpm (cP) 58.8 64.1 58 63.3 Viscosity at 300 rpm (cP) 39.8 44.5 39.8 42.1 Viscosity at 200 rpm (cP) 31.8 37.2 31.8 33.3 Viscosity at 100 rpm (cP) 22.3 26.6 22.3 22.3 Viscosity at 6 rpm (cP) 6.6 8.7 6.6 5.1 Viscosity at 3 rpm (cP) 5.2 6.7 5.2 3.7 Plastic Viscosity (cP) 19 19.6 19 21.2 Yield Strength (lb / 100 sq ft) 20.8 24.9 20.8 20.9 Gel Strength (lb / 100 sq ft) (10 sec / 10 min) 5.6 / 9.5 7.3 / 9.9 5.6 / 9.5 4.9 / 5.8 % Shale Recovery 75.82 68.07 91.7 88.95 Sample C13 with the SAS-latex powder mixture had the highest shale recovery. EXAMPLE 14 Several oil-base mud field samples (a first sample was a 13.8 lbm / gal (oil-to-water ratio) 82 / 18 OWR field mud obtained from the Eagle Ford area, and a second sample was a 9.5 lbm / gal OWR field mud obtained from the Rocky Mountain region) were evaluated for lubricity by different methods including an extreme pressure (EP) lubricity meter and a dynamic lubricity evaluation monitor (LEM). A solid-state lubricant (80 / 20 or 4:1 SAS-latex blend) was evaluated with a tribometer to produce a continuous Stribeck curve that allows evaluation of the lubricant throughout the lubricity range. The CoF results obtained from the EP lubricity meter were transformed by calculating the Stribeck number to construct the curve. The reduction in CoF in the boundary lubrication region occurs when the asperities of the wellbore and the bit / BHA are in contact.This is explained by the adsorption of the novel solid-state lubricant onto the asperities, resulting in a smooth surface. The novel solid-state lubricant has a broad particle size distribution (PSD) to cover different asperity sizes and heights. The Stribeck curves of the novel solid-state lubricant show that the lubricant can reduce the CoF in the boundary lubrication region where frictional forces are greatest compared to a base fluid and other liquid lubricants. EP Lubricity Meter: The most common lubricity test measures the fluid resistance of various lubricant additives. The standard coefficient of lubricity test is run at 60 rpm with 150 in-lb of force (the equivalent of approximately 600 psi (4,137 kPa) of intermediate fluid pressure) and is applied to two hardened steel surfaces, a rotating ring, and a stationary block. Friction is measured as the CoF (µ). The CoF between two solids is defined as the frictional force of the load or the force perpendicular to the surfaces. The CoF is independent of the apparent areas of contact as long as this area is not so small as to penetrate the film. The force to overcome friction will be the same for a small area as for a larger area.The force, F, required to slide the block and ring surfaces against each other at a given speed is measured by the power required to rotate the test ring shaft at a prescribed speed of revolutions per minute. The coefficient of friction (CoF), μ = gauge reading / load or force. Lubricity Evaluation Monitor: The Lubricity Evaluation Monitor (LEM) is a laboratory device designed to evaluate lubricants by direct comparison. It determines the CoF between an exchangeable wellbore sample (casing, formation, sandstone, etc.) pressed against a rotating steel paddle while submerged in a circulating cup of test fluid. The LEM measures relative friction factors at ambient temperature and pressure. It is designed to provide lubricity comparisons between different fluid systems and / or fluid additives. The unit can use friction materials such as sandstone or casing. A pneumatic ram applies a lateral load, which pushes the paddle against the sample, and periodically renews the test fluid by pulling the paddle away from the sample at definable intervals. The clamp allows casing, formation, sandstone, etc. samples to be evaluated in the same device.The LEM has computerized data acquisition and control software. The user enters the rotational speed, lateral load, and turnover parameters. Test files provide access to historical data graphs including: rotational speed (RPM), torque (in-lb), lateral load (lb), and CoF over time. The test is run, and the machine collects 600 data points or until the CoF values ​​have stabilized. Tribometer: When lubrication is applied to reduce wear / friction on moving surfaces, the lubrication contact at the interface can change between several regimes, including boundary, mixed, and hydrodynamic lubrication. Fluid film thickness plays an important role in this process, primarily determined by fluid viscosity, the load applied at the interface, and the relative velocity between the two surfaces. How lubrication regimes react to friction is shown in what is known as a Stribeck curve. The tribometer demonstrates a method capable of measuring a continuous Stribeck curve. Using advanced continuous speed control, from 2000 to 0.01 rpm, the software directly provides a complete Stribeck curve within 10 minutes.The simple initial setup only requires users to select exponential ramp mode and enter the initial and final velocities, rather than having to perform multiple tests or program a step-by-step procedure at different speeds that requires data stitching for conventional Stribeck curve measurements. The Stribeck curve graphs the CoF as a function of viscosity, speed, and load. The vertical axis is the CoF, and the horizontal axis is a parameter that combines the other variables. Measurement Objective: Stribeck curves were measured with two lubricating oils with different kinetic viscosities for comparison. A pin-on-disc tribometer equipped with the lubrication module was used. The rotational speed decreased at an exponential rate from 2000 to 0.01 rpm to demonstrate the continuous Stribeck curve measurement and the precise sensitivity of the tribometer's capabilities. Initial lubricity data was obtained using a standard EP lubricity meter. Typically, CoF is defined based on a torque load of 150 in-lb while rotating at 60 rpm. However, when the CoF is plotted against the base fluid torque load and base fluid containing 2 and 3 lbm / bbl of solid-state lubricant (80 / 20 or 4:1 SAS-latex blend), the shape of the fitted curve exhibited a characteristic profile. As seen in Figure 13, the solid-type lubricant (80 / 20 or 4:1 SAS-latex blend) exhibited a lower CoF at lower torque loads. Figure 13 is a graph illustrating the variation in the coefficient of friction with torque for oil-base drilling mud compositions that include a solid lubricant. EXAMPLE 15 The EP lubricity meter results were then graphed to construct the Stribeck curve (lpív nn / Lznz / E / YiAi). The x-axis is the Stribeck number = g*V / W, calculated using rpm (60) and torque load, and a dynamic viscosity of 1 is assumed to give a different perspective on the curve profile. The results are shown in Figure 14, which shows the behavior of the solid-type lubricant (80 / 20 or 4:1 SAS-latex blend) at 2 lbm / bbl, 3 lbm / bbl, and 4 lbm / bbl in the boundary lubrication regime at lower Stribeck numbers. The lubricant reduces the CoF at the boundary condition compared to the base fluid. Figure 14 is a graph illustrating the variation in coefficient of friction with Stribeck number for oil-based drilling mud compositions that exclude and include a solid lubricant. The base drilling mud composition included a 90 / 10 OWR (oil-to-water ratio) of 8.2 Ibm / bbl with Gibson D822 oil (Gibson Energy, Houston, Texas). The same method was used to calculate the Stribeck curve of the same fluid containing 10 lbm / bbl of Rev Dust™ inert particulate matter (Milwhite, Inc., Houston, TX). The effect on the CoF of the sample with 2.0 lbm / bbl of lubricant is clear in the presence of the simulated low gravity solids at the boundary condition. Figure 15 is a graph illustrating the variation in coefficient of friction with Stribeck number for oil-base drilling mud compositions that exclude and include a solid lubricant and the friction-reducing particulate matter. The base drilling mud composition included 8.2 lbm / bbl 90 / 10 OWR with Gibson D822 oil (Gibson Energy, Houston, Texas). Another base fluid was used to evaluate the lubricant and the results are shown in Figure 16. The effect of the lubricant on the boundary lubrication condition was observed with a mineral OWR 90 / 10 OMB (oil-base mud) with 5.0 lbm / bbl of organophilic clay. The base drilling mud composition included 8.2 lbm / bbl OWR 90 / 10 with PureDrill™ HT 40 oil (Petro-Canada, Mississauga, Canada). Figure 16 is a graph illustrating the variation in coefficient of friction with Stribeck number for oil-base drilling mud compositions excluding and including a solid lubricant and an organophilic clay. EXAMPLE 16 The CoF was examined using a dynamic lubricity meter. Unlike the EP lubricity meter, where the CoF was measured with the same film as the torque load increased, the LEM's contact between the rotor and the block is continuously renewed as the fluid circulates. Tests were carried out in several stages until a stable dynamic CoF was obtained. A laboratory sample of 85 / 15 OWR and OBM diesel at 11.0 lbm / gal and a base fluid sample containing 2.0 lbm / bbl of solid-state lubricant were evaluated at the LEM. Although the measured CoF of both samples was 0.12, an evaluation of the data showed that the fluid not containing the solid-state lubricant had a higher static CoF compared to the fluid containing the solid-state lubricant. The static CoF is the maximum peak observed at the beginning of each stage as the rotor begins to move into the boundary condition. EXAMPLE 17 The Stribeck curves of fluids containing the solid-state lubricant (80 / 20 or 4:1 SAS-latex blend) were evaluated against those of liquid lubricants and their performance under boundary conditions. The tribometer is capable of producing a continuous Stribeck curve while varying the rpm between 0.01 and 1000 rpm. Instrument rotational speeds between 0.01 and 250 rpm were used for practical purposes. A fixed load of 150 in-lb was also selected when measuring CoF values. The same fluid tested in the LEM was used to construct the Stribeck curves with the tribometer. Four tests were run, including the base fluid (BF) and base fluid samples containing 2.0 lbm / bbl of solid-state lubricant and 2% by volume of two liquid lubricants. The results are shown in Figures 17, 18, and 19. Figure 17 is a graph illustrating the coefficient of friction with time for a base oil drilling mud composition. Figure 18 is a graph illustrating the coefficient of friction with time for a base oil drilling mud composition that includes the solid lubricant. Figure 19 is a graph illustrating the variation of the coefficient of friction with Stribeck number for oil-based drilling mud compositions that exclude a lubricant, that include a solid lubricant, and that include two different liquid lubricants. Lubricant 2 (Torque-Buster, Franklin Well Services, Vincennes, Indiana) performed poorly and had an adverse effect on the base fluid CoF. Lubricant 1 (Turbo-Lube, Granja-Oyl®, St. Paul, MN) performed better than Lubricant 2, providing a slight decrease in static CoF and a similar dynamic CoF. The solid-state lubricant resulted in a reduction in both static and dynamic CoF across the rpm range. The dynamic CoF of the base fluid with 2.0 lbm / bbl of solid lubricant decreased continuously after 1.2 minutes. In contrast, of the liquid lubricants tested, one produced no improvement in static or dynamic CoF, and the other produced an adverse effect on both static and dynamic CoF. Without being limited by theory, solid lubricant works in the boundary lubrication regime by producing a tribofilm, which reduces viscosity. EXAMPLE 18 A field trial was carried out with the novel solid lubricant in the lpív nn / Lznz / E / YiAi Basin Permian with a direct emulsion water-base mud. The purpose of the field trial was to evaluate the potential replacement of OBM with direct emulsion mud and solid-state lubricant (80 / 20 or 4:1 SAS-latex blend). The solid-state lubricant was added by applying pellets at a concentration of 3.0 lbm / bbl until a final concentration of 3.0 lbm / bbl was reached in the circulating system. The operator increased the concentration to 6.0 lbm / bbl throughout the entire depth of the interval. A summary of the field trial conducted in the Permian Basin was evaluated. An overall increase in rate of penetration (ROP) was observed with 6.0 lbm / bbl compared to 3.0 lbm / bbl of solid-state lubricant while maintaining a similar torque load. The increase and decrease in weight was recorded along the horizontal section. Figure 20 is a graph illustrating the variation in weight increase and decrease along a horizontal section with depth. While an increase in both weight increase and decrease is expected with increasing depth, both curves show a decrease in both measurements. The trend in both curves is smooth when the solid lubricant concentration reached 3.0 lbm / bbl throughout the system. The invention has been described above with reference to numerous aspects, embodiments, and specific examples. Many variations will occur to those of ordinary skill in the art in light of the foregoing detailed description. All such obvious variations are within the full intended scope of the appended claims. Other aspects of the invention may include, but are not limited to, the following aspects. Many aspects are described as comprising certain components or steps, but may alternatively consist essentially of or consist of those components or steps unless specifically stated otherwise.

Claims

1. A drilling mud composition, comprising: a first concentration of powdered latex; and a second concentration of sodium asphalt sulfonate (SAS), wherein the second concentration of SAS (by mass) is greater than or equal to the first concentration of latex (by mass).

2. The drilling mud composition according to claim 1, wherein the second SAS concentration is greater than the first latex concentration.

3. The drilling mud composition according to claim 1 or 2, wherein the powdered latex comprises at least one of a styrene-butadiene copolymer or an ethylene-vinyl acetate copolymer.

4. The drilling mud composition according to any of claims 1 to 3, wherein the powdered latex has a population average particle size in the range of about 70 micrometers to about 100 micrometers.

5. The drilling mud composition according to claim 4, wherein the average population particle size is in the range of about 80 micrometers to about 90 micrometers.

6. The drilling mud composition according to claim 5, wherein the average population particle size is about 85 micrometers.

7. The drilling mud composition according to any of claims 1 to 6, wherein the drilling mud composition comprises a water-based carrier, wherein the second SAS concentration is greater than the first latex concentration, and wherein the drilling mud composition has an average high temperature high pressure (HTHP) fluid loss at 250°F and 500 pounds per square inch (psi) of less than or about 20 mL when evaluated according to American Petroleum Institute (API) Test 13B-1.

8. The drilling mud composition according to claim 7, having a coefficient of friction of less than or about 0.40 at a torque of 250 lbf.

9. The drilling mud composition according to claim 7 or 8, wherein the drilling mud composition has an average permeability plugging test (PPT) loss at 250°F with a 12 lpiv nn / Lznz / E / YiAi micrometer filtration disc of less than or about 18.0 mL when evaluated according to API Test 13B-1.

10. The drilling mud composition according to any of claims 7 to 9, wherein the drilling mud composition has a plastic viscosity at 120°F in the range of about 20 cP to about 30 cP when evaluated according to American Petroleum Institute (API) test 13B-1.

11. The drilling mud composition according to any of claims 7 to 10, wherein the drilling mud composition has a yield strength at 120°F in the range of about 20 lb / 100 ft2 to about 45 lb / 100 ft2 when evaluated in accordance with American Petroleum Institute (API) test 13B-1.

12. The drilling mud composition according to any one of claims 7 to 11, wherein the drilling mud composition has a gel strength in 10 seconds at 120°F in the range of about 5.5 to about 6.5 lb / 100 ft2 when evaluated according to American Petroleum Institute (API) test 13B-1.

13. The drilling mud composition according to any of claims 7 to 12, wherein the drilling mud composition has a gel strength at 10 minutes at 120°F in the range of about 5 to about 12 lb / 100 ft2 when evaluated according to American Petroleum Institute (API) test 13B-1.

14. The drilling mud composition according to any of claims 7 to 13, wherein the first concentration of powdered latex is at least 1 pound per barrel (lb / bbl), and wherein the second concentration of SAS is at least 2 lb / bbl.

15. The drilling mud composition according to claim 14, wherein the first concentration of powdered latex is in the range of about 1.5 to about 2.5 lbm / bbl, and wherein the second concentration of SAS is in the range of about 2.5 to about 3.5 lbm / bbl.

16. The drilling mud composition according to claim 15, wherein the first concentration of powdered latex is about 2 lb / bbl, and wherein the second concentration of SAS is about 3 lb / bbl.

17. The drilling mud composition according to claim 14, wherein the first concentration of powdered latex is about 1.5 lb / bbl, and wherein the second concentration of SAS is about 4.5 lb / bbl.

18. The drilling mud composition according to claim 14, wherein the first concentration of powdered latex is about 1.2 lb / bbl, and wherein the second concentration of SAS is about 4.8 lb / bbl.

19. A method comprising dispersing a first predetermined amount of powdered latex and a second predetermined amount of SAS in a water-based carrier to form a water-based slurry comprising the composition according to claim 1 to 18.

20. The drilling mud composition according to any of claims 1 to 6, wherein the drilling mud composition comprises an oil-based carrier, and wherein the drilling mud composition has an average permeability plugging test (PPT) fluid loss at 300°F with a 55-micrometer filter disk of less than or about 1.06 mL when evaluated in accordance with American Petroleum Institute (API) Test 13B-2.

21. The drilling mud composition according to claim 20, wherein the drilling mud composition has a plastic viscosity at 120°F in the range of about 20 cP to about 30 cP when evaluated according to API test 13B-2.

22. The drilling mud composition according to any of claims 20 to 21, wherein the drilling mud composition has a yield strength at 120°F in the range of about 5 lb / 100 ft2 to about 6 lb / 100 ft2 when evaluated according to API test 13B-2.

23. The drilling mud composition according to any of claims 20 to 22, wherein the drilling mud composition has a gel strength in 10 seconds at 120°F in the range of about 2 to about 11 lb / 100 ft2 when evaluated according to API test 13B-2.

24. The drilling mud composition according to any of claims 20 to 23, wherein the drilling mud composition has a gel strength at 10 minutes at 120°F in the range of about 10 to about 40 lb / 100 ft2 when evaluated according to API test 13B-2.

25. The drilling mud composition according to any of claims 20 to 24, wherein the first concentration of powdered latex is at least about 1 pound per barrel (lb / bbl), and wherein the second concentration of SAS is at least about 1 lb / bbl.

26. The drilling mud composition according to claim 25, wherein the first concentration of powdered latex is about 1 lb / bbl, and wherein the second concentration of SAS is about 3 lb / bbl.

27. The drilling mud composition according to claim 25, wherein the first concentration of powdered latex is in the range of about 1.5 to about 2.5 lbm / bbl, and wherein the second concentration of SAS is in the range of about 1.5 to about 2.5 lbm / bbl.

28. The drilling mud composition according to claim 25, wherein the first concentration of powdered latex is about 2 lb / bbl, and wherein the second concentration of SAS is about 2 lb / bbl.

29. A method comprising dispersing a first predetermined amount of powdered latex and a second predetermined amount of SAS in an oil-based carrier to form an oil-based slurry comprising the composition according to claim 1 to 6 or 20 to 28.

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