Abstract: A drilling fluid comprises one or more deep eutectic solvents in an amount greater than or equal to 70 wt. % based on the total weight of the drilling fluid. Each deep eutectic solvent comprises at least one hydrogen bond acceptor compound and at least one hydrogen bond donor compound. A molar ratio of the total moles of the hydrogen bond donor compounds to the total moles of the hydrogen bond acceptor compounds in each deep eutectic solvent is from 0.1 to 1.0. The drilling fluid has a density greater than or equal to 200 kg/m3. The drilling fluid has a viscosity greater than or equal to 0.5 Pa·s when measured at 25° C. Methods for drilling wells in subterranean formations using the drilling fluid are also disclosed.

Abstract: A method of drilling a wellbore includes pumping an oleaginous wellbore fluid into a wellbore, the oleaginous wellbore fluid including an oleaginous continuous phase; a non-oleaginous discontinuous phase; an emulsifier stabilizing the non-oleaginous discontinuous phase in the oleaginous continuous phase; an organophilic clay; a weighting agent; and a wetting agent having an HLB ranging from about 4 to 10.5 that it selected such that the oleaginous wellbore fluid has a 600 rpm dial value at 40° F. of less than about 300 and a 10 minute gel strength of less than about 40 lbf/100 ft2.

Abstract: Methods and systems for using an invert emulsion fluid that is beneficial in the drilling, completing and working over of subterranean wells are provided. In some embodiments, the method includes: preparing a treatment fluid including an invert emulsion, wherein the invert emulsion further includes an aqueous dispersed phase, an oleaginous continuous phase, and an amine surfactant emulsifier and placing the treatment fluid in a wellbore penetrating at least portion of a subterranean formation.

Abstract: The present invention relates to a composition for dissolving an oil-based filter cake in a wellbore, and a single-step method of use. The composition comprises a chelating agent, a converting agent, a polymer removal agent, a mutual solvent, and a surfactant. The present invention also relates to a multi-step method of dissolving an oil-based filter cake using similar components. Both single-step and multistep methods may be used to dissolve oil-based filter cakes comprising barite as a weighting material.

Abstract: Provided here are water-based drilling fluids containing weighting agents and an alkanolamine, and methods of using such compositions during drilling operations for recovery of hydrocarbons. The weighting agents can include manganese tetroxide and barium sulfate. The alkanolamine can be monoethanolamine. Various other embodiments may be disclosed and claimed.

Abstract: A body lubricating, moisturizing, and anti-inflammatory formulation utilizes a mucilage-containing extract derived from a plant such as okra, Abelmoschus esculentus (Hibiscus esculentus). The formulation can be provided as a free liquid such as a solution, suspension, foam, gel, cream, ointment, or spray or alternatively impregnated into an absorbent solid article such as a wipe, swab, a bandage or a gauze. Application of the formulation to a mucosal or external bodily tissue result in the application of a layer of mucilage that lubricates and moisturizes the tissue as well as protects it from external damage from foreign particles and UV irradiation. Application of the formulation to an inflamed tissue provides anti-inflammatory effects. The formulation can be impregnated into a cloth pad to provide an eyelid wipe.

Abstract: Oil-based drilling fluid compositions comprising an oil phase comprising a base oil, an aqueous phase comprising water, at least one emulsifier, and one or more additives. The at least one emulsifier comprises an amino amide comprising the formula R—CO—NH—R?—NH—R?—NH2, where R is a fatty acid alkyl and R? and R? are alkyl groups. The one or more additives are chosen from a wetting agent, a rheology modifier, a fluid-loss control additive, and a weighting additive. Methods of making the oil-based drilling fluid compositions and methods of drilling a subterranean well utilizing the oil-based drilling fluid compositions are also provided.

Abstract: Various embodiments disclosed relate to methods of cleaning invert emulsion drilling fluids. In various embodiments, the present invention provides a method of cleaning a drilling fluid. The method includes cleaning a used invert emulsion drilling fluid that includes drilled cuttings to form a cleaned invert emulsion drilling fluid. The cleaning includes processing the used invert emulsion drilling fluid in a separator to remove at least some of the drilled cuttings therefrom.

Abstract: Oil-based drilling fluid compositions comprising an oil phase comprising a base oil, an aqueous phase comprising water, at least one emulsifier, and one or more additives. The at least one emulsifier comprises an amino amide comprising the formula R—CO—NH—R?—NH2, where R is a fatty acid alkyl and R? is an alkyl group. The one or more additives are chosen from a wetting agent, a rheology modifier, a fluid-loss control additive, and a weighting additive. Methods of making the oil-based drilling fluid compositions and methods of drilling a subterranean well utilizing the oil-based drilling fluid compositions are also provided.

Abstract: Friction-reducing compositions useful for reducing Operating Torque in a drilling operation are described. Methods of conducting drilling operations using such friction-reducing compositions and lubricant compositions formed from blends of the friction-reducing composition with an oil-based mud composition are also described.

Abstract: Various invert emulsion drilling fluid compositions. One such invert emulsion drilling fluid is a water in oil emulsion, which can include an invert emulsifier to stabilize the water in oil emulsion, a C16 to C18 saturated linear alpha carboxylic acid, a fatty dimer diamine, a filtration control agent, a weighting agent including manganese tetroxide, and a bridging agent including calcium chloride. The invert emulsion drilling fluids can be formulated to be substantially free of clay.

Abstract: Compositions herein may include an oleaginous continuous phase, an aqueous discontinuous phase, a first clay comprising an organophilic smectite clay, and a second clay comprising a magnesium silicate clay. Methods herein may include circulating such fluids downhole as well as admixing a magnesium silicate dispersed clay and an organophilic smectite clay in an oleaginous base fluid.

Abstract: A thinner that is a poly fatty amide reacted with maleic acid to form a product, and diluting the product with a compound selected from the group consisting of oleyl alcohol, fatty acid, and poly condensed fatty acid is able to reduce the viscosity of oil-based drilling fluid, thus allowing for reuse of the oil-based drilling fluid.

Abstract: Methods and systems for maintaining stability of contaminated drilling muds within a desirable range by chemical and/or physical treatment. In one aspect, a method includes injecting a drilling mud in a subterranean zone, the drilling mud including a quantity of a first drilling mud additive including a volcanic ash, determining a presence of a gas associated to a process of the subterranean zone, and neutralizing the gas by injecting a quantity of a second drilling mud additive through the subterranean zone, the second drilling mud additive including a gas neutralizer.

Abstract: The physical properties of a fluid may be used in deriving the compositional properties of the fluid, which may, in turn, be used to influence an operational parameters of a drilling operation. For example, a method may include drilling a wellbore penetrating a subterranean formation with a drilling fluid as part of a drilling operation; circulating or otherwise containing the drilling fluid in a flow path that comprises the wellbore; measuring at least one physical property of the drilling fluid at a first location and a second location along the flow path; deriving a compositional property of the drilling fluid at the first location and the second location based on the at least one physical property that was measured; comparing the compositional property of the drilling fluid at the first location and the second location; and changing an operational parameter of the drilling operation based on the comparison.

Abstract: The present invention relates to a high performance aqueous phase polymer fluid, which is a seawater-based drilling fluid for well drilling in low gradient formations. It is formulated based on liquid state polymer chemical products, easy to aggregate, and quickly mixed; a preparation and homogenization that reduces preparation times, designed to drill hydrocarbon-producing deposits, focusing on minimizing damages to the producing formations, with a high rate of circulation loss in naturally-fractured deposits. The system is environmentally-friendly, it complies with the required main functions of the drilling fluids while also providing a high inhibition control by swelling and dispersion of clay zones, due to the polymeric nature of the materials with which it is formulated. It is a fluid that does not contain solids in its formulation and provides an excellent transport and cleaning of the drilling shears in the well.

Abstract: The invention relates to aqueous, cationically stabilized primary dispersions comprising dispersed polymer particles having a Z-average particle diameter of 5 to 500 nm and which are obtainable by emulsion polymerization of at least one olefinically unsaturated monomer (A). The emulsion polymerization takes place in the presence of one or more emulsifiers (E) having the following general formula: R1—N(R2)(R3), where R1 is a moiety with 15 to 40 carbon atoms which contains at least one aromatic group and at least one aliphatic group, and which contains at least one functional group selected from hydroxyl groups, thiol groups, and primary or secondary amino groups, and/or has at least one carbon-carbon multiple bond, and R2 and R3, independently of one another, are the same or different aliphatic moieties containing 1 to 14 carbon atoms.

Abstract: An imidazoline compound, a mobility control system, a plugging agent for gas channelling, and a method for carbon dioxide flooding. The structure of the imidazoline compound is represented by formula (1), in which R is pentadecyl, heptadecenyl, or heptadecyl. A mobility control system that contains the imidazoline compound can interact with carbon dioxide to form a plugging agent for gas channelling, and thereby attains a plugging effect for carbon dioxide channelling in a carbon dioxide flooding process.

Abstract: Embodiments disclosed herein relate to a method including feeding an invert emulsion wellbore fluid, or a previously used invert emulsion wellbore fluid, into a mixing unit; adding an additive to the mixing unit; delivering the invert emulsion wellbore fluid and the additive to one or more stages of the mixing unit, the mixing unit having a shear rate ranging from about 10,000 s-1 to about 100,000 s-1. The invert emulsion wellbore fluid includes a non-oleaginous fluid being the discontinuous internal aqueous phase of the wellbore fluid, and an oleaginous fluid being the continuous external phase of the wellbore fluid.

Abstract: Systems and methods for creating surfactant-polyelectrolyte complexes at a well site are provided. In one embodiment, the methods comprise: providing a first solution comprising at least one surfactant and a second solution comprising at least one polyelectrolyte; using a stop-flow mixing apparatus at a well site to mix the first and second solutions to form one or more surfactant-polyelectrolyte complexes; using a low-dose pumping apparatus at the well site to transfer the one or more surfactant-polyelectrolyte complexes from the stop-flow mixing apparatus to a blending apparatus at the well site; using the blending apparatus to mix the one or more surfactant-polyelectrolyte complexes with an aqueous base fluid to form a treatment fluid; and introducing the treatment fluid into a well bore penetrating at least a portion of a subterranean formation at the well site.

Abstract: Provided are biocidal compositions comprising 2,2-dibromo-3-nitrilopropionamide and tris(hydroxymethyl)-nitromethane.

Abstract: The invention relates to a fatty amide, which is based on: a) a diamine selected from aromatic or cycloaliphatic or linear C2 to C10 aliphatic diamines, b) a C3 to C12 lactam or amino acid, c) optionally, a second primary diamine different from said diamine a), d) a hydroxylated fatty monoacid, e) optionally, a nonhydroxylated monoacid chosen from linear C6 to C12 aliphatic acids, with a mole ratio b/(a+c) of 0.25 to 3/1. The invention also covers a process for the preparation of said amide and its use as organogelator or rheology additive in an organic solvent medium, in particular in coating, glue or adhesive, mastic, sealant or stripping agent compositions or molding or cosmetic compositions.

Abstract: Disclosed are compositions and methods for treating subterranean formations, in particular, oilfield stimulation compositions and methods using polymer viscosified fluid crosslinked with metal complexes with amino and/or phosphonic acids to provide an increased crosslinking temperature and a low pH sensitivity. The metal complexes can be used with borate crosslinkers to provide continuous viscosification as the temperature is increased.

Abstract: Some embodiments disclosed herein comprise a method of treating a subterranean formation comprising: providing a treatment fluid comprising a base fluid and an extracted natural mucilage; and introducing the treatment fluid into the subterranean formation. The treatment fluid may further comprise a mucin in an amount in the range of from about 0.000001% to about 10% by weight in the treatment fluid.

Abstract: An invert emulsion drilling fluid, and a method of drilling with such fluid, having improved rheology effected with addition of a fatty dimer diamine additive in the presence of little or no lime. The drilling fluids of the present invention exhibit similar yield points and gel strengths at temperatures ranging from about 40° F. to about 375° F. or higher and at pressures ranging from about 0 psi to about 13500 psi.

Abstract: The present invention provides methods and formulations for reducing or inhibiting increase in the concentration of microbes in a water-based fluid. The methods and formulations of the present invention use an oxazolidine compound and a hydroxymethyl-substituted phosphorus compound selected from the group consisting of tetrakis(hydroxymethyl)phosphonium salts, C1-C3 alkyl- and alkenyltris(hydroxymethyl)phosphonium salts and tris(hydroxymethyl)phosphine. The methods and formulations of the present invention can be useful in treating water contaminated with aerobic or anaerobic bacteria in oilfield and other industrial applications.

Abstract: Solid proppants are coated with a coating that exhibits the handling characteristics of a precured coating while also exhibiting the ability to form particle-to-particle bonds at the elevated temperatures and pressures within a wellbore. The coating includes a substantially homogeneous mixture of (i) at least one isocyanate component having at least 2 isocyanate groups, and (ii) a curing agent. The coating process can be performed with short cycle times, e.g., less than about 4 minutes, and still produce a dry, free-flowing, coated proppant that exhibits low dust characteristics during pneumatic handling but also proppant consolidation downhole for reduced washout and good conductivity.

Abstract: The hydration of clays in drilling operations can be inhibited by employing an aqueous based drilling fluid containing from about 0.2 to about 5 wt % of a hydration inhibitor that comprises bis-hexamethylene-triamine, bis-hexamethylene-triamine salts, or mixtures thereof.

Abstract: Solid proppants are coated with a phenol-urethane coating in one or more layers by a method comprising coating a proppant solid and then curing the coated proppant under conditions sufficient to substantially cure said proppant, wherein said coating comprises a substantially homogeneous mixture of (i) an isocyanate component having at least 2 isocyanate groups, (ii) an amine reactant, and optionally (iii) an amine that is a latent curing agent for said isocyanate.

Abstract: Emulsions usable within a wellbore as drilling fluids can be prepared by adding an internal phase to an external phase to form an emulsion base, and adding solid organophilizated mineral structures, a matrix stabilizing agent, a weighting agent, and a secondary stabilizer to the emulsion base. The solid organophilizated mineral structures stabilize the emulsion base and affect the rheology thereof, and the matrix stabilizing agent and the secondary stabilizer can retain the stability and viscosity of the emulsion base in the presence of hydrophilic solids. In addition to use as a wellbore fluid independently, usable emulsions can be compatible with and combined with traditional emulsions to form a mixture usable within a wellbore a drilling fluid.

Abstract: Aqueous and substantially anhydrous fluids having particularly low thermal conductivities and variable densities are disclosed. The fluids include: one or more organic and/or inorganic salts and at least one aprotic polar organic solvent, a mixture of aprotic and protic polar organic solvents, and/or a polar organic solvent having both protic and aprotic polar functional group linkages. The fluids optionally include one or more viscosifying agents and are free of cross-linking agents. Methods for formulating and using the fluids are also disclosed.

Abstract: The present invention concerns the use of a novel additive as an agent for inhibiting the swelling of clays, in particular in the field of boreholes. More specifically, the present invention concerns the use of a specific diamine and diacid salt as an agent for inhibiting the swelling of clays in an aqueous medium, and a drilling or hydraulic fracturing fluid composition comprising the salt according to the invention and methods for drilling or hydraulic fracturing implementing said salt.

Abstract: A wellbore fluid that includes an aqueous based fluid; an amphoteric, viscoelastic surfactant; and a modified starch is disclosed. Methods of drilling subterranean wells, methods of reducing the loss of fluid out of subterranean wells, and methods of completing wellbores using aqueous-based fluids having an ampoteric, viscoelastic surfactant and a modified starch are also disclosed.

Abstract: Nanomaterial compositions are useful for applications in drilling and completion fluids as enhancers of electrical and thermal conductivity, emulsion stabilizers, wellbore strength improvers, drag reduction agents, wettability changers, corrosion coating compositions and the like These nanomaterials may be dispersed in the liquid phase in low volumetric fraction, particularly as compared to corresponding agents of larger size. Nanofluids (fluids containing nano-sized particles) may be used to drill at least part of the wellbore. Nanofluids for drilling and completion applications may be designed including nanoparticles such as carbon nanotubes. These fluids containing nanomaterials, such as carbon nanotubes, meet the required rheological and filtration properties for application in challenging HPHT drilling and completions operations.

Abstract: Degeneration of shale caused by oxygen in aqueous drilling, fracturing and completion fluids is minimized by introducing imidazolines modified so that they will be attracted efficiently to pyrites in the shale, thereby forming a protective coating on the pyrites. Inhibiting oxidation of the pyrites sharply reduces physical degradation of the shale in the presence of drilling, fracturing and completion fluids carrying oxygen. The imidazoline is an ionic salt or a beatine.

Abstract: Compositions of and methods of using a fluid formulation for increasing flow, production, and/or recovery of oil and gas hydrocarbons from a subterranean formation.

Abstract: A composition that includes a product resulting from a condensation reaction of quebracho with at least one organophilic species that includes a reactive amine is disclosed.

Abstract: Emulsions usable within a wellbore as drilling fluids can be prepared by providing an emulsion base that includes a crude biodiesel product, and adding an emulsifying subsystem to the emulsion base. Solid particles in the emulsifying subsystem migrate to interfaces between continuous and discontinuous components in the emulsion base to define phases of the emulsion. A weighting agent can be added, as needed, to provide the emulsion with a suitable mud weight for use in a particular wellbore. Usable crude biodiesel products can include the unmodified product of a transesterification reaction, that include a continuous ester phase and a discontinuous alcohol phase without requiring separation or modification. Usable emulsifying subsystems can be prepared in situ. Use of esters, clays, and/or alcohols can enable reduction or elimination of water, brine, and petrochemicals in the emulsions.

Abstract: The present invention generally relates to emulsifiers for oil-based drilling fluids and muds comprising an emulsifier based on the polyamides derived from fatty acid/carboxylic acid and optionally alkoxylated polyamines. The invention also relates to oil or synthetic based drilling fluids comprising the emulsifiers of the invention and to drilling methods utilizing same.

Abstract: A method of servicing a wellbore in a subterranean formation having one or more lost circulation zones comprising placing a wellbore servicing fluid comprising a sealing composition into the wellbore, wherein the sealing composition comprises a latex and an accelerator and wherein the latex, the accelerator or both are encapsulated with an encapsulation material. A wellbore servicing fluid comprising a latex and an accelerator wherein the latex, the accelerator, or both are encapsulated.

Abstract: Disclosed are compositions and methods for treating subterranean formations, in particular, oilfield stimulation compositions and methods using polymer viscosified fluid crosslinked with metal complexes with amino and/or phosphonic acids to provide an increased crosslinking temperature and a low pH sensitivity. The metal complexes can be used with borate crosslinkers to provide continuous viscosification as the temperature is increased.

Abstract: An invert emulsion drilling fluid, and a method of drilling with such fluid, having improved rheology effected with addition of a fatty dimer diamine additive in the presence of little or no lime. The drilling fluids of the present invention exhibit similar yield points and gel strengths at temperatures ranging from about 40° F. to about 375° F. or higher and at pressures ranging from about 0 psi to about 13500 psi.

Abstract: The present invention provides a method of treating an aqueous system for biocide control, by adding an acidified solution that includes monoalkyldithiocarbamate salt and alkyl isothiocyanate to an aqueous system. A biocide feed system is also provided that is configured to generate a reproducible level of alkyl isothiocyanate. The method and system provide effective levels of alkyl isothiocyanate for rapid biocidal activity, along with levels of monoalkyldithiocarbamate salt which can decompose to form additional alkyl isothiocyanate and provide longer-term biocidal activity.

Abstract: An invert emulsion drilling fluid, and a method for the use thereof in drilling wellbores, with good rheological properties at high temperatures and pressures. One embodiment of the drilling fluids is free of organophilic clays and lignites, free of calcium chloride, and comprises glycerol in the internal phase, and a suspension agent comprising a combination of a fatty dimer diamine and a short chain acid, such as citric acid. In one embodiment, the base oil for the emulsion is a paraffin and/or mineral oil. The drilling fluids provide good rheological properties including good suspension of drill cuttings.

Abstract: According to an embodiment, an invert emulsion drilling fluid comprises: an external phase, wherein the external phase of the drilling fluid comprises a hydrocarbon liquid; an internal phase, wherein the internal phase of the drilling fluid comprises water; and a surfactant, wherein the surfactant: (A) comprises a hydrophobic tail group having a carbon chain length greater than or equal to 16; (B) has a boiling point greater than or equal to 400° F. (204.4° C.); and (C) is in at least a sufficient concentration such that the surfactant spontaneously forms reverse-micelles. According to another embodiment, a method of using the invert emulsion drilling fluid comprises: introducing the drilling fluid into a well.

Abstract: Biodegradable organophilic clays for use in drilling fluids may, in some instances, include clay treated with a surfactant system that includes biodegradable quaternary ammonium surfactants and nonbiodegradable quaternary ammonium surfactants. The biodegradable quaternary ammonium surfactant may be capable of degrading by more than about 90% over 28 days as determined by Method 306 of the OECD Guidelines for the Testing of Chemical.

Abstract: A oil field production fluid, namely a drilling mud composition, comprising a mixture of: (a) at least one base oil component; and (b) an additive component comprising a blend of dibasic esters. The functional fluid can optionally comprise additional additive components. The blend of dibasic esters comprises two or more of dialkyl methylglutarate, dialkyl adipate, dialkyl ethylsuccinate, dialkyl succinate, dialkyl glutarate.

Abstract: A composition that includes a product resulting from a condensation reaction of quebracho with at least one organophilic species that includes a reactive amine is disclosed.

Abstract: Ester based drilling fluids with enhanced stability at high temperatures for drilling, running casing in, and/or cementing a borehole in a subterranean formation. The drilling fluids comprise a monomeric or polymeric carbodiimide hydrolysis inhibitor.

Abstract: An invert emulsion drilling fluid, and a method of drilling with such fluid, having improved rheology at low mud weights and high temperatures. The improved rheology is effected with addition of a rheology additive of the invention comprising fatty dimer diamines or dimer diamines and an organic acid or ester of the acid. A nonlimiting example of such a rheology additive comprises a C36 fatty dimer diamine and adipic acid or dimethyl adipate.