WO2014153102A1 - Procédés et compositions en vue d'une utilisation dans des puits de pétrole et/ou de gaz - Google Patents

Procédés et compositions en vue d'une utilisation dans des puits de pétrole et/ou de gaz Download PDF

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Publication number
WO2014153102A1
WO2014153102A1 PCT/US2014/029079 US2014029079W WO2014153102A1 WO 2014153102 A1 WO2014153102 A1 WO 2014153102A1 US 2014029079 W US2014029079 W US 2014029079W WO 2014153102 A1 WO2014153102 A1 WO 2014153102A1
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WIPO (PCT)
Prior art keywords
microemulsion
emulsion
fluid
composition
alkyl
Prior art date
Application number
PCT/US2014/029079
Other languages
English (en)
Inventor
Lakia M. CHAMPAGNE
Angus FURSDON-WELSH
Nathan L. LETT
Maria Elizabeth GREEN
David GERMACK
Keith Ingram Dismuke
Randall M. Hill
Andrei Zelenev
James SILAS
Charles Earl HAMMOND
John T. Pursley
Glenn S Penny
Michael A. Bryan
Monica GONZALEZ-ROLDAN
Melinda SOEUNG
Hasnain SABOOWALA
Nicole MAST
Joby HUGHES
Original Assignee
Cesi Chemical Inc.
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Priority claimed from US13/829,434 external-priority patent/US9068108B2/en
Priority claimed from US13/829,495 external-priority patent/US9428683B2/en
Priority claimed from US13/918,166 external-priority patent/US20140371115A1/en
Priority claimed from US13/918,155 external-priority patent/US9321955B2/en
Application filed by Cesi Chemical Inc. filed Critical Cesi Chemical Inc.
Priority to EP14768919.4A priority Critical patent/EP2970753A4/fr
Priority to CA2906165A priority patent/CA2906165C/fr
Priority to AU2014236272A priority patent/AU2014236272B2/en
Priority to CN201480026902.0A priority patent/CN105492572A/zh
Publication of WO2014153102A1 publication Critical patent/WO2014153102A1/fr
Priority to AU2018201361A priority patent/AU2018201361B2/en

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Classifications

    • C—CHEMISTRY; METALLURGY
    • C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
    • C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
    • C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
    • C09K8/60—Compositions for stimulating production by acting on the underground formation
    • C09K8/62—Compositions for forming crevices or fractures
    • C09K8/66—Compositions based on water or polar solvents
    • C09K8/68—Compositions based on water or polar solvents containing organic compounds
    • C—CHEMISTRY; METALLURGY
    • C04—CEMENTS; CONCRETE; ARTIFICIAL STONE; CERAMICS; REFRACTORIES
    • C04B—LIME, MAGNESIA; SLAG; CEMENTS; COMPOSITIONS THEREOF, e.g. MORTARS, CONCRETE OR LIKE BUILDING MATERIALS; ARTIFICIAL STONE; CERAMICS; REFRACTORIES; TREATMENT OF NATURAL STONE
    • C04B28/00—Compositions of mortars, concrete or artificial stone, containing inorganic binders or the reaction product of an inorganic and an organic binder, e.g. polycarboxylate cements
    • C04B28/02—Compositions of mortars, concrete or artificial stone, containing inorganic binders or the reaction product of an inorganic and an organic binder, e.g. polycarboxylate cements containing hydraulic cements other than calcium sulfates
    • C—CHEMISTRY; METALLURGY
    • C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
    • C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
    • C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
    • C09K8/02—Well-drilling compositions
    • C09K8/03—Specific additives for general use in well-drilling compositions
    • C09K8/035—Organic additives
    • C—CHEMISTRY; METALLURGY
    • C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
    • C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
    • C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
    • C09K8/02—Well-drilling compositions
    • C09K8/04—Aqueous well-drilling compositions
    • C09K8/26—Oil-in-water emulsions
    • C—CHEMISTRY; METALLURGY
    • C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
    • C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
    • C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
    • C09K8/42—Compositions for cementing, e.g. for cementing casings into boreholes; Compositions for plugging, e.g. for killing wells
    • C09K8/46—Compositions for cementing, e.g. for cementing casings into boreholes; Compositions for plugging, e.g. for killing wells containing inorganic binders, e.g. Portland cement
    • C09K8/467—Compositions for cementing, e.g. for cementing casings into boreholes; Compositions for plugging, e.g. for killing wells containing inorganic binders, e.g. Portland cement containing additives for specific purposes

Definitions

  • compositions comprising an emulsion or a microemulsion for use in various aspects of a life cycle of an oil and/or gas well are provided.
  • the life cycle of an oil and/or gas well includes drilling to form a wellbore, casing, cementing, stimulation, and enhanced or improved oil recovery.
  • Various aspects of the life cycle of an oil and/or gas well are designed to facilitate the extraction of oil and/or gas from the reservoir via the wellbore.
  • a wide variety of fluids is utilized during the life cycle of an oil and/or gas well and are well known.
  • additives have been incorporated into various fluids utilized during the life cycle of an oil and/or gas well.
  • the incorporation of additives into fluids utilized during the life cycle of an oil and/or gas well can increase crude oil or formation gas, for example, by reducing capillary pressure and/or minimizing capillary end effects.
  • drilling fluids are utilized to carry cuttings and other particulates from beneath the drill bit to the surface and can function to reduce friction between the drill bit and the sides of the wellbore while maintaining the stability of uncased sections of the borehole.
  • the drilling fluid and the subsequent cementing and perforating fluids can be formulated to prevent imbibition and/or unwanted influxes of some formation fluids.
  • fracturing and acidizing are a commonly used techniques to stimulate the production of oil and/or gas from reservoirs, wherein a stimulation fluid is injected into the wellbore and the formation (reservoir).
  • the stimulation fluid can comprise additives to aid in the stimulation process, for example, proppants, scale inhibitors, friction reducers, biocides, gases such as carbon dioxide and nitrogen, acids, slow release acids, corrosion inhibitors, buffers, viscosifiers, clay swelling inhibitors, oxygen scavengers, and surfactants. Later in the life of the well additional fluids and gases may be injected into the well to remediate damage, maintain pressure or contact and recover further oil.
  • a fluid to be utilized during the life cycle of an oil and/or gas well it is important for the fluid to comprise the right combination of additives and components to achieve the necessary characteristics of the specific end-use application.
  • a primary goal amongst all aspects of the life cycle of a well is to optimize recovery of oil and/or gas from the reservoir.
  • the fluids utilized during the life cycle of an oil and/or gas well are often utilized to perform a number of tasks simultaneously, achieving necessary to optimal characteristics is not always easy.
  • additives provide multiple benefits and are useful across multiple portions of the life cycle of the well.
  • a challenge often encountered is fluid recovery following injection of fracturing fluids or other fluids into the wellbore.
  • large quantities of injected fluids are trapped in the formation, for example, in the area surrounding the fracture and within the fracture itself. It is theorized that the trapping of the fluid is due to interfacial tension between water and reservoir rock and/or capillary end effects in and around the vicinity of the face of the fractured rock. The presence of trapped fluids generally has a negative effect on the productivity of the well.
  • a method of treating an oil and/or gas well having a wellbore comprising injecting a fluid comprising an emulsion or
  • microemulsion into the wellbore wherein the emulsion or microemulsion comprises an aqueous phase; a surfactant; and a solvent, wherein the solvent comprises an amine of
  • R , R , and R are the same or different and are alkyl, provide at least one of R 1 , R2 , and R 3 is methyl or ethyl, or optionally, wherein any
  • a method of treating an oil and/or gas well having a wellbore comprising injecting a fluid comprising an emulsion or
  • a method of treating an oil and/or gas well having a wellbore comprising injecting a fluid comprising an emulsion or
  • microemulsion into the wellbore wherein the emulsion or microemulsion comprises water; an alcohol; a solvent comprising a terpene; and a surfactant, wherein the surfactant has a structure as in Formula I:
  • Ar is an aryl group;
  • R 12 is hydrogen or alkyl; n is 1-100; and each m is independently 1 or 2.
  • a method of treating an oil and/or gas well having a wellbore comprising injecting a fluid comprising an emulsion or
  • microemulsion into the wellbore wherein the emulsion or microemulsion comprise water; an alcohol; a solvent comprising a terpene; and a surfactant, wherein the surfactant has a structure as in Formula II:
  • Ar is an aryl group;
  • Y " is an anionic group;
  • X + is a cationic group;
  • a method of treating an oil and/or gas well having a wellbore comprising injecting a fluid comprising an emulsion or
  • microemulsion into the wellbore wherein the emulsion or microemulsion comprises water; an alcohol; a solvent comprising a terpene; and a surfactant, wherein the surfactant has a structure as in Formula III:
  • Ar is an aryl group;
  • Z is a cationic group;
  • a method of treating an oil and/or gas well having a wellbore comprising injecting a solution into the wellbore, wherein the solution comprising a fluid selected from the group consisting of a mud displacement fluid, a cementing fluid, a perforating fluid, a kill fluid, and EOR/IOR fluid, a stored fluid, or a stimulation fluid utilized in offshore wells or during fracture packing, and an emulsion or microemulsion, wherein the emulsion or the microemulsion comprises between about 1 wt% and 95 wt% water; between about 1 wt% and 99 wt% solvent; between about 0 wt% and about 50 wt% alcohol; between about 1 wt% and 90 wt% surfactant; between about 0 wt% and about 70 wt% freezing point depression agent; and between about 0 wt% and about 70 wt% other additives.
  • the solution comprising a fluid selected from the group consisting of a mud displacement fluid,
  • a composition for use in an oil and/or gas well having a wellbore comprising a fluid and an emulsion or microemulsion, wherein the emulsion or the microemulsion comprises water; an alcohol; a solvent comprising a terpene; and a surfactant in an amount between about 9 wt% and about 11 wt% versus the total emulsion, wherein the surfactant has a structure as in Formula I:
  • Ar is an aryl group;
  • R 12 is hydrogen or alkyl;
  • n is 1-100; and each m is independently 1 or 2.
  • a composition for use in an oil and/or gas well having a wellbore comprising a fluid and an emulsion or microemulsion, wherein the emulsion or the microemulsion comprises water; an alcohol; a solvent comprising a terpene; and a surfactant in an amount between about 9 wt% and about 11 wt% versus the total emulsion, wherein the surfactant has a structure as in Formula II:
  • Ar is an aryl group;
  • Y " is an anionic group;
  • X + is a cationic group;
  • a composition for use in an oil and/or gas well having a wellbore comprising a fluid and an emulsion or microemulsion, wherein the emulsion or the microemulsion comprises water; an alcohol; a solvent comprising a terpene; and a surfactant in an amount between about 9 wt% and about 11 wt% versus the total emulsion, wherein the surfactant has a structure as in Formula III:
  • Ar is an aryl group;
  • Z + is a cationic group;
  • Figure 1 shows an exemplary plot for determining the phase inversion temperature of a microemulsion, according to some embodiments.
  • An emulsion or a microemulsion may comprise water, a solvent, a surfactant, a co-surfactant (e.g., an alcohol), and optionally other components (e.g., a clay stabilizer, a freezing point depression agent, an acid, a salt, etc.).
  • the solvent comprises more than one type of solvent (e.g., a first type of solvent and a second type of solvent).
  • the methods and compositions relate to various aspects of the life cycle of an oil and/or gas well (e.g., drilling, mud displacement, casing, cementing, perforating, stimulation, kill fluids, enhanced oil recovery/improved oil recovery, etc.).
  • an emulsion or a microemulsion is added to a fluid utilized in the life cycle of well thereby increasing hydrocarbon (e.g., liquid or gaseous) production of the well, improving recovery of the fluid and/or other fluids, and/or preventing or minimizing damage to the well caused by exposure to the fluid (e.g., from imbibition).
  • emulsions or microemulsions may be utilized in any a wide variety of application in the life cycle of the well, as described in Section B.
  • emulsions or microemulsion are provided.
  • the terms should be understood to include emulsions or microemulsions that have a water continuous phase, or that have an oil continuous phase, or microemulsions that are bicontinuous or multiple continuous phases of water and oil.
  • emulsion is given its ordinary meaning in the art and refers to dispersions of one immiscible liquid in another, in the form of droplets, with diameters approximately in the range of 100-1,000 nanometers. Emulsions may be thermodynamically unstable and/or require high shear forces to induce their formation.
  • microemulsion is given its ordinary meaning in the art and refers to dispersions of one immiscible liquid in another, in the form of droplets, with diameters approximately in the range of about between about 1 and about 1000 nm, or between 10 and about 1000 nanometers, or between about 10 and about 500 nm, or between about 10 and about 300 nm, or between about 10 and about 100 nm.
  • Microemulsions are clear or transparent because they contain particles smaller than the wavelength of visible light. In addition, microemulsions are homogeneous
  • thermodynamically stable single phases and form spontaneously, and thus, differ markedly from thermodynamically unstable emulsions, which generally depend upon intense mixing energy for their formation.
  • Microemulsions may be characterized by a variety of advantageous properties including, by not limited to, (i) clarity, (ii) very small particle size, (iii) ultra-low interfacial tensions, (iv) the ability to combine properties of water and oil in a single homogeneous fluid, (v) shelf life stability, and (vi) ease of preparation.
  • the microemulsions described herein are stabilized microemulsions that are formed by the combination of a solvent-surfactant blend with an appropriate oil-based or water-based carrier fluid.
  • the microemulsion forms upon simple mixing of the components without the need for high shearing generally required in the formation of ordinary emulsions.
  • the solvent-surfactant blend with an appropriate oil-based or water-based carrier fluid.
  • microemulsion is a thermodynamically stable system, and the droplets remain finely dispersed over time.
  • the average droplet size ranges from about 10 nm to about 300 nm.
  • the emulsion or microemulsion is a single emulsion or microemulsion.
  • the emulsion or microemulsion comprises a single layer of a surfactant.
  • the emulsion or microemulsion may be a double or multilamellar emulsion or microemulsion.
  • the emulsion or microemulsion comprises two or more layers of a surfactant.
  • the emulsion or microemulsion comprises a single layer of surfactant surrounding a core (e.g., one or more of water, oil, solvent, and/or other additives) or a multiple layers of surfactant (e.g., two or more concentric layers surrounding the core).
  • the emulsion or microemulsion comprises two or more immiscible cores (e.g., one or more of water, oil, solvent, and/or other additives which have equal or about equal affinities for the surfactant).
  • a microemulsion comprises water, a solvent, and a surfactant.
  • the microemulsion further comprises additional components, for example, a freezing point depression agent. Details of each of the components of the micro emulsions are described in detail herein. In some embodiments, the components of the microemulsions are selected so as to reduce or eliminate the hazards of the microemulsion to the environment and/or the subterranean reservoirs.
  • the emulsion or microemulsion comprise between about 1 wt% and 95 wt% water, between about 1 wt% and 99 wt% solvent, between about 0 wt% and about 50 wt% alcohol, between about 1 wt% and 90 wt% surfactant, and between about 0 wt% and about 70 wt% freezing point depression agent, and between about 0 wt% and about 70 wt% other additives, versus the total microemulsion composition.
  • the emulsion or microemulsion comprise between about 1 wt% and 60 wt% water, between about 1 wt% and 30 wt% solvent, between about 1 wt% and about 50 wt% alcohol, between about 5 wt% and 65 wt% surfactant, and between about 0 wt% and about 25 wt% freezing point depression agent, and between about 0 wt% and about 30 wt% other additives, versus the total microemulsion composition.
  • the water is present in an amount between about 10 wt% and about 55 wt%, or between about 15 wt% and about 45 wt%.
  • the solvent is present in an amount between about 2 wt% and about 25 wt%, or between about 5 wt% and about 25 wt%.
  • the solvent comprises a terpene. In some embodiments, for the
  • the alcohol is present in an amount between about 5 wt% and about 40 wt%, or between about 5 wt% and 35 wt%.
  • the alcohol comprises isopropanol.
  • the surfactant is present in an amount between about 5 wt% and 60 wt%, or between about 10 wt% and 55 wt%.
  • the freezing point depression agent is present in an amount between about 1 wt% and about 25 wt%, or between about 1 wt% and about 20 wt%, or between about 3 wt% and about 20 wt%.
  • the other additives are present in an amount between about 1 wt% and about 30 wt%, or between about 1 wt% and about 25 wt%, or between about 1 wt% and about 20 wt%.
  • the other additives comprise one or more salts and/or one or more acids.
  • a microemulsion composition comprises between about 5 wt% to about 60 wt% water, from about 2 wt% to about 50 wt% solvent , from about 5 wt% to about 60 wt% of a first type of a solubilizing surfactant, from about 2 wt% to about 50 wt% of alcohol, from about 0.5 to 30 wt% of a freezing point depression agent, from about 0.5 wt% to about 30 wt% of a second type of surfactant, from about 0 wt% to about 70 wt% of other additives (e.g., acid), and from about 0.5 wt% to about 30% of mutual solvent, which is miscible together with the water and the solvent.
  • a solubilizing surfactant from about 2 wt% to about 50 wt% of alcohol
  • a freezing point depression agent from about 0.5 to 30 wt% of a freezing point depression agent
  • a second type of surfactant from about 0
  • the solvent is a substance with a significant hydrophobic character with linear, branched, cyclic, bicyclic, saturated or unsaturated structure, including but not limited to terpenes, terpineols, terpene alcohols, aldehydes, ketones, esters, amines, and amides.
  • suitable mutual solvents include
  • ethyleneglycolmonobutyl ether (EGMBE), dipropylene glycol monomethyl ether, short chain alcohols (e.g., isopropanol), tetrahydrofuran, dioxane, dimethylformamide, and dimethylsulfoxide.
  • Freezing point depressions agents are described in more detail herein, and include, but are not limited to, alkali metal or earth alkali metal salts, preferably chlorides, urea, alcohols (e.g., glycols such as propylene glycol and triethylene glycol).
  • the solubilizing surfactant is a molecule capable of forming a colloidal solution of the said solvent in predominantly aqueous media.
  • surfactants are amphiphilic molecules that adsorb at interfaces to lower surface energy and can be used to form microemulsions in which they stabilize a mixture of polar and non-polar solvent.
  • suitable surfactants include nonionic surfactants with linear or branched structure, including, but not limited to, ethoxylated fatty alcohols, ethoxylated castor oils, and alkyl glucosides with a hydrocarbon chain of at least 8 carbon atoms and mole % of ethoxylation of 5 or more. Additional surfactants are described herein.
  • second types of surfactants include adsorption modifiers, foamers, surface tension lowering enhancers, and emulsion breaking additives.
  • surfactants include cationic surfactants with a medium chain length, linear or branched anionic surfactants, amine oxides, amphoteric surfactants, silicone based surfactants, alkoxylated novolac resins (e.g. alkoxylated phenolic resins), alkoxylated polyimines, alkoxylated polyamines, and fluorosurfactants.
  • the emulsion or microemulsion is as described in U.S. Patent Number 7,380,606 and entitled “Composition and Process for Well Cleaning,” herein incorporated by reference.
  • the microemulsion generally comprises a solvent.
  • the solvent, or a combination of solvents may be present in the microemulsion in any suitable amount.
  • the total amount of solvent present in the microemulsion is between about 1 wt% and about 99 wt%, or between about 2 wt% and about 90 wt %, or between about 1 wt% and about 60 wt%, or between about 2 wt% and about 60 wt%, or between about 1 and about 50 wt%, or between about 1 and about 30 wt%, or between about 5 wt% and about 40 wt%, or between about 5 wt% and about 30 wt%, or between about 2 wt% and about 25 wt%, or between about 5 wt% and about 25 wt%, or between about 60 wt% and about 95 wt%, or between about 70 wt% or about 95 wt%, or between about 75 wt% and about 90 wt%, or
  • microemulsion composition is a microemulsion composition.
  • microemulsions comprising more than two types of solvents may be utilized in the methods, compositions, and systems described herein.
  • the microemulsion may comprise more than one or two types of solvent, for example, three, four, five, six, or more, types of solvents.
  • the microemulsion comprises a first type of solvent and a second type of solvent.
  • the first type of solvent to the second type of solvent ratio in a microemulsion may be present in any suitable ratio.
  • the ratio of the first type of solvent to the second type of solvent by weight is between about 4: 1 and 1 :4, or between 2: 1 and 1 :2, or about 1 : 1.
  • the solvent is an unsubstituted cyclic or acyclic, branched or unbranched alkane having 6-12 carbon atoms.
  • the cyclic or acyclic, branched or unbranched alkane has 6-10 carbon atoms.
  • unsubstituted acyclic unbranched alkanes having 6-12 carbon atoms include hexane, heptane, octane, nonane, decane, undecane, and dodecane.
  • Non-limiting examples of unsubstituted acyclic branched alkanes having 6-12 carbon atoms include isomers of methylpentane (e.g., 2-methylpentane, 3-methylpentane), isomers of dimethylbutane (e.g., 2,2-dimethylbutane, 2, 3 -dimethylbutane), isomers of methylhexane (e.g., 2- methylhexane, 3 -methylhexane), isomers of ethylpentane (e.g., 3-ethylpentane), isomers of dimethylpentane (e.g., 2,2,-dimethylpentane, 2,3-dimethylpentane, 2,4- dimethylpentane, 3,3-dimethylpentane), isomers of trimethylbutane (e.g., 2,2,3- trimethylbutane), isomers of methylheptane (e.
  • trimethylpentane e.g., 2,2,3-trimethylpentane, 2,2,4-trimethylpentane, 2,3,3- trimethylpentane, 2,3,4-trimethylpentane
  • ethylmethylpentane e.g., 3- ethyl-2 -methylpentane, 3-ethyl-3-methylpentane
  • unsubstituted cyclic branched or unbranched alkanes having 6-12 carbon atoms include cyclohexane, methylcyclopentane, ethylcyclobutane, propylcyclopropane,
  • the unsubstituted cyclic or acyclic, branched or unbranched alkane having 6-12 carbon is selected from the group consisting of heptane, octane, nonane, decane, 2,2,4-trimethylpentane (isooctane), and propylcyclohexane.
  • the solvent is an unsubstituted acyclic branched or unbranched alkene having one or two double bonds and 6-12 carbon atoms. In some embodiments, the solvent is an unsubstituted acyclic branched or unbranched alkene having one or two double bonds and 6-10 carbon atoms.
  • Non- limiting examples of unsubstituted acyclic unbranched alkenes having one or two double bonds and 6-12 carbon atoms include isomers of hexene (e.g., 1-hexene, 2-hexene), isomers of hexadiene (e.g., 1,3-hexadiene, 1 ,4-hexadiene), isomers of heptene (e.g., 1-heptene, 2-heptene, 3- heptene), isomers of heptadiene (e.g., 1,5-heptadiene, 1-6, heptadiene), isomers of octene (e.g., 1-octene, 2-octene, 3-octene), isomers of octadiene (e.g., 1 ,7-octadiene), isomers of nonene, isomers of nonadiene, isomers of decen
  • the acyclic unbranched alkene having one or two double bonds and 6-12 carbon atoms is an alpha-olefm (e.g., 1-hexene, 1-heptene, 1-octene, 1-nonene, 1- decene, 1-undecene, 1-dodecene).
  • alpha-olefm e.g., 1-hexene, 1-heptene, 1-octene, 1-nonene, 1- decene, 1-undecene, 1-dodecene.
  • Non- limiting examples unsubstituted acyclic branched alkenes include isomers of methylpentene, isomers of dimethylpentene, isomers of ethylpentene, isomers of methylethylpentene, isomers of propylpentene, isomers of methylhexene, isomers of ethylhexene, isomers of dimethylhexene, isomers of methylethylhexene, isomers of methylheptene, isomers of ethylheptene, isomers of dimethylhexptene, and isomers of methylethylheptene.
  • the unsubstituted acyclic unbranched alkene having one or two double bonds and 6-12 carbon atoms is selected from the group consisting of 1-octene and 1,7-octadiene.
  • the solvent is a cyclic or acyclic, branched or unbranched alkane having 9-12 carbon atoms and substituted with only an -OH group.
  • Non-limiting examples of cyclic or acyclic, branched or unbranched alkanes having 9-12 carbon atoms and substituted with only an -OH group include isomers of nonanol, isomers of decanol, isomers of undecanol, and isomers of dodecanol.
  • the cyclic or acyclic, branched or unbranched alkane having 9-12 carbon atoms and substituted with only an -OH group is selected from the group consisting of 1 -nonanol and 1- decanol.
  • the solvent is a branched or unbranched dialkylether compound having the formula C n H2 n+ iOC m H 2m+ i wherein n + m is between 6 and 16. In some cases, n + m is between 6 and 12, or between 6 and 10, or between 6 and 8.
  • Non- limiting examples of branched or unbranched dialkylether compounds having the formula C n H2n+iOC m H 2 m+i include isomers of C3H7OC3H7, isomers of C4H9OC3H7, isomers of C5H11OC3H7, isomers of C6H13OC3H7, isomers of C4H9OC4H9, isomers of C4H9OC5H11, isomers of C4H9OC6H13, isomers of C5H11OC6H13, and isomers of
  • the branched or unbranched dialklyether is an isomer CeHoOCeHo (e.g., dihexylether).
  • the solvent is an aromatic solvent having a boiling point between about 300-400 °F.
  • aromatic solvents having a boiling point between about 300-400 °F include butylbenzene, hexylbenzene, mesitylene, light aromatic naphtha, and heavy aromatic naphtha.
  • the solvent is a bicyclic hydrocarbon solvent with varying degrees of unsaturation including fused, bridgehead, and spirocyclic compounds.
  • Non- limiting examples of bicyclic solvents include isomers of decalin, tetrahydronapthalene, norbornane, norbornene, bicyclo[4.2.0]octane, bicyclo[3.2.1]octane, and
  • the solvent is a bicyclic hydrocarbon solvent with varying degrees of unsaturation and containing at least one O, N, or S atom including fused, bridgehead, and spirocyclic compounds.
  • Non-limiting examples include isomers of 7 oxabicyclo[2.2.1]heptane, 4,7-epoxyisobenzofuran-l,3-dione, and 7
  • the solvent is a cyclic or acyclic, branched or unbranched alkane having 8 carbon atoms and substituted with only an -OH group.
  • Non- limiting examples of cyclic or acyclic, branched or unbranched alkanes having 8 carbon atoms and substituted with only an -OH group include isomers of octanol (e.g., 1-octanol, 2- octanol, 3-octanol, 4-octanol), isomers of methyl heptanol, isomers of ethylhexanol (e.g., 2-ethyl-l-hexanol, 3-ethyl-l-hexanol, 4-ethyl-l-hexanol), isomers of dimethylhexanol, isomers of propylpentanol, isomers of methylethylpentanol,
  • the cyclic or acyclic, branched or unbranched alkane having 8 carbon atoms and substituted with only an -OH group is selected from the group consisting of 1-octanol and 2-ethyl-l-hexanol.
  • the amine is of the formula NR R R , wherein R , R , and
  • R are the same or different and are hydrogen or cyclic or acyclic, branched or unbranched alkyl (e.g., C 1-16 alkyl), optionally substituted, or optionally, any two of R 1 ,
  • R" and R J are joined together to form a ring.
  • each of R , R , and R J are joined together to form a ring.
  • R are the same or different and are hydrogen or cyclic or acyclic, branched or unbranched alkyl, or optionally, any two of R 1 , R2 and R 3 are joined together to form a
  • R is methyl or ethyl.
  • R is cyclic
  • Ci-C 6 alkyl and R and R are the same or different and are hydrogen or cyclic or acyclic, branched or unbranched alkyl (e.g., C 8-16 alkyl), or optionally, R 2 and R 3 may be joined together to form a ring.
  • R 1 is methyl or ethyl and R 2 and R 3 are the same or different and are hydrogen or cyclic or acyclic, 2 3 branched or unbranched alkyl (e.g., C 8 _i 6 alkyl), or optionally, R and R may be joined
  • R is methyl and R and R are the same or different and are hydrogen or cyclic or acyclic, branched or unbranched alkyl (e.g., C 8-16
  • R and R may be joined together to form a ring.
  • R and R are the same or different and are hydrogen or cyclic or acyclic, branched or unbranched Ci-C 6 alkyl and R is branched or unbranched alkyl (e.g., C 8 _i 6 alkyl).
  • R and R are the same or different and are methyl or ethyl and R is hydrogen or cyclic or acyclic, branched or unbranched alkyl (e.g., C 8 _i 6 alkyl).
  • R and R are the same or different and are methyl or ethyl and R is hydrogen or cyclic or acyclic, branched or unbranched alkyl (e.g., C 8 _i 6 alkyl).
  • R and R are methyl and R is hydrogen or cyclic or acyclic, branched or unbranched alkyl (e.g., C 8 _i 6 alkyl).
  • the amine is of the formula NR R R , wherein R , R , and
  • R are the same or different and are cyclic or acyclic, branched or unbranched alkyl (e.g.,
  • Ci_i6 alkyl optionally substituted, or optionally, any two of R , R and R are joined
  • each of R , R , and R are the same or different and are cyclic or acyclic, branched or unbranched alkyl, or optionally, any two
  • R 1 2 3 1 2 3 of R , R and R are joined together to form a ring, provide at least one of R , R , and R is methyl or ethyl.
  • R 1 is cyclic or acyclic, branched or unbranched Ci-C 6
  • alkyl and R and R are the same or different and are cyclic or acyclic, branched or
  • R 1 is methyl or ethyl and R 2 and R 3 are the same or different and are cyclic or acyclic, branched or unbranched alkyl (e.g., C 8 _i 6 alkyl), or optionally,
  • R and R may be joined together to form a ring.
  • R is methyl and R and
  • R are the same or different and are cyclic or acyclic, branched or unbranched alkyl (e.g.,
  • R and R may be joined together to form a ring.
  • R and R are the same or different and are cyclic or acyclic, branched or unbranched Ci-C 6 alkyl and R is branched or unbranched alkyl (e.g., C 8 _i 6 alkyl).
  • R and R are the same or different and are methyl or ethyl and R is cyclic
  • R and R are methyl and R is cyclic or acyclic, branched or unbranched alkyl (e.g., C 8 _i 6 alkyl).
  • the amine is of the formula NR R R , wherein R is
  • R and R are the same or different and are hydrogen or cyclic or acyclic
  • Non-limiting examples of amines include isomers of N-methyl-octylamine, isomers of N-methyl-nonylamine, isomers of N-methyl-decylamine, isomers of N methylundecylamine, isomers of N-methyldodecylamine, isomers of N methyl teradecylamine, and isomers of N-methyl-hexadecylamine.
  • the amine is selected from the group consisting of N methyldecylamine and N
  • the amine is of the formula NR R R , wherein R is
  • R and R are the same or different and are cyclic or acyclic, branched or
  • the amine is of the formula NR R R , wherein R is methyl and R and R are the same or different and are cyclic or acyclic, branched or unbranched C 8 _i 6 alkyl, or optionally R 2 and R 3 are joined together to form a ring.
  • Non-limiting examples of amines include isomers of N-methyl-N-octyloctylamine, isomers of N-methyl-N- nonylnonylamine, isomers of N-methyl-N-decyldecyl amine, isomers of N-methyl-N- undecylundecylamine, isomers of N-methyl-N-dodecyldodecylamine, isomers of N- methyl-N-tetradecylteradecylamine, isomers of N-methyl-N-hexadecylhdexadecylamine, isomers of N-methyl-N-octylnonylamine, isomers of N-methyl-N-octyldecylamine, isomers of N-methyl-N-octyldodecylamine, isomers of N-methyl-N-octylundecylamine, is
  • the amine is selected from the group consisting of N-methyl-N-octyloctylamine, isomers of N-methyl-N- nonylnonylamine, isomers of N-methyl N-decyldecylamine, isomers of N-methyl-N- undecylundecylamine, isomers of N-methyl-N-dodecyldodecylamine, isomers of N- methyl-N-tetradecylteradecylamine, and isomers of N-methyl-N-octyloctylamine, isomers of N-methyl-N-n-nonylamine, isomers of N-methyl N-decyldecylamine, isomers of N-methyl-N- undecylundecylamine, isomers of N-methyl-N-dodecyldodecylamine, isomers of N- methyl-N-tetradecy
  • the amine is selected from the group consisting of N-methyl-N-dodecyldodecylamine and isomers of N-methyl-N hexadecylhexadecylamine.
  • the amine is selected from the group consisting of isomers of N-methyl-N-octylnonylamine, isomers of N-methyl-N- octyldecylamine, isomers of N-methyl-N-octyldodecylamine, isomers of N-methyl-N- octylundecylamine, isomers of N-methyl-N-octyltetradecylamine, isomers of N-methyl- N-octylhexadecylamine, N-methyl-N-nonyldecylamine, isomers of N-methyl-N- nonyldodecylamine, isomers of N-methyl-N-nonyltetradecylamine, isomers of N- methyl-N-nonylhexadecylamine, isomers of N-methyl-N-decyldodecylamine, iso
  • the cyclic or acyclic, branched or unbranched tri-substituted amines is selected from the group consisting of N-methyl-N-octyldodecylamine, N-methyl-N-octylhexadecylamine or N-methyl-N- dodecylhexadecylamine.
  • the amine is of the formula NR R R , wherein R and R are methyl and R is cyclic or acyclic, branched or unbranched C 8-16 alkyl.
  • Non-limiting examples of amines include isomers of ⁇ , ⁇ -dimethylnonylamine, isomers of N,N- dimethyldecylamine, isomers of ⁇ , ⁇ -dimethylundecylamine, isomers of N,N- dimethyldodecylamine, isomers of ⁇ , ⁇ -dimethyltetradecylamine, and isomers of N,N- dimethylhexadecylamine.
  • the amine is selected from the group consisting of ⁇ , ⁇ -dimethyldecyl amine, isomers of ⁇ , ⁇ -dodecylamine, and isomers of N,N-dimethylhexadecylamine.
  • each of R 4 , R 5 , and R 6 are the same or different and are hydrogen or cyclic or acyclic, branched or unbranched alkyl (e.g., Ci_ 16 alkyl), optionally substituted, or optionally, R 5 and R 6 are joined together to form a ring, provided at least one of R 4 , R 5 , and R 6 is methyl or ethyl.
  • R 4 is hydrogen or cyclic or acyclic, branched or unbranched Ci-C 6 alkyl, optionally
  • R 5 and R 6 are the same or different and are hydrogen or cyclic or acyclic, branched or unbranched alkyl (e.g., Cg_i6 alkyl), optionally substituted, or optionally, R 5 and R 6 may be joined together to form a ring.
  • R 4 is hydrogen, methyl, or ethyl and R 5 and R 6 are the same or different and are hydrogen or cyclic or acyclic, branched or unbranched alkyl (e.g., Cg_i 6 alkyl), optionally substituted, or optionally, R 5 and R 6 may be joined together to form a ring.
  • R 4 is hydrogen and R 5 and R 6 are the same or different and are cyclic or acyclic, branched or unbranched alkyl (e.g., Cg_i 6 alkyl), optionally substituted, or optionally, R 5 and R 6 may be joined together to form a ring.
  • R 4 and R 5 are the same or different and are hydrogen or cyclic or acyclic, branched or unbranched Ci-C 6 alkyl, optionally substituted
  • R 6 is cyclic or acyclic, branched or unbranched alkyl (e.g., C 8-16 alkyl), optionally substituted.
  • R 4 and R 5 are the same or different and are hydrogen, methyl, or ethyl and R 6 is cyclic or acyclic, branched or unbranched alkyl (e.g., Cg_i6 alkyl), optionally substituted. In some cases, R 4 and R 5 are hydrogen and R 6 is cyclic or acyclic, branched or unbranched alkyl (e.g., Cg_i 6 alkyl), optionally substituted.
  • R 6 is hydrogen or cyclic or acyclic, branched or unbranched Ci-C 6 alkyl, optionally substituted
  • R 4 and R 5 are the same or different and are hydrogen or cyclic or acyclic, branched or unbranched alkyl (e.g., Cg_i 6 alkyl), optionally substituted, or optionally.
  • R 6 is hydrogen, methyl, or ethyl and R 4 and R 5 are the same or different and are hydrogen or cyclic or acyclic, branched or unbranched alkyl (e.g., Cg_i 6 alkyl).
  • R 6 is hydrogen and R 4 and R 5 are the same or different and are cyclic or acyclic, branched or unbranched alkyl (e.g., Cg_i 6 alkyl), optionally substituted.
  • R 5 and R 6 are the same or different and are hydrogen or cyclic or acyclic, branched or unbranched Ci-C 6 alkyl, optionally substituted
  • R 4 is cyclic or acyclic, branched or unbranched alkyl (e.g., Cg_i 6 alkyl), optionally substituted.
  • R 5 and R 6 are the same or different and are hydrogen, methyl, or ethyl and R 4 is cyclic or acyclic, branched or unbranched alkyl (e.g., Cg_i 6 alkyl), optionally substituted. In some cases, R 5 and R 6 are hydrogen and R 4 is cyclic or acyclic, branched or unbranched alkyl (e.g., Cg_i6 alkyl), optionally substituted.
  • each of R 4 , R 5 , and R 6 are the same or different and are cyclic or acyclic, branched or unbranched alkyl (e.g., C 1-16 alkyl), optionally substituted, or optionally, R 5 and R 6 are joined together to form a ring, provided at least one of R 4 , R 5 , and R 6 is methyl or ethyl.
  • R 4 is cyclic or acyclic, branched or unbranched Ci-C 6 alkyl, optionally substituted
  • R 5 and R 6 are the same or different and are hydrogen or cyclic or acyclic, branched or unbranched alkyl (e.g., C 8-16 alkyl), optionally substituted, or optionally, R 5 and R 6 may be joined together to form a ring.
  • R 4 is methyl or ethyl and R 5 and R 6 are the same or different and are cyclic or acyclic, branched or unbranched alkyl (e.g., C 8 _i 6 alkyl), optionally substituted, or optionally, R 5 and R 6 may be joined together to form a ring.
  • R 4 is and R 5 and R 6 are the same or different and are cyclic or acyclic, branched or unbranched alkyl (e.g., C 8-16 alkyl), optionally substituted, or optionally, R 5 and R 6 may be joined together to form a ring.
  • R 4 is methyl and R 5 and R 6 are the same or different and are cyclic or acyclic, branched or unbranched alkyl (e.g., Cg_i6 alkyl), optionally substituted, or optionally, R 5 and R 6 may be joined together to form a ring.
  • R 4 and R 5 are the same or different and are methyl or ethyl and R 6 is cyclic or acyclic, branched or unbranched alkyl (e.g., C 8-16 alkyl), optionally substituted.
  • R 4 and R 5 are methyl and R 6 is cyclic or acyclic, branched or unbranched alkyl (e.g., C 8 _i 6 alkyl), optionally substituted.
  • R 6 is cyclic or acyclic, branched or unbranched Ci-C 6 alkyl, optionally substituted
  • R 4 and R 5 are the same or different and are hydrogen or cyclic or acyclic, branched or unbranched alkyl (e.g., C 8-16 alkyl), optionally substituted, or optionally.
  • R 6 is methyl or ethyl and R 4 and R 5 are the same or different and are hydrogen or cyclic or acyclic, branched or unbranched alkyl (e.g., C 8 _i 6 alkyl). In some cases, R 6 is methyl and R 4 and R 5 are the same or different and are cyclic or acyclic, branched or unbranched alkyl (e.g., C 8 _i6 alkyl), optionally substituted.
  • R 5 and R 6 are the same or different and are cyclic or acyclic, branched or unbranched Ci-C 6 alkyl, optionally substituted, and R 4 is cyclic or acyclic, branched or unbranched alkyl (e.g., C 8 _i 6 alkyl), optionally substituted.
  • R 5 and R 6 are the same or different and are methyl or ethyl and R 4 is cyclic or acyclic, branched or unbranched alkyl (e.g., C 8 _i 6 alkyl), optionally substituted.
  • R 5 and R 6 are methyl and R 6 is cyclic or acyclic, branched or unbranched alkyl (e.g., C 8 _i 6 alkyl), optionally substituted.
  • the amide is of the formula
  • R 4 , R 5 , and R 6 are the same or different and are cyclic or acyclic, branched or unbranched C 8 _i 6 alkyl, optionally substituted, or optionally, R 5 and R 6 are joined together to form a ring.
  • R 4 , R 5 , and R 6 are the same or different and are selected from the group consisting of t-butyl and cyclic or acyclic, branched or unbranched C 8 _i 6 alkyl, optionally substituted, or optionally, R 5 and R 6 are joined together to form a ring.
  • Non-limiting examples amides include N,N-dioctyloctamide, ⁇ , ⁇ -dinonylnonamide, N,N-didecyldecamide, ⁇ , ⁇ -didodecyldodecamide, N,N- diundecylundecamide, ⁇ , ⁇ -ditetradecyltetradecamide, N,N-dihexadecylhexadecamide, ⁇ , ⁇ -didecyloctamide, N,N-didodecyloctamide, ⁇ , ⁇ -dioctyldodecamide, N,N- didecyldodecamide, N,N-dioctylhexadecamide, ⁇ , ⁇ -didecylhexadecamide, and N,N- didodecylhexadecamide.
  • the amide is selected from the group consisting of ⁇ , ⁇ -dioctyloct
  • R 6 is selected from the group consisting of hydrogen, methyl, ethyl, propyl and isopropyl, and R 4 and R 5 are the same or different and are cyclic or acyclic, branched or unbranched C 4 _i 6 alkyl, optionally substituted.
  • R 6 is selected from the group consisting of hydrogen, methyl, ethyl, propyl and isopropyl, and R 4 and R 5 are the same or different and are cyclic or acyclic, branched or unbranched C 8 _ 16 alkyl, optionally substituted. In some cases, at least one of R 4 and R 5 is substituted with a hydroxy group.
  • R 6 is selected from the group consisting of hydrogen, methyl, ethyl, propyl, and isopropyl
  • R 4 and R 5 are the same or different and are selected from the group consisting of tert-butyl, cyclic or acyclic, branched or unbranched C 5-16 alkyl, optionally substituted, and cyclic or acyclic, branched or unbranched C 1-16 alkyl substituted with an -OH group.
  • R 4 and R 5 are the same or different and are cyclic or acyclic, branched or unbranched C 4 _i 6 alkyl, optionally substituted.
  • R 6 is selected from the group consisting of methyl, ethyl, propyl and isopropyl
  • R 4 and R 5 are the same or different and are cyclic or acyclic, branched or unbranched C 4 _i6 alkyl, optionally substituted.
  • R 6 is selected from the group consisting of methyl, ethyl, propyl and isopropyl
  • R 4 and R 5 are the same or different and are cyclic or acyclic, branched or unbranched C 8-16 alkyl, optionally substituted. In some cases, at least one of R 4 and R 5 is substituted with a hydroxy group.
  • R 6 is selected from the group consisting of methyl, ethyl, propyl, and isopropyl
  • R 4 and R 5 are the same or different and are selected from the group consisting of tert-butyl, cyclic or acyclic, branched or unbranched C 5 _i6 alkyl, optionally substituted, and cyclic or acyclic, branched or unbranched C 1-16 alkyl substituted with an -OH group.
  • Non-limiting examples of amides include N,N-di-tert-butylformamide, N,N- dipentylformamide, N,N-dihexylformamide, ⁇ , ⁇ -diheptylformamide, N,N- dioctylformamide, N,N-dinonylformamide, ⁇ , ⁇ -didecylformamide, N,N- diundecylformamide, ⁇ , ⁇ -didodecylformamide, N,N-dihydroxymethylformamide, N,N- di-tert-butylacetamide, N,N-dipentylacetamide, ⁇ , ⁇ -dihexylacetamide, N,N- diheptylacetamide, N,N-dioctylacetamide, ⁇ , ⁇ -dinonylacetamide, N,N- didecylacetamide, N,N-diundecylacetamide, ⁇ , ⁇ -didodecylacet
  • the amide is selected from the group consisting of ⁇ , ⁇ -dioctyldodecacetamide, N,N-methyl-N- octylhexadecdidodecylacetamide, and N-methyl-N-ihexadecyldodecylhexadecacetamide.
  • Non-limiting amides include isomers of N
  • amides are sleeted from the group consisteing of N methyloctamide, N
  • Non-limiting amides include isomers of N-methyl-N- octyloctamide, isomers of N-methyl-N-nonylnonamide, isomers of N-methyl-N- decyldecamide, isomers of N methyl-N undecylundecamide, isomers of N methyl-N- dodecyldodecamide, isomers of N methyl N-tetradecylteradecamide, isomers of N- methyl-N-hexadecylhdexadecamide, isomers of N-methyl-N-octylnonamide, isomers of N-methyl-N-octyldecamide, isomers of N-methyl-N-octyldodecamide, isomers of N-methyl-N-octylundecamide, isomers of N-methyl-N-octyltetradecamide, isomers of N-
  • the amide is selected from the group consisting of isomers of N- methyl-N-octyloctamide, isomers of N-methyl-N-nonylnonamide, isomers of N-methyl- N-decyldecamide, isomers of N methyl-N undecylundecamide, isomers of N methyl-N- dodecyldodecamide, isomers of N methyl N-tetradecylteradecamide, and isomers of N- methyl-N-hexadecylhdexadecamide.
  • amide is selected from the group consisting of N-methyl-N-octyloctamide, N methyl-N-dodecyldodecamide, and N- methyl-N-hexadecylhexadecamide.
  • the amide is selected from the group consisting of isomers of N-methyl-N-octylnonamide, isomers of N-methyl-N- octyldecamide, isomers of N-methyl-N-octyldodecamide, isomers of N-methyl-N- octylundecamide, isomers of N-methyl-N-octyltetradecamide, isomers of N-methyl-N- octylhexadecamide, N-methyl-N-nonyldecamide, isomers of N-methyl-N - nonyldodecamide, isomers of N-methyl-N-nonyltetradecamide, isomers of N-methyl-N- nonylhexadecamide, isomers of N-methyl-N-decyldodecamide, isomers of N-methyl-N- decylundecamide, is
  • the amides is selected from the group consisting of N-methyl-N- octyldodecamide, N-methyl-N-octylhexadecamide, and N-methyl-N- dodecylhexadecamide.
  • R 5 and R 6 are the same or different and are selected from the group consisting of hydrogen, methyl, ethyl, propyl and isopropyl, and R 4 is cyclic or acyclic, branched or unbranched C 4 _i 6 alkyl, optionally substituted.
  • R 5 and R 6 are the same or different and are selected from the group consisting of hydrogen, methyl, ethyl, propyl and isopropyl and R 4 is cyclic or acyclic, branched or unbranched Cg_i6 alkyl, optionally substituted. In some cases, R 4 is substituted with a hydroxy group.
  • R 5 and R 6 are the same or different and are selected from the group consisting of hydrogen, methyl, ethyl, propyl, and isopropyl
  • R 4 is selected from the group consisting of tert-butyl, cyclic or acyclic, branched or unbranched C 5-16 alkyl, optionally substituted, and cyclic or acyclic, branched or unbranched C 1-16 alkyl substituted with an -OH group.
  • R 5 and R 6 are the same or different and are selected from the group consisting of methyl, ethyl, propyl and isopropyl, and R 4 is cyclic or acyclic, branched or unbranched C 4 _i 6 alkyl, optionally substituted.
  • R 5 and R 6 are the same or different and are selected from the group consisting of methyl, ethyl, propyl and isopropyl and R 4 is cyclic or acyclic, branched or unbranched C 8-16 alkyl, optionally substituted. In some cases, R 4 is substituted with a hydroxy group.
  • R 5 and R 6 are the same or different and are selected from the group consisting of methyl, ethyl, propyl, and isopropyl
  • R 4 is selected from the group consisting of tert-butyl, cyclic or acyclic, branched or unbranched C 5-16 alkyl, optionally substituted, and cyclic or acyclic, branched or unbranched C 1-16 alkyl substituted with an -OH group.
  • Non- limiting examples of amides include isomers of ⁇ , ⁇ -dimethyloctamide, isomers of N,N- dimethylnonamide, isomers of ⁇ , ⁇ -dimethyldecamide, isomers of N,N- dimethylundecamide, isomers of ⁇ , ⁇ -dimethyldodecamide, isomers of N,N- dimethyltetradecamide, and isomers of ⁇ , ⁇ -dimethylhexadecamide.
  • the cyclic or acyclic, branched or unbranched tri-substituted amines is selected from the group consisting of N,N-dimethyloctamide, ⁇ , ⁇ -dodecamide, and N,N-dimethylhexadecamide.
  • the solvent is an aromatic solvent having a boiling point between about 175-300 °F.
  • aromatic liquid solvents having a boiling point between about 175-300 °F include benzene, xylenes, and toluene.
  • the solvent is not xylene.
  • At least one of the solvents present in the microemulsion an ester of fatty acid, either naturally occurring or synthetic with the formula
  • R 7 0(C OR 8 ), wherein R 7 and R 8 are the same or different and are cyclic or acyclic, branched or unbranched alkyl (e.g., Cl-16 alkyl), optionally substituted.
  • R 7 and R 8 are the same or different and are cyclic or acyclic, branched or unbranched alkyl (e.g., Cl-16 alkyl), optionally substituted.
  • each of R and R are the same or different and are cyclic or acyclic
  • R and R is methyl, ethyl, propyl, or butyl.
  • Non-limiting examples include isomers of methyl octanoate, methyl decanoate, methyl dodecanoate, methyl undecanoate, methyl hexadecanoate, ethyl octanoate, ethyl decanoate, ethyl dodecanoate, ethyl undecanoate, ethyl
  • the esters are selected from the group consisting of methyl dodecanoate, methyl hexadecanoate, ethyl dodecanoate, ethyl hexadecanoate, propyl dodecanoate, propyl hexadecanoate, butyl dodecanoate, and butyl hexadecanoate.
  • Non-limiting examples include isomers of octyl octanoate, nonyl, nonanoate, decyl decanoate,undecyl undecanoate, dodecyl decanoate, hexadecyl hexadecanoate.
  • the esters are selected from the group consisting of octyl octonoate and decyl decanoate.
  • At least one of the solvents present in the microemulsion is a terpene or a terpenoid.
  • the terpene or terpenoid comprises a first type of terpene or terpenoid and a second type of terpene or terpenoid.
  • Terpenes may be generally classified as monoterpenes (e.g., having two isoprene units), sesquiterpenes (e.g., having 3 isoprene units), diterpenes, or the like.
  • terpenoid also includes natural degradation products, such as ionones, and natural and synthetic derivatives, e.g., terpene alcohols, aldehydes, ketones, acids, esters, epoxides, and hydrogenation products (e.g., see Ullmann's Encyclopedia of Industrial Chemistry, 2012, pages 29-45, herein incorporated by reference). It should be understood, that while much of the description herein focuses on terpenes, this is by no means limiting, and terpenoids may be employed where appropriate. In some cases, the terpene is a naturally occurring terpene.
  • the terpene is a non-naturally occurring terpene and/or a chemically modified terpene (e.g., saturated terpene, terpene amine, fluorinated terpene, or silylated terpene).
  • a chemically modified terpene e.g., saturated terpene, terpene amine, fluorinated terpene, or silylated terpene.
  • the terpene is a monoterpene.
  • Monoterpenes may be further classified as acyclic, monocyclic, and bicyclic (e.g., with a total number of carbons in the range between 18-20), as well as whether the monoterpene comprises one or more oxygen atoms (e.g., alcohol groups, ester groups, carbonyl groups, etc.).
  • the terpene is an oxygenated terpene, for example, a terpene comprising an alcohol, an aldehyde, and/or a ketone group.
  • the terpene comprises an alcohol group.
  • Non-limiting examples of terpenes comprising an alcohol group are linalool, geraniol, nopol, a-terpineol, and menthol.
  • the terpene comprises an ether-oxygen, for example, eucalyptol, or a carbonyl oxygen, for example, menthone.
  • the terpene does not comprise an oxygen atom, for example, d-limonene.
  • Non-limiting examples of terpenes include linalool, geraniol, nopol, a-terpineol, menthol, eucalyptol, menthone, d-limonene, terpinolene, ⁇ -occimene, ⁇ -terpinene, a-pinene, and citronellene.
  • the terpene is selected from the group consisting of a-terpeneol, a-pinene, nopol, and eucalyptol.
  • the terpene is nopol.
  • the terpene is eucalyptol.
  • some embodiment are examples of terpenes.
  • the terpene is not limonene (e.g., d-limonene). In some embodiments, the emulsion is free of limonene.
  • the terpene is a non-naturally occurring terpene and/or a chemically modified terpene (e.g., saturated terpene). In some cases, the terpene is a partially or fully saturated terpene (e.g., p-menthane, pinane). In some cases, the terpene is a non-naturally occurring terpene.
  • Non-limiting examples of non-naturally occurring terpenes include, menthene, p-cymene, r-carvone, terpinenes (e.g., alpha-terpinenes, beta-terpinenes, gamma-terpinenes), dipentenes, terpinolenes, borneol, alpha- terpinamine, and pine oils.
  • the terpene is classified in terms of its phase inversion temperature (PIT).
  • phase inversion temperature is given its ordinary meaning in the art and refers to the temperature at which an oil in water microemulsion inverts to a water in oil microemulsion (or vice versa).
  • PIT phase inversion temperature
  • Those of ordinary skill in the art will be aware of methods for determining the PIT for a microemulsion comprising a terpene (e.g., see Strey, Colloid & Polymer Science, 1994. 272(8): p. 1005-1019; Kahlweit et al, Angewandte Chemie International Edition in English, 1985. 24(8): p. 654-668).
  • the PIT values described herein were determined using a 1 : 1 ratio of terpene (e.g., one or more terpenes): de-ionized water and varying amounts (e.g., between about 20 wt% and about 60 wt%; generally, between 3 and 9 different amounts are employed) of a 1 : 1 blend of surfactant comprising linear C 12 -C 15 alcohol ethoxylates with on average 7 moles of ethylene oxide (e.g., Neodol 25-7):isopropyl alcohol wherein the upper and lower temperature boundaries of the microemulsion region can be determined and a phase diagram may be generated.
  • a 1 : 1 ratio of terpene e.g., one or more terpenes
  • de-ionized water varying amounts (e.g., between about 20 wt% and about 60 wt%; generally, between 3 and 9 different amounts are employed) of a 1 : 1 blend of surfactant comprising linear C 12
  • phase diagram e.g., a plot of temperature against surfactant concentration at a constant oil-to-water ratio
  • fish diagram e.g., a plot of temperature against surfactant concentration at a constant oil-to-water ratio
  • Kahlweit plot The temperature at the vertex is the PIT.
  • An exemplary fish diagram indicating the PIT is shown in Figure 1.
  • PITs for non-limiting examples of terpenes determined using this experimental procedure outlined above are given in Table 1.
  • Table 1 Phase inversion temperatures for non-limiting examples of terpenes.
  • the solvent utilized in the emulsion or microemulsion herein may comprise one or more impurities.
  • a solvent e.g., a terpene
  • the solvent comprises a crude cut (e.g., uncut crude oil, for example, made by settling, separation, heating, etc.).
  • the solvent is a crude oil (e.g., naturally occurring crude oil, uncut crude oil, crude oil extracted from the wellbore, synthetic crude oil, crude citrus oil, crude pine oil, eucalyptus, etc.).
  • a crude oil e.g., naturally occurring crude oil, uncut crude oil, crude oil extracted from the wellbore, synthetic crude oil, crude citrus oil, crude pine oil, eucalyptus, etc.
  • the solvent is a citrus extract (e.g., crude orange oil, orange oil, etc.).
  • a citrus extract e.g., crude orange oil, orange oil, etc.
  • At least one of the solvents comprised in the emulsion or microemulsion comprising a mutual solvent which is miscible together with the water and the solvent.
  • the mutual solvent is present in an amount between about at 0.5 wt% to about 30% of mutual solvent.
  • suitable mutual solvents include ethyleneglycolmonobutyl ether (EGMBE), dipropylene glycol monomethyl ether, short chain alcohols (e.g., isopropanol), tetrahydrofuran, dioxane, dimethylformamide, and dimethylsulfoxide.
  • the microemulsion comprises an aqueous phase.
  • the aqueous phase comprises water.
  • the water may be provided from any suitable source (e.g., sea water, fresh water, deionized water, reverse osmosis water, water from field production).
  • the water may be present in any suitable amount.
  • the total amount of water present in the microemulsion is between about 1 wt% about 95 wt%, or between about 1 wt% about 90 wt%, or between about 1 wt% and about
  • the water to solvent ratio in a microemulsion may be varied. In some embodiments,
  • the ratio of water to solvent, along with other parameters of the solvent may be varied.
  • the ratio of water to solvent by weight is between about 15: 1 and 1 : 10, or between 9: 1 and 1 :4, or between 3.2: 1 and 1 :4.
  • the microemulsion comprises a surfactant.
  • the microemulsion may comprise a single surfactant or a combination of two or more surfactants.
  • the surfactant comprises a first type of surfactant and a second type of surfactant.
  • surfactant is given its ordinary meaning in the art and refers to compounds having an amphiphilic structure which gives them a specific affinity for oil/water-type and water/oil-type interfaces which helps the compounds to reduce the free energy of these interfaces and to stabilize the dispersed phase of a microemulsion.
  • surfactant encompasses cationic surfactants, anionic surfactants, amphoteric surfactants, nonionic surfactants, zwitterionic surfactants, and mixtures thereof.
  • the surfactant is a nonionic surfactant.
  • Nonionic surfactants generally do not contain any charges.
  • Amphoteric surfactants generally have both positive and negative charges, however, the net charge of the surfactant can be positive, negative, or neutral, depending on the pH of the solution.
  • Anionic surfactants generally possess a net negative charge.
  • Cationic surfactants generally possess a net positive charge.
  • Zwitterionic surfactants are generally not pH dependent.
  • a zwitterion is a neutral molecule with a positive and a negative electrical charge, though multiple positive and negative charges can be present. Zwitterions are distinct from dipole, at different locations within that molecule.
  • the surfactant is an amphiphilic block copolymer where one block is hydrophobic and one block is hydrophilic. In some cases, the total molecular weight of the polymer is greater than 5000 daltons.
  • the hydrophilic block of these polymers can be nonionic, anionic, cationic, amphoteric, or zwitterionic.
  • surface energy is given its ordinary meaning in the art and refers to the extent of disruption of intermolecular bonds that occur when the surface is created (e.g., the energy excess associated with the surface as compared to the bulk).
  • surface energy is also referred to as surface tension (e.g., for liquid-gas interfaces) or interfacial tension (e.g., for liquid-liquid interfaces).
  • surfactants generally orient themselves across the interface to minimize the extent of disruption of intermolecular bonds (i.e. lower the surface energy).
  • a surfactant at an interface between polar and non-polar phases orient themselves at the interface such that the difference in polarity is minimized.
  • the surfactant(s) are matched to and/or optimized for the particular oil or solvent in use.
  • the surfactant(s) are selected by mapping the phase behavior of the microemulsion and choosing the surfactant(s) that gives the desired range of phase behavior.
  • the stability of the microemulsion over a wide range of temperatures is targeted as the microemulsion may be subject to a wide range of temperatures due to the environmental conditions present at the subterranean formation and/or reservoir.
  • the surfactant may be present in the microemulsion in any suitable amount.
  • the surfactant is present in an amount between about 0 wt% and about 99 wt%, or between about 1 wt% and about 90 wt%, or between about 0 wt% and about 60 wt%, or between about 1 wt% and about 60 wt%, or between about 5 wt% and about 60 wt%, or between about 10 wt% and about 60 wt%, or between about 5 wt% and about 65 wt%, or between about 5 wt% and about 55 wt%, or between about 10 wt% and about 55 wt%, or between about 2 wt% and about 50 wt%, or between about 0 wt% and about 40 wt%, or between about 15 wt% and about 55 wt%, or between about 20 wt% and about 50 wt%, versus the total microemulsion composition.
  • the surfactant is an alkyl polyglycol ether, for example, having 2-250 ethylene oxide (EO) (e.g., or 2-200, or 2-150, or 2-100, or 2-50, or 2-40) units and alkyl groups of 4-20 carbon atoms.
  • the surfactant is an alkylaryl polyglycol ether having 2-250 EO units (e.g., or 2-200, or 2- 150, or 2-100, or 2-50, or 2-40) and 8-20 carbon atoms in the alkyl and aryl groups.
  • the surfactant is an ethylene oxide/propylene oxide (EO/PO) block copolymer having 2-250 EO or PO units (e.g., or 2-200, or 2-150, or 2-100, or 2-50, or 2-40).
  • the surfactant is a fatty acid polyglycol ester having 6-24 carbon atoms and 2-250 EO units (e.g., or 2-200, or 2-150, or 2-100, or 2-50, or 2-40).
  • the surfactant is a polyglycol ether of hydroxyl-containing triglycerides (e.g., castor oil).
  • the surfactant is an ethylene oxide/propylene oxide block copolymer having 2-250 EO or PO units (e.g., or 2-200, or 2-150, or 2-100, or 2-50, or 2-40).
  • the surfactant is a fatty acid polyglycol ester having 6-24 carbon atoms and 2-250 EO units (e.g., or 2-200, or 2-150, or 2-
  • the surfactant is a fatty ester of glycerol, sorbitol, or pentaerythritol.
  • the surfactant is an amine oxide (e.g., dodecyldimethylamine oxide).
  • the surfactant is an alkyl sulfate, for example having a chain length of 8-18 carbon atoms, alkyl ether sulfates having 8-18 carbon atoms in the hydrophobic group and 1-40 ethylene oxide (EO) or propylene oxide (PO) units.
  • EO ethylene oxide
  • PO propylene oxide
  • the surfactant is a sulfonate, for example, an alkyl sulfonate having 8-18 carbon atoms, an alkylaryl sulfonate having 8-18 carbon atoms, an ester or half ester of sulfosuccinic acid with monohydric alcohols or alkylphenols having 4-15 carbon atoms, or a multisulfonate (e.g., comprising two, three, four, or more, sulfonate groups).
  • the alcohol or alkylphenol can also be ethoxylated with 1-250 EO units (e.g., or 2-200, or 2-150, or 2-100, or 2-50, or 2-40).
  • the surfactant is an alkali metal salt or ammonium salt of a carboxylic acid or poly(alkylene glycol) ether carboxylic acid having 8-20 carbon atoms in the alkyl, aryl, alkaryl or aralkyl group and 1-250 EO or PO units (e.g., or 2-200, or 2- 150, or 2-100, or 2-50, or 2-40).
  • the surfactant is a partial phosphoric ester or the corresponding alkali metal salt or ammonium salt, e.g., an alkyl and alkaryl phosphate having 8-20 carbon atoms in the organic group, an alkylether phosphate or alkarylether phosphate having 8-20 carbon atoms in the alkyl or alkaryl group and 1-250 EO units (e.g., or 2-200, or 2-150, or 2-100, or 2-50, or 2-40).
  • the surfactant is a salt of primary, secondary, or tertiary fatty amine having 8-24 carbon atoms with acetic acid, sulfuric acid, hydrochloric acid, and phosphoric acid.
  • the surfactant is a quaternary alkyl- and alkylbenzylammonium salt, whose alkyl groups have 1-24 carbon atoms (e.g., a halide, sulfate, phosphate, acetate, or hydroxide salt).
  • the surfactant is an alkylpyridinium, an alkylimidazolinium, or an alkyloxazolinium salt whose alkyl chain has up to 18 carbons atoms (e.g., a halide, sulfate, phosphate, acetate, or hydroxide salt).
  • the surfactant is amphoteric or zwitterionic, including sultaines (e.g., cocamidopropyl hydroxysultaine), betaines (e.g., cocamidopropyl betaine), or phosphates (e.g., lecithin).
  • sultaines e.g., cocamidopropyl hydroxysultaine
  • betaines e.g., cocamidopropyl betaine
  • phosphates e.g., lecithin
  • Non-limiting examples of specific surfactants include a linear C12-C15 ethoxylated alcohols with 5-12 moles of EO, lauryl alcohol ethoxylate with 4-8 moles of EO, nonyl phenol ethoxylate with 5-9 moles of EO, octyl phenol ethoxylate with 5-9 moles of EO, tridecyl alcohol ethoxylate with 5-9 moles of EO, Pluronic® matrix of EO/PO copolymers, ethoxylated cocoamide with 4-8 moles of EO, ethoxylated coco fatty acid with 7-11 moles of EO, and cocoamidopropyl amine oxide.
  • the surfactant is a siloxane surfactant as described in U.S. Patent Application Serial No. 13/831,410, filed March 14, 2014, herein incorporated by reference.
  • the surfactant is a Gemini surfactant.
  • Gemini surfactants generally have the structure of multiple amphiphilic molecules linked together by one or more covalent spacers.
  • the surfactant is an extended surfactant, wherein the extended surfactats has the structure where a non-ionic hydrophilic spacer (e.g. ethylene oxide or propylene oxide) connects an ionic hydrophilic group (e.g.
  • the surfactant is an alkoxylated polyimine with a relative solubility number (RSN) in the range of 5-20.
  • RSN values are generally determined by titrating water into a solution of surfactant in l,4dioxane. The RSN values is generally defined as the amount of distilled water necessary to be added to produce persistent turbidity.
  • the surfactant is an alkoxylated novolac resin (also known as a phenolic resin) with a relative solubility number in the range of 5-20.
  • the surfactant is a block copolymer surfactant with a total molecular weight greater than 5000 daltons.
  • the block copolymer may have a hydrophobic block that is comprised of a polymer chain that is linear, branched, hyperbranched, dendritic or cyclic.
  • monomeric repeat units in the hydrophobic chains of block copolymer surfactants are isomers of acrylic, methacrylic, styrenic, isoprene, butadiene, acrylamide, ethylene, propylene and norbornene.
  • the block copolymer may have a hydrophilic block that is comprised of a polymer chain that is linear, branched, hyper branched, dendritic or cyclic.
  • monomeric repeat units in the hydrophilic chains of the block copolymer surfactants are isomers of acrylic acid, maleic acid, methacrylic acid, ethylene oxide, and acrylamine.
  • the surfactant has a structure as in Formula I:
  • R 12 hydrogen or Ci_ 6 alkyl.
  • R is H, methyl, or ethyl.
  • R 12 is H.
  • the surfactant has a structure as in Formula II:
  • X is a metal cation or N(R ) 4 , wherein each R is independently selected from the group consisting of hydrogen, optionally substituted alkyl, or optionally substituted aryl. In some embodiments, X is NH 4 .
  • metal cations are Na ⁇ , K ⁇ ,
  • Y " is -O " , - S0 2 0 " , or -OSO 2 O " .
  • the surfactant has a structure as in Formula III:
  • Ar is phenyl.
  • Z is N(R ) 3 , wherein each R 13 is independent selected from the group consisting of hydrogen, optionally substituted alkyl, or optionally substituted aryl.
  • Ar is phenyl.
  • each m is 1.
  • each m is 2.
  • n is 6-100, or 1-50, or 6-50, or 6-25, or 1-25, or 5-50, or 5-25, or 5-20.
  • an emulsion or microemulsion comprises a surfactant of Formula (I), (II), or (III) in an amount between about 1 wt% and about 20 wt%, or between about 3 wt% and about 15 wt%, or between about 5 wt% and about 13 wt%, or between about 5 wt% and about 11 wt%, or between about 7 wt% and about 11 wt%, or between about 10 wt% and about 12 wt%, or between about 8 wt% and about 12 wt%, or between about 8 wt% and about 10 wt%, or about 9 wt%.
  • a surfactant of Formula (I), (II), or (III) in an amount between about 1 wt% and about 20 wt%, or between about 3 wt% and about 15 wt%, or between about 5 wt% and about 13 wt%, or between about 5 wt% and about 11 wt%, or
  • the emulsion or microemulsion comprises, in addition to the surfactant of Formula (I), (II), or (III), water and a non-aqueous phase (e.g., a terpene), and optionally other additives (e.g., one or more additional surfactants, an alcohol, a freezing point depression agent, etc.).
  • the emulsion or microemulsion comprises, in addition to the surfactant of Formula (I), (II), or (III), water, a terpene, an alcohol, one or more additional surfactants, and optionally other additives (e.g., a freezing point depression agent).
  • the emulsion or microemulsion comprises, in addition to the surfactant of Formula (I), (II), or (III), between about 20 wt% and 90 wt% water, between about 2 wt% and about 70 wt% of one or more additional surfactants, between about 1 wt% and about 80 wt% of a solvent (e.g., terpene), and between about 10 wt% and about 40 wt% of a mutual solvent (e.g., alcohol).
  • a solvent e.g., terpene
  • a mutual solvent e.g., alcohol
  • the emulsion or microemulsion comprises, in addition to the surfactant of Formula (I), (II), or (III), between about 10 wt% and 80 wt% water, between about 2 wt% and about 80 wt% of one or more additional surfactants, between about 1 wt% and about 70 wt% of a solvent (e.g., terpene), and between about 5 wt% and about 40 wt% of a mutual solvent (e.g., alcohol).
  • a solvent e.g., terpene
  • a mutual solvent e.g., alcohol
  • the emulsion or microemulsion comprises, in addition to the surfactant of Formula (I), (II), or (III), between about 20 wt% and 90 wt% water, between about 2 wt% and about 70 wt% of one or more additional surfactants, between about 1 wt% and about 78 wt% of a solvent (e.g., terpene), and between about 22 wt% and about 40 wt% of a mutual solvent (e.g., alcohol).
  • a solvent e.g., terpene
  • a mutual solvent e.g., alcohol
  • Non-limiting examples of surfactants of Formula (I), (II), or (III) include styrylphenol ethoxylate, a tristyrylphenol ethoxylate, a styrylphenol propoxylate, a tristyrylphenol propoxylate, a styrylphenol ethoxylate propoxylate, or a tristyrylphenol ethoxylate propoxylate.
  • the emulsion or microemulsion may comprise one or more additives in addition to water, solvent (e.g., one or more types of solvents), and surfactant (e.g., one or more types of surfactants).
  • the additive is an alcohol, a freezing point depression agent, an acid, a salt, a proppant, a scale inhibitor, a friction reducer, a biocide, a corrosion inhibitor, a buffer, a viscosifier, a clay swelling inhibitor, an oxygen scavenger, and/or a clay stabilizer.
  • the microemulsion comprises an alcohol.
  • the alcohol may serve as a coupling agent between the solvent and the surfactant and aid in the stabilization of the microemulsion.
  • the alcohol may also lower the freezing point of the microemulsion.
  • the microemulsion may comprise a single alcohol or a combination of two or more alcohols.
  • the alcohol is selected from primary, secondary and tertian' alcohols having between 1 and 20 carbon atoms.
  • the alcohol comprises a first type of alcohol and a second type of alcohol.
  • Non-limiting examples of alcohols include methanol, ethanol, isopropanol, n-propanol, n-butanol, i-butanol, sec-butanol, iso-butanol, and t-butanol.
  • the alcohol is ethanol or isopropanol.
  • the alcohol is isopropanol.
  • the alcohol may be present in the emulsion in any suitable amount. In some embodiments, the alcohol is present in an amount between about 0 wt% and about 50 wt%, or between about 0.1 wt% and about 50 wt%, or between about 1 wt% and about 50 wt%, or between about 2 wt% and about 50 wt% or between about 5 wt% and about 40 wt%, or between about 5 wt% and 35 wt%, versus the total microemulsion composition.
  • the microemulsion comprises a freezing point depression agent.
  • the microemulsion may comprise a single freezing point depression agent or a combination of two or more freezing point depression agents.
  • the freezing point depression agent comprises a first type of freezing point depression agent and a second type of freezing point depression agent.
  • the term freezing point depression agent is given its ordinary meaning in the art and refers to a compound which is added to a solution to reduce the freezing point of the solution. That is, a solution comprising the freezing point depression agent has a lower freezing point as compared to an essentially identical solution not comprising the freezing point depression agent.
  • Non-limiting examples of freezing point depression agents include primary, secondary, and tertiary alcohols with between 1 and 20 carbon atoms.
  • the alcohol comprises at least 2 carbon atoms, alkylene glycols including polyalkylene glycols, and salts.
  • Non-limiting examples of alcohols include methanol, ethanol, i-propanol, n-propanol, t-butanol, n-butanol, n-pentanol, n-hexanol, and 2-ethyl-hexanol.
  • the freezing point depression agent is not methanol (e.g., due to toxicity).
  • alkylene glycols include ethylene glycol (EG), polyethylene glycol (PEG), propylene glycol (PG), and triethylene glycol (TEG).
  • EG ethylene glycol
  • PEG polyethylene glycol
  • PG propylene glycol
  • TOG triethylene glycol
  • the freezing point depression agent is not ethylene oxide (e.g., due to toxicity).
  • the freezing point depression agent comprises an alcohol and an alkylene glycol.
  • the freezing point depression agent comprises a carboxycyclic acid salt and/or a di-carboxycylic acid salt.
  • Another non-limiting example of a freezing point depression agent is a combination of choline chloride and urea.
  • the microemulsion comprising the freezing point depression agent is stable over a wide range of temperatures, for example, between about -50 °F to 200 °F.
  • the freezing point depression agent may be present in the microemulsion in any suitable amount.
  • the freezing point depression agent is present in an amount between about 0 wt% and about 70 wt%, or between about 0.5 and 30 wt%, or between about 1 wt% and about 40 wt%, or between about 0 wt% and about 25 wt%, or between about 1 wt% and about 25 wt%, or between about 1 wt% and about 20 wt%, or between about 3 wt% and about 20 wt%, or between about 8 wt% and about 16 wt%, versus the total microemulsion composition.
  • microemulsion may comprise other additives.
  • the microemulsion may comprise an acid and/or a salt.
  • other additives include proppants, scale inhibitors, friction reducers, biocides, corrosion inhibitors, buffers, viscosifiers, clay swelling inhibitors, paraffin dispersing additives, asphaltene dispersing additives, and oxygen scavengers.
  • proppants include grains of sand, glass beads, crystalline silica (e.g., Quartz), hexamethylenetetramine, ceramic proppants (e.g., calcined clays), resin coated sands, and resin coated ceramic proppants.
  • crystalline silica e.g., Quartz
  • ceramic proppants e.g., calcined clays
  • resin coated sands e.g., calcined clays
  • resin coated ceramic proppants e.g., resin coated ceramic proppants.
  • Other proppants are also possible and will be known to those skilled in the art.
  • Non-limiting examples of scale inhibitors include one or more of methyl alcohol, organic phosphonic acid salts (e.g., phosphonate salt), polyacrylate, ethane- 1,2-diol, calcium chloride, and sodium hydroxide.
  • organic phosphonic acid salts e.g., phosphonate salt
  • polyacrylate e.g., polyacrylate
  • ethane- 1,2-diol calcium chloride
  • sodium hydroxide sodium hydroxide
  • Non-limiting examples of buffers include acetic acid, acetic anhydride, potassium hydroxide, sodium hydroxide, and sodium acetate.
  • Other buffers are also possible and will be known to those skilled in the art.
  • Non-limiting examples of corrosion inhibitors include isopropanol, quaternary ammonium compounds, thiourea/formaldehyde copolymers, propargyl alcohol and methanol.
  • Other corrosion inhibitors are also possible and will be known to those skilled in the art.
  • biocides include didecyl dimethyl ammonium chloride, gluteral, Dazomet, bronopol, tributyl tetradecyl phosphonium chloride, tetrakis
  • Non-limiting examples of clay swelling inhibitors include quaternary ammonium chloride and tetramethylammonium chloride. Other clay swelling inhibitors are also possible and will be known to those skilled in the art.
  • friction reducers include petroleum distillates, ammonium salts, polyethoxylated alcohol surfactants, and anionic polyacrylamide copolymers. Other friction reducers are also possible and will be known to those skilled in the art.
  • Non-limiting examples of oxygen scavengers include sulfites, and bisulfites.
  • oxygen scavengers are also possible and will be known to those skilled in the art.
  • paraffin dispersing additives and asphaltene dispersing additives include active acidic copolymers, active alkylated polyester, active alkylated polyester amides, active alkylated polyester imides, aromatic naphthas, and active amine sulfonates.
  • Other paraffin dispersing additives are also possible and will be known to those skilled in the art.
  • the other additives are present in an amount between about 0 wt% about 70 wt%, or between about 0 wt % and about 30 wt%, or between about 1 wt% and about 30 wt%, or between about 1 wt% and about 25 wt%, or between about 1 and about 20 wt%, versus the total microemulsion composition.
  • the microemulsion comprises an acid or an acid precursor.
  • the microemulsion may comprise an acid when used during acidizing operations.
  • the microemulsion may comprise a single acid or a combination of two or more acids.
  • the acid comprises a first type of acid and a second type of acid.
  • acids or di-acids include
  • the microemulsion comprises an organic acid or organic di-acid in the ester (or di-ester) form, whereby the ester (or diester) is hydrolyzed in the wellbore and/or reservoir to form the parent organic acid and an alcohol in the wellbore and/or reservoir.
  • esters or di-esters include isomers of methyl formate, ethyl formate, ethylene glycol diformate, a,a-4-trimethyl-3-cyclohexene-l-methylformate, methyl lactate, ethyl lactate, ⁇ , ⁇ -4- trimethyl 3-cyclohexene-l-methyllactate, ethylene glycol dilactate, ethylene glycol diacetate, methyl acetate, ethyl acetate, a,a,-4-trimethyl-3-cyclohexene-l-methylacetate, dimethyl succinate, dimethyl maleate, di(a,a-4-trimethyl-3-cyclohexene-l- methyl)succinate, 1 -methyl -4-(l-methylethenyl)-cyclohexylformate, l-methyl-4-(l- ethylethenyl)cyclohexylactate, 1 -methyl-4-( 1 -methylethen
  • the microemulsion comprises a salt.
  • the presence of the salt may reduce the amount of water needed as a carrier fluid, and in addition, may lower the freezing point of the microemulsion.
  • the microemulsion may comprise a single salt or a combination of two or more salts.
  • the salt comprises a first type of salt and a second type of salt.
  • Non-limiting examples of salts include salts comprising K, Na, Br, Cr, Cs, or Li, for example, halides of these metals, including NaCl, KC1, CaCl 2 , and MgCl 2 .
  • the microemulsion comprises a clay stabilizer.
  • the microemulsion may comprise a single clay stabilizer or a combination of two or more clay stabilizers.
  • the salt comprises a first type of clay stabilizer and a second type of clay stabilizer.
  • Non-limiting examples of clay stabilizers include salts above, polymers (PAC, PHP A, etc), glycols, sulfonated asphalt, lignite, sodium silicate, and choline chloride.
  • the components of the microemulsion and/or the amounts of the components are selected such that the microemulsion is stable over a wide-range of temperatures.
  • the microemulsion may exhibit stability between about -40 °F and about 400 °F, or between about -40 °F and about 300 °F or between about -40 °F and about 150 °F.
  • the lower boundary may be determined by the freezing point and the upper boundary may be determined by the cloud point and/or using spectroscopy methods.
  • Stability over a wide range of temperatures may be important in embodiments where the microemulsions are being employed in applications comprising environments wherein the temperature may vary significantly, or may have extreme highs (e.g., desert) or lows (e.g., artic).
  • microemulsions described herein may be formed using methods known to those of ordinary skill in the art.
  • the aqueous and non-aqueous phases may be combined (e.g., the water and the solvent(s)), followed by addition of a surfactant(s) and optionally (e.g., freezing point depression agent(s)) and agitation.
  • a surfactant(s) and optionally e.g., freezing point depression agent(s)
  • the strength, type, and length of the agitation may be varied as known in the art depending on various factors including the components of the microemulsion, the quantity of the microemulsion, and the resulting type of microemulsion formed.
  • Agitation may be provided by any suitable source, for example, a vortex mixer, a stirrer (e.g., magnetic stirrer), etc.
  • any suitable method for injecting the microemulsion e.g., a diluted microemulsion
  • microemulsion into a wellbore
  • the microemulsion may be injected into a subterranean formation by injecting it into a well or wellbore in the zone of interest of the formation and thereafter pressurizing it into the formation for the selected distance.
  • Methods for achieving the placement of a selected quantity of a mixture in a subterranean formation are known in the art.
  • the well may be treated with the microemulsion for a suitable period of time.
  • the microemulsion and/or other fluids may be removed from the well using known techniques, including producing the well.
  • the microemulsion may be diluted and/or combined with other liquid component(s) prior to and/or during injection (e.g., via straight tubing, via coiled tubing, etc.).
  • the microemulsion is diluted with an aqueous carrier fluid (e.g., water, brine, sea water, fresh water, or a well- treatment fluid (e.g., an acid, a fracturing fluid comprising polymers, produced water, sand, slickwater, etc.,)) prior to and/or during injection into the wellbore.
  • an aqueous carrier fluid e.g., water, brine, sea water, fresh water, or a well- treatment fluid (e.g., an acid, a fracturing fluid comprising polymers, produced water, sand, slickwater, etc.,)
  • a composition for injecting into a wellbore comprising a microemulsion as described herein and an aqueous carrier fluid, wherein the microemulsion is present in an amount between about 0.1 and about 50 gallons per thousand gallons (gpt) per dilution fluid, or between 0.1 and about 100 gpt, or between about 0.5 and about 10 gpt, or between about 0.5 and about 2 gpt.
  • gpt gallons per thousand gallons
  • emulsions and microemulsions described herein may be used in various aspects of the life cycle of an oil and/or gas well, including, but not limited to, drilling, mud displacement, casing, cementing, perforating, stimulation, enhanced oil recovery/ improved oil recovery, etc.).
  • drilling, mud displacement, casing, cementing, perforating, stimulation enhanced oil recovery/ improved oil recovery, etc.
  • inclusion of an emulsion or microemulsion into the fluids typically employed in these processes for example, drilling fluids, mud displacement fluids, casing fluids, cementing fluids, perforating fluid, stimulation fluids, kill fluids, etc., results in many advantages as compared to use of the fluid alone.
  • each step may occur more than once in the life cycle of the well.
  • fracturing may be followed by stimulations, followed by additional fracturing steps.
  • refracturing, or the process of repeating the above stimulation processes is further improved by the addition of an emulsion or microemulsion to the stimulation fluid.
  • drilling to form wellbores typically requires the displacement (e.g., using a drill pipe and a drill bit) of reservoir material (e.g., rock, sand, stone, or the like).
  • reservoir material e.g., rock, sand, stone, or the like.
  • Such drilling generally requires the use of certain drilling fluids which may, for example, lubricate and/or cool the drill bit, assist in the removal of earth (e.g., cuttings), create and/or balance hydrostatic head pressure (e.g., to prevent, for example, a collapse of the hole being formed by the drill bit, to control the flow of hydrocarbons and/or water into the wellbore, to decrease swelling of the surrounding reservoir material), and/or to control or prevent a kick (e.g., an explosive moving of drilling fluid back to the surface).
  • a kick e.g., an explosive moving of drilling fluid back to the surface.
  • Non-limiting examples of drilling fluids include water-based systems, oil-based systems (e.g., synthetic oil-based systems, low viscosity oils such as diesel, crude oil, etc.).
  • water-based systems the water may comprise one or more additives, for example, salts (e.g., to form brine), solid particles, etc.
  • oil-based systems the oil can comprise any oil including, by not limited to, mineral oil, esters, and alpha-olefms.
  • the drilling fluid comprises a foam or a mist.
  • the drilling fluid is a water-based system.
  • drilling fluids include one or more minerals or additives (e.g., hematite, montmorillionite, barite, bentonite, ilmenite, lignite, lignosulfonate, slacked lime, sodium hydroxide, etc.).
  • minerals or additives e.g., hematite, montmorillionite, barite, bentonite, ilmenite, lignite, lignosulfonate, slacked lime, sodium hydroxide, etc.
  • the drilling fluid comprises an emulsion or
  • an additional emulsion or microemulsion in the drilling fluid may have many advantages as compared to the use of a drilling fluid alone, including, for example, decreasing the swelling of the surrounding reservoir, changing (e.g., increasing or decreasing) the viscosity of the drilling fluid, decreasing the amount of water absorbed into the well during the drilling process, increasing the amount of water extracted from the reservoir, changing (e.g., increasing and/or decreasing) the amount of contaminants and/or particulates extracted from the reservoir, and/or increasing the amount of oil and/or gas extracted from the reservoir.
  • the oil and/or gas comprises an oil and/or gas condensate.
  • the composition of a drilling fluid may change during the process of drilling.
  • imbibition is a nearly instantaneous process that occurs when water comes in contact with the exposed primary permeability of, for example, water wet shales and/or clays.
  • This exposed primary permeability may be on the face of the drilled cuttings and borehole wall and/or along the faces of the naturally occurring micro -fractures (secondary permeability).
  • secondary permeability the overall depth of invasion into the formation may be directly related to the depth of the micro-fractures and the volume of whole water base fluid and/or filtrate allowed to imbibe into the micro-fractures.
  • the speed of invasion of the available water base fluid or filtrate into the secondary permeability is generally related to the primary permeability features of capillary diameters and degree of saturation of the shales and/or clays.
  • the addition of an emulsion or microemulsion in the drilling fluid may have advantages as compared to the use of a drilling fluid alone, including, for example, the controlling imbibition (e.g., prevention, reduction, or increase of imbibition).
  • the drilling fluid comprises an emulsion or microemulsion as described herein wherein the emulsion or microemulsion is present in an amount between about 0.5 and about 200 gallons per thousand gallons (gpt) of drilling fluid, or between about 0.5 and about 100 gpt, or between about 0.5 and about 50 gpt, or between about 1 and about 50 gpt, or between about 1 and about 20 gpt, or between about 2 and about 20 gpt, or between about 2 and about 10 gpt, or between about 2 and about 5 gpt. In certain embodiments, the emulsion or microemulsion is present in an amount between about 5 and about 10 gpt.
  • the drilling fluid contains at least about 0.5 gpt, or at least about 1 gpt, or at least about 2 gpt, or at least about 4 gpt, or at least about 10 gpt, or at least about 20 gpt, or at least about 50 gpt, or at least about 100 gpt, or at least about 200 gpt, of an emulsion or a microemulsion.
  • the drilling fluid contains less than or equal to about 200 gpt, or less than or equal to about 100 gpt, or less than or equal to about 50 gpt, or less than or equal to about 20 gpt, or less than or equal to about 10 gpt, or less than or equal to about 4 gpt, or less than or equal to about 2 gpt, or less than or equal to about 1 gpt, or less than or equal to about 0.5 gpt of an emulsion or microemulsion.
  • Stabilizing the wellbore may include inserting a casing (e.g., metal sleeves, steel tubes, and the like) down the wellbore.
  • a cement is injected in the annulus between the wellbore and casing to add further stability.
  • additional fluids e.g., a mud displacement fluid
  • a mud displacement fluid refers to a fluid that displaces drilling mud.
  • a mud displacement fluid is typically injected at high pressure into the inner core of the casing, and exits at the bottom of the casing, returning to the surface via the annular region between the casing and the sides of the wellbore.
  • the mud displacement fluid may be injected at a high pressure between the casing and the sides of the wellbore and exits at the bottom of the casing, returning to the surface via the inner core of the casing.
  • a non-limiting example of a mud displacement fluid includes a water-based system.
  • the mud displacement fluid comprises water and one or more solvents, surfactants, and/or other additives known to those skilled in the art.
  • the mud displacement fluid comprises an emulsion or microemulsion.
  • Emulsions and microemulsions are described in more detail herein.
  • the addition of an emulsion or microemulsion in the mud displacement fluid may have many advantages as compared to the use of a mud displacement fluid alone including, for example, preventing or minimizing damage from imbibition, assisting in liquification and removal of filter cakes, and/or preparing the hole for cementation.
  • the presence of the emulsion or the microemulsion in the mud displacement fluid may result in improved (e.g., increased) delivery of the fluid to portions of the well, which aids in displacing surface contamination, which can result in less imbibition, formation blockages, and/or improves surfaces for cementing.
  • the mud displacement fluid comprises an emulsion or microemulsion as described herein wherein the emulsion or microemulsion is present in an amount between about 0.5 and about 200 gpt of mud displacement fluid, or between about 0.5 and about 100 gpt, or between about 0.5 and about 50 gpt, or between about 1 and about 50 gpt, or between about 1 and about 20 gpt, or between about 2 and about 20 gpt, or between about 2 and about 10 gpt, or between about 2 and about 5 gpt, or between about 5 and about 10 gpt. In some embodiments, the emulsion or microemulsion is present in an amount between about 1 and about 4 gpt.
  • the mud displacement fluid contains at least about 0.5 gpt, at least about 1 gpt, or at least about 2 gpt, or at least about 4 gpt, or at least about 10 gpt, or at least about 20 gpt, or at least about 50 gpt, or at least about 100 gpt, or at least about 200 gpt of an emulsion or a microemulsion.
  • the mud displacement fluid contains less than or equal to about 200 gpt, or less than or equal to about 100 gpt, or less than or equal to about 50 gpt, or less than or equal to about 20 gpt, or less than or equal to about 10 gpt, or less than or equal to about 4 gpt, or less than or equal to about 2 gpt, or less than or equal to about 1 gpt, or less than or equal to about 0.5 gpt of an emulsion or
  • cement is placed between the casing and the wellbore sides.
  • pieces of cement e.g., cement particles, ground cement, etc.
  • the reservoir material or fluid present in the wellbore e.g., gelling the mud such that the viscosity is significantly increased and rendering it generally unworkable
  • the viscosity of fluids injected into the wellbore and/or the viscosity of fluids recovered from the wellbore.
  • a portion of the cement (e.g., at the bottom of the well, also known as a cement plug) may be removed by drilling, thereby resulting in pieces of cement.
  • the pieces of cement may be removed via injection of a fluid (e.g., a cementing fluid) during and/or following the cementing process.
  • the cementing fluid comprises an emulsion or
  • microemulsion Emulsions and microemulsions are described in more detail herein.
  • the addition of an emulsion or microemulsion in the cementing fluid may have many advantages as compared to the use of a cementing fluid alone including, for example, reducing the viscosity of fluids containing cement particles.
  • the cementing fluid comprises an emulsion or
  • microemulsion as described herein wherein the emulsion or microemulsion is present in an amount between about 0.5 and about 200 gpt of cementing fluid, or between about 0.5 and about 50 gpt, or between about 0.5 and about 100 gpt, or between about 1 and about 50 gpt, or between about 1 and about 20 gpt, or between about 2 and about 20 gpt, or between about 2 and about 10 gpt, or between about 2 and about 5 gpt, or between about 5 and about 10 gpt.
  • the cementing fluid contains at least about 0.5 gpt, or at least about 1 gpt, or at least about 2 gpt, or at least about 4 gpt, or at least about 10 gpt, or at least about 20 gpt, or at least about 50 gpt, or at least about 100 gpt, or at least about 200 gpt, of an emulsion or a microemulsion.
  • the cementing fluid contains less than or equal to about 200 gpt, or less than or equal to about 100 gpt, or less than or equal to about 50 gpt, or less than or equal to about 20 gpt, or less than or equal to about 10 gpt, or less than or equal to about 4 gpt, or less than or equal to about 2 gpt, or less than or equal to about 1 gpt, or less than or equal to about 0.5 gpt of an emulsion or microemulsion. II-D. Perforating
  • perforating guns may be lowered into the wellbore to create holes between the interior of the casing and the surrounding reservoir material.
  • perforating guns utilize liquid jets (e.g., hydrocutters) or explosives (e.g., an expanding plume of gas) to send high velocity jets of fluid (e.g., a perforating fluid) between the gun and the casing to form holes of controlled size and depth into the casing, cement, and/or nearby reservoir material.
  • a perforating fluid e.g., a perforating fluid
  • the perforating fluid generally flows into the areas formed by the perforating gun.
  • the perforating fluid comprises an emulsion or
  • microemulsion Emulsions and microemulsions are described in more detail herein.
  • the addition of an emulsion or microemulsion in the perforating fluid may have many advantages as compared to the use of a perforating fluid alone, including, for example, preventing or minimizing damage from imbibition, preventing the formation of new filter cakes (e.g., that may reduce hydrocarbons in the reservoir material from entering the casing), and/or increasing the pressure differential between the wellbore and the surrounding reservoir material.
  • the perforating fluid comprises an emulsion or
  • microemulsion as described herein wherein the emulsion or microemulsion is present in an amount between about 0.5 and about 200 gpt of perforating fluid, or between about 0.5 and about 100 gpt, or between about 0.5 and about 50 gpt, or between about 1 and about 50 gpt, or between about 1 and about 20 gpt, or between about 2 and about 20 gpt, or between about 2 and about 10 gpt, or between about 2 and about 5 gpt, or between about 5 and about 10 gpt. In some embodiments, the emulsion or microemulsion is present in an amount between about 1 and about 10 gpt.
  • the perforating fluid contains at least about 0.5 gpt, or at least about 1 gpt, or at least about 2 gpt, or at least about 4 gpt, or at least about 10 gpt, or at least about 20 gpt, or at least about 50 gpt, or at least about 100 gpt, or at least about 200 gpt of an emulsion or a microemulsion.
  • the perforating fluid contains less than or equal to about 200 gpt, or less than or equal to about 100 gpt, or less than or equal to about 50 gpt, or less than or equal to about 20 gpt, or less than or equal to about 10 gpt, or less than or equal to about 4 gpt, or less than or equal to about 2 gpt, or less than or equal to about 1 gpt, or less than or equal to about 0.5 gpt of an emulsion or microemulsion.
  • stimulation generally refers to the treatment of geological formations to improve the recovery of liquid hydrocarbons (e.g., formation crude oil and/or formation gas).
  • liquid hydrocarbons e.g., formation crude oil and/or formation gas.
  • the porosity and permeability of the formation determine its ability to store hydrocarbons, and the facility with which the hydrocarbons can be extracted from the formation.
  • Common stimulation techniques include well fracturing (e.g., fracturing, hydraulic fracturing) and acidizing (e.g., fracture acidizing, matrix acidizing) operations.
  • Non-limiting examples of fracturing operations include hydraulic fracturing, which is commonly used to stimulate low permeability geological formations to improve the recovery of hydrocarbons.
  • the process can involve suspending chemical agents in a stimulation fluid (e.g., fracturing fluid) and injecting the fluid down a wellbore.
  • the fracturing fluid may be injected at high pressures and/or at high rates into a wellbore.
  • the assortment of chemicals pumped down the well can cause damage to the surrounding formation by entering the reservoir material and blocking pores.
  • one or more of the following may occur: wettability reversal, emulsion blockage, aqueous-filtrate blockage, mutual precipitation of soluble salts in wellbore- fluid filtrate and formation water, deposition of paraffins or asphaltenes, condensate banking, bacterial plugging, and/or gas breakout.
  • fluids may become trapped in the formation due to capillary end effects in and around the vicinity of the formation fractures.
  • the addition of an emulsion or microemulsion in the fracturing fluid may have many advantages as compared to the use of a fracturing fluid alone, including, for example, maximizing the transfer and/or recovery of injected fluids, increasing oil and/or gas recovery, and/or other benefits described herein.
  • Non-limiting examples of acidizing operations include the use of water-based fluids to remove drilling fluids and particles remaining in the wellbore to permit optimal flow feeding into the wellbore (e.g., matrix acidizing).
  • Matrix acidizing generally refers to the formation of wormholes (e.g., pores or channels through which oil, gas, and/or other fluids can flow) through the use of a fluid (e.g., acidic stimulation fluid)
  • an emulsion or microemulsion to the stimulation fluid may have many advantages as compared to the use of a stimulation fluid alone, including, for example, the formation of an acidic gel (e.g., which creates a more uniform distribution of acid across the reservoir materials as it travels along the surface), increasing oil and/or gas recovery, and/or other benefits described herein.
  • Fracture acidizing generally refers to the use of an acid to extend fractures formed by the injection of treatment fluid at high-pressure (e.g., fracturing).
  • the addition of an emulsion or microemulsion to the stimulation fluid may have advantages as compared to the use of a stimulation fluid alone, including, for example, increasing the removal of fracturing fluid skin (e.g., fluid and solids from the reservoir which may block optimal flow of the wellbore) from the fractures allowing for more effective acid treatment.
  • stimulation fluids e.g., acidizing fluids, fracturing fluids, etc.
  • stimulation fluids include water and hydrochloric acid (e.g., 15% HC1 in water).
  • the acid is partially or completely consumed after reacting with carbonates in the reservoir.
  • stimulation fluids include conventional fluids (e.g., gelling agents comprising crosslinking agents such as borate, zirconate, and/or titanate), water fracture fluids (e.g., friction reducers, gelling agents, viscoelastic surfactants), hybrid fluids (e.g., friction reducers, gelling agents, viscoelastic surfactants, and combinations thereof), energized fluids (e.g., foam generating energizers comprising nitrogen or carbon dioxide), acid fracture fluids (e.g., gelled acid base fluids), gas fracture fluids (e.g., propane), and matrix acidizing fluids (e.g., an acid).
  • conventional fluids e.g., gelling agents comprising crosslinking agents such as borate, zirconate, and/or titanate
  • water fracture fluids e.g., friction reducers, gelling agents, viscoelastic surfactants
  • hybrid fluids e.g., friction reducers, gelling agents, viscoel
  • the stimulation fluid comprises a viscosifier (e.g., guar gum) and/or a bridging agent (e.g., calcium carbonate, size salt, oil-soluble resins, mica, ground cellulose, nutshells, and other fibers).
  • a viscosifier e.g., guar gum
  • a bridging agent e.g., calcium carbonate, size salt, oil-soluble resins, mica, ground cellulose, nutshells, and other fibers.
  • removal of leftover drilling fluids or reservoir fluids refers to the breakdown and removal of a near-wellbore skin (e.g., fluid and solids from the reservoir which may block optimal flow into the wellbore).
  • skin materials include paraffin, asphaltene, drilling mud components (e.g., barite, clays), non-mobile oil in place, and fines (e.g., which may block pores in the reservoir material).
  • an emulsion or microemulsion to the acidizing fluid may have many advantages as compared to the use of a acidizing fluid alone, including, for example, increasing the breakdown of the skin into smaller components to be more easily removed by flow from the wellbore, increasing oil and/or gas recovery, and/or other benefits described herein.
  • incorporation of an emulsion or a microemulsion into a stimulation fluid can aid in reducing fluid trapping, for example, by reducing capillary pressure and/or minimizing capillary end effects, as compared to the use of a stimulation fluid alone.
  • incorporation of an emulsion or microemulsion into stimulation fluids can promote increased flow back of aqueous phases following well treatment, increasing production of liquid and/or gaseous hydrocarbons, and/or increasing the displacement of residual fluids (e.g., drilling fluids, etc.) by formation crude oil and/or formation gas.
  • non- limiting advantages as compared to the use of a stimulation fluid alone include increasing the amount of water extracted from the reservoir, increasing the amount or oil and/or gas extracted from the reservoir, more uniformly distributing the acid along the surface of the wellbore and/or reservoir, improving the formation of wormholes (e.g., by slowing down the reaction rate to create deeper and more extensive wormholes during fracture acidizing).
  • microemulsion increases the amount of hydrocarbons transferred from the reservoir to fluids injected into the reservoir during hydraulic fracturing.
  • the stimulation fluid comprises an emulsion or microemulsion as described herein wherein the emulsion or microemulsion is present in an amount between about 0.5 and about 200 gpt of stimulation fluid, or between about 0.5 and about 100 gpt, or between about 0.5 and about 50 gpt, or between about 1 and about 50 gpt, or between about 1 and about 20 gpt, or between about 2 and about 20 gpt, or between about 2 and about 10 gpt, or between about 2 and about 5 gpt, or between about 5 and about 10 gpt. In some embodiments, the emulsion or microemulsion is present in an amount between about 2 and about 5 gpt.
  • the stimulation fluid contains at least about 0.5 gpt, or at least about 1 gpt, or at least about 2 gpt, or at least about 4 gpt, or at least about 10 gpt, or at least about 20 gpt, or at least about 50 gpt, or at least about 100 gpt, or at least about 200 gpt, of an emulsion or a microemulsion.
  • the stimulation fluid contains less than or equal to about 200 gpt, or less than or equal to about 100 gpt, or less than or equal to about 50 gpt, or less than or equal to about 20 gpt, or less than or equal to about 10 gpt, or less than or equal to about 4 gpt, or less than or equal to about 2 gpt, or less than or equal to about 1 gpt, or less than or equal to about 0.5 gpt of an emulsion or microemulsion.
  • refracturing or the process of repeating the above stimulation processes, is further improved by the addition of an emulsion or
  • microemulsion to the stimulation fluid.
  • the emulsion or microemulsion for use with a stimulation fluid comprising a surfactant as in Formula I:
  • R is hydrogen or Ci_ 6 alkyl.
  • R 12 is H, methyl, or ethyl.
  • R is H.
  • the emulsion or microemulsion for use with a stimulation fluid comprising a surfactant as in Formula II:
  • X is a metal cation or N(R ) 4 , wherein each R 13 is independently selected from the group consisting of hydrogen, optionally substituted alkyl, or optionally substituted aryl.
  • X + is NH 4 .
  • Non-limiting examples of metal cations are Na + , K + , Mg +2 , and Ca +2 .
  • Y " is -O " , -S0 2 0 ⁇ , or -OS0 2 0 " .
  • the emulsion or microemulsion for use with a stimulation fluid comprising a surfactant as in Formula III:
  • Z is N(R ) 3 , wherein each R is independent selected from the group consisting of hydrogen, optionally substituted alkyl, or optionally substituted aryl. 7 8
  • Ar is phenyl.
  • each m is 1.
  • each m is 2.
  • n is 6-100, or 1-50, or 6-50, or 6-25, or 1-25, or 5-50, or 5-25, or 5-20.
  • an emulsion or microemulsion comprises a surfactant of Formula (I), (II), or (III) in an amount between about 1 wt% and about 20 wt%, or between about 3 wt% and about 15 wt%, or between about 5 wt% and about 13 wt%, or between about 5 wt% and about 11 wt%, or between about 7 wt% and about 11 wt%, or between about 10 wt% and about 12 wt%, or between about 8 wt% and about 12 wt%, or between about 8 wt% and about 10 wt%, or about 9 wt%.
  • a surfactant of Formula (I), (II), or (III) in an amount between about 1 wt% and about 20 wt%, or between about 3 wt% and about 15 wt%, or between about 5 wt% and about 13 wt%, or between about 5 wt% and about 11 wt%, or
  • the emulsion or microemulsion comprises, in addition to the surfactant of Formula (I), (II), or (III), water and a non-aqueous phase (e.g., a terpene), and optionally other additives (e.g., one or more additional surfactants, an alcohol, a freezing point depression agent, etc.).
  • the emulsion or microemulsion comprises, in addition to the surfactant of Formula (I), (II), or (III), water, a terpene, an alcohol, one or more additional surfactants, and optionally other additives (e.g., a freezing point depression agent).
  • the emulsion or microemulsion comprises, in addition to the surfactant of Formula (I), (II), or (III), between about 20 wt% and 90 wt% water, between about 2 wt% and about 70 wt% of one or more additional surfactants, between about 1 wt% and about 80 wt% of a solvent (e.g., terpene), and between about 10 wt% and about 40 wt% of a mutual solvent (e.g., alcohol).
  • a solvent e.g., terpene
  • a mutual solvent e.g., alcohol
  • the emulsion or microemulsion comprises, in addition to the surfactant of Formula (I), (II), or (III), between about 10 wt% and 80 wt% water, between about 2 wt% and about 80 wt% of one or more additional surfactants, between about 1 wt% and about 70 wt% of a solvent (e.g., terpene), and between about 5 wt% and about 40 wt% of a mutual solvent (e.g., alcohol).
  • a solvent e.g., terpene
  • a mutual solvent e.g., alcohol
  • the emulsion or microemulsion comprises, in addition to the surfactant of Formula (I), (II), or (III), between about 20 wt% and 90 wt% water, between about 2 wt% and about 70 wt% of one or more additional surfactants, between about 1 wt% and about 78 wt% of a solvent (e.g., terpene), and between about 22 wt% and about 40 wt% of a mutual solvent (e.g., alcohol).
  • a solvent e.g., terpene
  • a mutual solvent e.g., alcohol
  • Non-limiting examples of surfactants of Formula (I), (II), or (III) include styrylphenol ethoxylate, a tristyrylphenol ethoxylate, a styrylphenol propoxylate, a tristyrylphenol propoxylate, a styrylphenol ethoxylate propoxylate, or a tristyrylphenol ethoxylate propoxylate.
  • a fluid herein referred to as a kill fluid
  • a kill fluid comprises an emulsion or microemulsion.
  • Emulsions and microemulsions are described in more detail herein.
  • the addition of an emulsion or microemulsion in the kill fluid may have many advantages as compared to the use of a kill fluid alone including, for example, increasing the amount of kill fluid recovered and/or improving the ability for the well to return to the rate of production it exhibited prior to injection of the kill fluid.
  • the kill fluid comprises an emulsion or microemulsion as described herein wherein the emulsion or microemulsion is present in an amount between about 0.5 and about 200 gpt of kill fluid, or between about 0.5 and about 100 gpt, or between about 0.5 and about 50 gpt, or between about 1 and about 50 gpt, or between about 1 and about 20 gpt, or between about 2 and about 20 gpt, or between about 2 and about 10 gpt, or between about 2 and about 5 gpt, or between about 5 and about 10 gpt. In some embodiments, the emulsion or microemulsion is present in an amount between about 1 and about 10 gpt.
  • the kill fluid contains at least about 0.5 gpt, or at least about 1 gpt, or at least about 2 gpt, or at least about 4 gpt, or at least about 10 gpt, or at least about 20 gpt, or at least about 50 gpt, or at least about 100 gpt, or at least about 200 gpt, of an emulsion or a microemulsion.
  • the kill fluid contains less than or equal to about 200 gpt, or less than or equal to about 100 gpt, or less than or equal to about 50 gpt, or less than or equal to about 20 gpt, or less than or equal to about 10 gpt, or less than or equal to about 4 gpt, or less than or equal to about 2 gpt, or less than or equal to about 1 gpt, or less than or equal to about 0.5 gpt of an emulsion or microemulsion.
  • EOR enhanced oil recovery
  • IOR improved oil recovery
  • EOR/IOR typically uses a secondary or a tertiary system (e.g., comprising one or more of water, polymers, surfactants, etc.) to create a new mechanism which increases the displacement of oil and/or gas from the reservoir for recovery.
  • EOR/IOR uses an existing wellbore which has been converted into a recovering well (e.g., an injecting well).
  • the recovering well is used to inject the secondary or tertiary system into the reservoir at a continuous or noncontinuous rate and/or pressure to increase the amount of hydrocarbons extracted from the reservoir.
  • EOR/IOR procedures include water flooding, gas flooding, polymer flooding, and/or the use of surfactant polymers.
  • the EOR/IOR procedure may comprise an EOR/IOR fluid (e.g., a water flooding fluid, a polymer flooding fluid, a surfactant flooding fluid, a gas flooding fluid, a surfactant, or combinations thereof).
  • water flooding refers to the injection of a water flooding fluid into a reservoir to increase the amount of oil and/or gas recovered from the wellbore.
  • the water flooding fluid comprises one or more of water (e.g., water, makeup water, etc.), acidizing fluids (e.g., matrix acidizing fluids), surfactants, polymers, and foam.
  • the water flooding fluid comprises a polymer (e.g., a polymer flooding fluid), and/or a surfactant (i.e. during a surfactant flood), and/or a surfactant polymer flood (i.e.
  • the water flooding fluid comprises an emulsion or microemulsion. Emulsions and microemulsions are described in more detail herein. The addition of an emulsion or microemulsion to the water flooding fluid may have many advantages as compared to a water flooding fluid alone including increasing the adhesion of the polymer to oil, increasing interfacial efficiency of the polymer, increasing the amount of oil and/or gas extracted from the reservoir, decreasing the volume of water needed to extract the same amount of oil, and/or lowering the pressure necessary to extract hydrocarbons from the reservoir. In some embodiments, the addition of an emulsion or microemulsion to the water flooding fluid increases the recovery of fracturing fluids (e.g., fracturing fluids not previously removed).
  • fracturing fluids e.g., fracturing fluids not previously removed.
  • polymer gels are injected into the formation during secondary and tertiary recovery to block water and gas (carbon dioxide and nitrogen) flow from previously swept zones and large fractures (e.g., thief zones) or to prevent imbibition of water from a part of the formation that abuts the oil containing zone.
  • Use of polymers in these cases is commonly referred to as conformance control or water shut-off.
  • emulsions and microemulsions are injected into the formation as a pre flush to prepare the formation for the polymer gel injection.
  • an emulsion or microemulsion prior to the injection of a polymer gel may have many advantages as compared the injection of a polymer gel alone including enhancing the adhesion of the polymer to the formation (e.g., by removing surface contamination and residual oil).
  • gas flooding refers to the injection of a gas (e.g., carbon dioxide, nitrogen) into a reservoir to increase the amount of oil and/or gas recovered from the wellbore.
  • gas flooding comprises a gas flooding fluid (e.g., liquid carbon dioxide and/or liquid nitrogen).
  • the gas flooding fluid comprises an emulsion or microemulsion. The addition of an emulsion or a
  • microemulsion in the gas flooding fluid may have many advantages as compared to the use of a gas flooding fluid alone, including reducing the miscibility pressure as compared to gas flooding alone, and/or reducing the volume of liquid carbon dioxide or liquid nitrogen that expands into a gas during the gas flooding process.
  • a formulation e.g., a foam diverter, emulsion diverter, or matrix diverter
  • gas e.g., carbon dioxide, flu gas, methane, natural gas, or nitrogen
  • a foam diverter emulsion diverter, or matrix diverter
  • gas e.g., carbon dioxide, flu gas, methane, natural gas, or nitrogen
  • gas e.g., carbon dioxide or nitrogen
  • an emulsion and/or microemulsion is injected into the formation as a preflush to prepare the formation for the foam diverter injection.
  • an emulsion or microemulsion prior to the injection of the foam may have many advantages as compared the injection of the foam alone including enhancing the stability of the foam (e.g., by removing surface contamination and residual oil), or increasing the penetration of the foam into the formation (e.g., by controlling the adsorption of the diverter onto the rock surface).
  • the EOR/IOR fluid comprises an emulsion or
  • microemulsion as described herein wherein the emulsion or microemulsion is present in an amount between about 0.5 and about 200 gpt of EOR/IOR fluid, or between about 0.5 and about 100 gpt, or between about 0.5 and about 50 gpt, or between about 1 and about 50 gpt, or between about 1 and about 20 gpt, or between about 2 and about 20 gpt, or between about 2 and about 10 gpt, or between about 2 and about 5 gpt, or between about 5 and about 10 gpt. In some embodiments, the emulsion or microemulsion is present in an amount between about 1 and about 10 gpt.
  • the EOR/IOR fluid contains at least about 0.5 gpt, or at least about 1 gpt, or at least about 2 gpt, or at least about 4 gpt, or at least about 10 gpt, or at least about 20 gpt, or at least about 50 gpt, or at least about 100 gpt, or at least about 200 gpt of an emulsion or a microemulsion.
  • the EOR/IOR fluid contains less than or equal to about 200 gpt, or less than or equal to about 100 gpt, or less than or equal to about 50 gpt, or less than or equal to about 20 gpt, or less than or equal to about 10 gpt, or less than or equal to about 4 gpt, or less than or equal to about 2 gpt, or less than or equal to about 1 gpt, or less than or equal to about 0.5 gpt of an emulsion or microemulsion.
  • wellbores and/or reservoirs which are no longer used for oil and/or gas recovery may generally be used to store excess fluid (e.g., water, makeup water, salt water, brine, etc.) recovered from the reservoir.
  • excess fluid e.g., water, makeup water, salt water, brine, etc.
  • an emulsion or microemulsion is added to the stored fluid. The addition of an emulsion or microemulsion to the stored fluid may reduce corrosion of the wellbore.
  • the stored fluid comprises an emulsion or microemulsion as described herein wherein the emulsion or microemulsion is present in an amount between about 0.5 and about 200 gpt of stored fluid, or between about 0.5 and about 100 gpt, or between about 0.5 and about 50 gpt, or between about 1 and about 50 gpt, or between about 1 and about 20 gpt, or between about 2 and about 20 gpt, or between about 2 and about 10 gpt, or between about 2 and about 5 gpt, or between about 5 and about 10 gpt. In some embodiments, the emulsion or microemulsion is present in an amount between about 1 and about 10 gpt.
  • the stored fluid contains at least about 0.5 gpt, or at least about 1 gpt, or at least about 2 gpt, or at least about 4 gpt, or at least about 10 gpt, or at least about 20 gpt, or at least about 50 gpt, or at least about 100 gpt, or at least about 200 gpt of an emulsion or a microemulsion.
  • the stored fluid contains less than or equal to about 200 gpt, or less than or equal to about 100 gpt, or less than or equal to about 50 gpt, or less than or equal to about 20 gpt, or less than or equal to about 10 gpt, or less than or equal to about 4 gpt, or less than or equal to about 2 gpt, or less than or equal to about 1 gpt, or less than or equal to about 0.5 gpt of an emulsion or microemulsion.
  • stimulation fluids are used in onshore wells.
  • stimulation fluids are used in offshore wells and/or during fracture packing (e.g., gravel packing).
  • fracture packing e.g., gravel packing
  • stimulation fluids for use in offshore wells may comprise stable media (e.g., gravel) that may be injected into a wellbore to protect the integrity of the wellbore itself.
  • stimulation fluids for use in offshore wells are used in high rate water packing wherein stimulation fluids may be injected at higher rates (e.g., 400 barrels/min), at higher pressures, and/or at higher volumes as compared to an onshore well.
  • the addition of an emulsion or microemulsion in the stimulation fluid for use in offshore wells may have many advantages as compared to the use of a stimulation fluid alone, including, for example, minimizing the damaging effects of stimulation fiuids that come in contact with the reservoir, and/or increasing the amount of hydrocarbons extracted from the reservoir.
  • the stimulation fluid utilized in offshore wells or during fracture packing comprises an emulsion or microemulsion as described herein wherein the emulsion or microemulsion is present in an amount between about 0.5 and about 200 gpt of stimulation fluid for use in offshore wells or during fracture packing, or between about 0.5 and about 100 gpt, or between about 0.5 and about 50 gpt, or between about 1 and about 50 gpt, or between about 1 and about 20 gpt, or between about 2 and about 20 gpt, or between about 2 and about 10 gpt, or between about 5 and about 10 gpt. In some embodiments, the emulsion or microemulsion is present in an amount between about 2 and about 5 gpt.
  • the stimulation fluid for use in offshore wells or during fracture packing contains at least about 0.5 gpt, or at least about 1 gpt, or at least about 2 gpt, or at least about 4 gpt, or at least about 10 gpt, or at least about 20 gpt, or at least about 50 gpt, or at least about 100 gpt, or at least about 200 gpt of an emulsion or a microemulsion.
  • the stimulation fluid for use in offshore wells or during fracture packing contains less than or equal to about 200 gpt, or less than or equal to about 100 gpt, or less than or equal to about 50 gpt, or less than or equal to about 20 gpt, or less than or equal to about 10 gpt, or less than or equal to about 4 gpt, or less than or equal to about 2 gpt, or less than or equal to about 1 gpt, or less than or equal to about 0.5 gpt of an emulsion or microemulsion.
  • Certain compounds of the present invention may exist in particular geometric or stereoisomeric forms.
  • the present invention contemplates all such compounds, including cis- and trans-isomers, R- and iS-enantiomers, diastereomers, (D)-isomers, (L)-isomers, the racemic mixtures thereof, and other mixtures thereof, as falling within the scope of the invention.
  • Additional asymmetric carbon atoms may be present in a substituent such as an alkyl group. All such isomers, as well as mixtures thereof, are intended to be included in this invention.
  • Isomeric mixtures containing any of a variety of isomer ratios may be utilized in accordance with the present invention. For example, where only two isomers are combined, mixtures containing 50:50, 60:40, 70:30, 80:20, 90: 10, 95 :5, 96:4, 97:3, 98:2, 99: 1 , or 100:0 isomer ratios are all contemplated by the present invention. Those of ordinary skill in the art will readily appreciate that analogous ratios are contemplated for more complex isomer mixtures.
  • aliphatic includes both saturated and unsaturated, nonaromatic, straight chain (i.e. unbranched), branched, acyclic, and cyclic (i.e.
  • carbocyclic hydrocarbons which are optionally substituted with one or more functional groups.
  • aliphatic is intended herein to include, but is not limited to, alkyl, alkenyl, alkynyl, cycloalkyl, cycloalkenyl, and cycloalkynyl moieties.
  • alkyl includes straight, branched and cyclic alkyl groups.
  • alkyl alkenyl
  • alkynyl alkynyl
  • aliphatic is used to indicate those aliphatic groups (cyclic, acyclic, substituted, unsubstituted, branched or unbranched) having 1-20 carbon atoms.
  • Aliphatic group substituents include, but are not limited to, any of the substituents described herein, that result in the formation of a stable moiety (e.g.
  • alkane is given its ordinary meaning in the art and refers to a saturated hydrocarbon molecule.
  • branched alkane refers to an alkane that includes one or more branches, while the term “unbranched alkane” refers to an alkane that is straight-chained.
  • cyclic alkane refers to an alkane that includes one or more ring structures, and may be optionally branched.
  • acyclic alkane refers to an alkane that does not include any ring structures, and may be optionally branched.
  • alkene is given its ordinary meaning in the art and refers to an unsaturated hydrocarbon molecule that includes one or more carbon-carbon double bonds.
  • branched alkene refers to an alkene that includes one or more branches, while the term “unbranched alkene” refers to an alkene that is straight-chained.
  • cyclic alkene refers to an alkene that includes one or more ring structures, and may be optionally branched.
  • acyclic alkene refers to an alkene that does not include any ring structures, and may be optionally branched.
  • aromatic is given its ordinary meaning in the art and refers to aromatic carbocyclic groups, having a single ring (e.g., phenyl), multiple rings (e.g., biphenyl), or multiple fused rings in which at least one is aromatic (e.g., 1,2,3,4- tetrahydronaphthyl, naphthyl, anthryl, or phenanthryl). That is, at least one ring may have a conjugated pi electron system, while other, adjoining rings can be cycloalkyls, cycloalkenyls, cycloalkynyls, aryls and/or heterocyclyls.
  • aryl is given its ordinary meaning in the art and refers to aromatic carbocyclic groups, optionally substituted, having a single ring (e.g., phenyl), multiple rings (e.g., biphenyl), or multiple fused rings in which at least one is aromatic (e.g., 1,2,3,4-tetrahydronaphthyl, naphthyl, anthryl, or phenanthryl). That is, at least one ring may have a conjugated pi electron system, while other, adjoining rings can be
  • aryl group may be optionally substituted, as described herein.
  • Substituents include, but are not limited to, any of the previously mentioned substitutents, i.e., the substituents recited for aliphatic moieties, or for other moieties as disclosed herein, resulting in the formation of a stable compound.
  • an aryl group is a stable mono- or polycyclic unsaturated moiety having preferably 3-14 carbon atoms, each of which may be substituted or unsubstituted.
  • amine is given its ordinary meaning in the art and refers to a primary (-NH 2 ), secondary (-NHR X ), tertiary (-NR x R y ), or quaternary (-N+R x R y R z ) amine (e.g., where R x , R y , and R z are independently an aliphatic, alicyclic, alkyl, aryl, or other moieties, as defined herein).
  • amide is given its ordinary meaning in the art and refers to a compound containing a nitrogen atom and a carbonyl group of the structure R x CONR y R z (e.g., where R x , R y , and R z are independently an aliphatic, alicyclic, alkyl, aryl, or other moieties, as defined herein).
  • This example describes a non-limiting experiment for determining displacement of residual aqueous treatment fluid by formation crude oil.
  • a 25 cm long, 2.5 cm diameter capped glass chromatography column was packed with 77 grams of 100 mesh sand or a mixture of 70/140 mesh shale and 100 mesh sand or a mixture of 70/140 mesh shale and 100 mesh sand.
  • the column was left open on one end and a PTFE insert containing a recessed bottom, 3.2 mm diameter outlet, and nipple was placed into the other end.
  • a 3 cm diameter filter paper disc (Whatman, #40) was pressed firmly into the recessed bottom of the insert to prevent leakage of 100 mesh sand.
  • a 2 inch piece of vinyl tubing was placed onto the nipple of the insert and a clamp was fixed in place on the tubing prior to packing.
  • the columns were gravity-packed by pouring approximately 25 grams of the diluted microemulsions (e.g., the microemulsions described in Examples 1 or 2, and diluted with 2% KC1, e.g., to about 2 gpt, or about 1 gpt) into the column followed by a slow, continuous addition of sand. After the last portion of sand had been added and was allowed to settle, the excess of brine was removed from the column so that the level of liquid exactly matched the level of sand.
  • the diluted microemulsions e.g., the microemulsions described in Examples 1 or 2
  • 2% KC1 e.g., 2% KC1
  • Pore volume in the packed column was calculated as the difference in mass of fluid prior to column packing and after the column had been packed. Three additional pore volumes of brine were passed through the column. After the last pore volume was passed, the level of brine was adjusted exactly to the level of sand bed. Light condensate oil was then added on the top of sand bed to form the 5 cm oil column above the bed. Additional oil was placed into a separatory funnel with a side arm open to an
  • This example describes a non-limiting experiment for determining displacement of residual aqueous treatment fluid by formation gas.
  • a 51 cm long, 2.5 cm inner diameter capped glass chromatography column was filled with approximately 410 ⁇ 20 g of 20/40 mesh Ottawa sand and the diluted microemulsions. To ensure uniform packing, small amounts of proppant were interchanged with small volumes of liquid. Periodically the mixture in the column was homogenized with the help of an electrical hand massager, in order to remove possible air pockets. Sand and brine were added to completely fill the column to the level of the upper cap. The exact amounts of fluid and sand placed in the column were determined in each experiment.
  • the column was oriented vertically and was connected at the bottom to a nitrogen cylinder via a gas flow controller pre-set at a flow rate of 60 cm3/min.
  • the valve at the bottom was slowly opened and liquid exiting the column at the top was collected into a tarred jar placed on a balance. Mass of collected fluid was recorded as a function of time by a computer running a data logging software. The experiments were conducted until no more brine could be displaced from the column. The total % of fluid recovered was then calculated.
  • This example describes a general preparation method for the production of diluted microemulsion.
  • the microemulsions were prepared in the laboratory by mixing the ingredients listed in specific examples. All ingredients are commercially available materials. In some embodiments, the components were mixed together in the order water-alcohol-surfactant- citrus terpene solvent, but other order of addition may also be employed. The mixtures were then agitated on a magnetic stirrer for 5 10 minutes. The microemulsions were then diluted to concentrations of 1 or 2 gallons per 1000 gallons with 2% KCl brine and these diluted fluids were used in displacement experiments (e.g., as described in Examples 1 and 2).
  • microemulsions were prepared according to the method described in Example 3 and comprising the components described in Table 2.
  • the microemulsions comprises a styrylphenol ethoxylate surfactant, water, other surfactants, co-solvents, and a solvent (e.g., hydrocarbon).
  • a solvent e.g., hydrocarbon
  • a reference to "A and/or B,” when used in conjunction with open-ended language such as “comprising” can refer, in one embodiment, to A without B (optionally including elements other than B); in another embodiment, to B without A (optionally including elements other than A); in yet another embodiment, to both A and B (optionally including other elements); etc.
  • the phrase "at least one,” in reference to a list of one or more elements, should be understood to mean at least one element selected from any one or more of the elements in the list of elements, but not necessarily including at least one of each and every element specifically listed within the list of elements and not excluding any combinations of elements in the list of elements.
  • This definition also allows that elements may optionally be present other than the elements specifically identified within the list of elements to which the phrase "at least one" refers, whether related or unrelated to those elements specifically identified.
  • At least one of A and B can refer, in one embodiment, to at least one, optionally including more than one, A, with no B present (and optionally including elements other than B); in another embodiment, to at least one, optionally including more than one, B, with no A present (and optionally including elements other than A); in yet another embodiment, to at least one, optionally including more than one, A, and at least one, optionally including more than one, B (and optionally including other elements); etc.

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Abstract

L'invention concerne des procédés et compositions comprenant une émulsion ou une microémulsion pour divers aspects du cycle de vie d'un puits de pétrole et/ou de gaz. Dans certains modes de réalisation, l'émulsion ou la microémulsion comprend de l'eau, un solvant et un tensio-actif, et facultativement, un ou plusieurs additifs.
PCT/US2014/029079 2013-03-14 2014-03-14 Procédés et compositions en vue d'une utilisation dans des puits de pétrole et/ou de gaz WO2014153102A1 (fr)

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EP14768919.4A EP2970753A4 (fr) 2013-03-14 2014-03-14 Procédés et compositions en vue d'une utilisation dans des puits de pétrole et/ou de gaz
CA2906165A CA2906165C (fr) 2013-03-14 2014-03-14 Procedes et compositions en vue d'une utilisation dans des puits de petrole et/ou de gaz
AU2014236272A AU2014236272B2 (en) 2013-03-14 2014-03-14 Methods and compositions for use in oil and/or gas wells
CN201480026902.0A CN105492572A (zh) 2013-03-14 2014-03-14 用于油井和/或气井的方法和组合物
AU2018201361A AU2018201361B2 (en) 2013-03-14 2018-02-26 Methods and compositions for use in oil and/or gas wells

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US13/829,434 2013-03-14
US13/829,495 2013-03-14
US13/829,434 US9068108B2 (en) 2013-03-14 2013-03-14 Methods and compositions for stimulating the production of hydrocarbons from subterranean formations
US13/829,495 US9428683B2 (en) 2013-03-14 2013-03-14 Methods and compositions for stimulating the production of hydrocarbons from subterranean formations
US13/918,166 2013-06-14
US13/918,155 2013-06-14
US13/918,166 US20140371115A1 (en) 2013-06-14 2013-06-14 Methods and compositions for stimulating the production of hydrocarbons from subterranean formations
US13/918,155 US9321955B2 (en) 2013-06-14 2013-06-14 Methods and compositions for stimulating the production of hydrocarbons from subterranean formations
US201461946176P 2014-02-28 2014-02-28
US61/946,176 2014-02-28

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WO2017099225A1 (fr) * 2015-12-10 2017-06-15 株式会社クレハ Réducteur de viscosité de pétrole lourd, procédé d'abaissement de la viscosité de pétrole lourd, et procédé de récupération de pétrole lourd
US10377942B2 (en) 2017-04-06 2019-08-13 Nissan Chemical America Corporation Hydrocarbon formation treatment micellar solutions
US10563117B2 (en) 2017-09-13 2020-02-18 Nissan Chemical America Corporation Crude oil recovery chemical fluids
US10801310B2 (en) 2017-09-26 2020-10-13 Nissan Chemcial America Corporation Using gases and hydrocarbon recovery fluids containing nanoparticles to enhance hydrocarbon recovery
US10870794B2 (en) 2017-11-03 2020-12-22 Nissan Chemical America Corporation Using brine resistant silicon dioxide nanoparticle dispersions to improve oil recovery
US10934478B2 (en) 2018-11-02 2021-03-02 Nissan Chemical America Corporation Enhanced oil recovery using treatment fluids comprising colloidal silica with a proppant
WO2021230890A1 (fr) * 2020-05-13 2021-11-18 Saudi Arabian Oil Company Amélioration des propriétés rhéologiques d'une mousse à l'aide d'un épaississant soluble dans l'eau
CN114381282A (zh) * 2021-12-17 2022-04-22 中国石油大学(华东) 表面活性剂及其制备方法、微乳液封堵剂及其制备方法和水基钻井液
CN115288647A (zh) * 2022-07-22 2022-11-04 捷贝通石油技术集团股份有限公司 一种用于提高油井采收率的复合扩容方法

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CN107033867B (zh) * 2017-04-12 2020-09-08 西安石油大学 纳米纤维素与粘弹性表面活性剂复合压裂液及其制备方法及其应用
CN112302588A (zh) * 2019-07-15 2021-02-02 中国石油化工股份有限公司 采用咪唑啉化合物降低co2驱最小混相压力的方法
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Cited By (18)

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Publication number Priority date Publication date Assignee Title
WO2016137455A1 (fr) * 2015-02-25 2016-09-01 Halliburton Energy Services, Inc. Gonflement in situ de polymères de fond de trou gonflables dans l'eau
WO2017099225A1 (fr) * 2015-12-10 2017-06-15 株式会社クレハ Réducteur de viscosité de pétrole lourd, procédé d'abaissement de la viscosité de pétrole lourd, et procédé de récupération de pétrole lourd
US10975289B2 (en) 2017-04-06 2021-04-13 Nissan Chemical America Corporation Hydrocarbon formation treatment micellar solutions
US10377942B2 (en) 2017-04-06 2019-08-13 Nissan Chemical America Corporation Hydrocarbon formation treatment micellar solutions
US10557078B2 (en) 2017-04-06 2020-02-11 Nissan Chemical America Corporation Brine resistant silica sol
US11401454B2 (en) 2017-04-06 2022-08-02 Nissan Chemical America Corporation Hydrocarbon formation treatment micellar solutions
US10563117B2 (en) 2017-09-13 2020-02-18 Nissan Chemical America Corporation Crude oil recovery chemical fluids
US10570331B2 (en) 2017-09-13 2020-02-25 Nissan Chemical America Corporation Crude oil recovery chemical fluid
US10801310B2 (en) 2017-09-26 2020-10-13 Nissan Chemcial America Corporation Using gases and hydrocarbon recovery fluids containing nanoparticles to enhance hydrocarbon recovery
US11274244B2 (en) 2017-11-03 2022-03-15 Nissan Chemical America Corporation Using brine resistant silicon dioxide nanoparticle dispersions to improve oil recovery
US11180692B2 (en) 2017-11-03 2021-11-23 Nissan Chemical America Corporation Using brine resistant silicon dioxide nanoparticle dispersions to improve oil recovery
US10870794B2 (en) 2017-11-03 2020-12-22 Nissan Chemical America Corporation Using brine resistant silicon dioxide nanoparticle dispersions to improve oil recovery
US10934478B2 (en) 2018-11-02 2021-03-02 Nissan Chemical America Corporation Enhanced oil recovery using treatment fluids comprising colloidal silica with a proppant
WO2021230890A1 (fr) * 2020-05-13 2021-11-18 Saudi Arabian Oil Company Amélioration des propriétés rhéologiques d'une mousse à l'aide d'un épaississant soluble dans l'eau
CN114381282A (zh) * 2021-12-17 2022-04-22 中国石油大学(华东) 表面活性剂及其制备方法、微乳液封堵剂及其制备方法和水基钻井液
CN114381282B (zh) * 2021-12-17 2024-05-28 中国石油大学(华东) 表面活性剂及其制备方法、微乳液封堵剂及其制备方法和水基钻井液
CN115288647A (zh) * 2022-07-22 2022-11-04 捷贝通石油技术集团股份有限公司 一种用于提高油井采收率的复合扩容方法
CN115288647B (zh) * 2022-07-22 2023-05-19 捷贝通石油技术集团股份有限公司 一种用于提高油井采收率的复合扩容方法

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CA3038464A1 (fr) 2014-09-25
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CA2906165A1 (fr) 2014-09-25

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