The term “produced water” refers to a water source that is present within and/or flows from a subterranean formation; produced water includes connate unless otherwise specified.

The “scope” of the present invention is defined by the appended claims, along with the full scope of equivalents to which such claims are entitled. The scope of the invention is further qualified as including any possible modification to any of the aspects and/or embodiments disclosed herein which would result in other embodiments, combinations, subcombinations, or the like that would be obvious to those skilled in the art.

The term “substantially” refers to a great or significant extent. “Substantially” can thus refer to a plurality, majority, and/or a supermajority of said quantifiable variable, given proper context.

As used herein, the term “substantially free” refers to compositions completely lacking the component or having such a small amount of the component that the component does not affect the performance of the composition. The component may be present as an impurity or as a contaminant and shall be less than 0.5 wt-%. In another embodiment, the amount of the component is less than 0.1 wt-% and in yet another embodiment, the amount of component is less than 0.01 wt-%.

As used herein, the term “surfactant” means a compound having at least one hydrophilic portion and at least one hydrophobic portion, wherein the compound is capable of spontaneous self-aggregation in aqueous compositions. Surfactants can also be referred to as “surface active agents” as they change the properties of a liquid at a surface when added to a liquid. Cationic surfactants have no anionic moieties covalently bonded to the molecule and one or more cationic moieties covalently bonded to the molecule. Anionic surfactants have no cationic moieties covalently bonded to the molecule and one or more anionic moieties covalently bonded to the molecule. Nonionic surfactants refer to those having no ionic moieties covalently bonded to the molecule. Amphoteric surfactants refer to those having one or more anionic moieties covalently bonded to the molecule and one or more cationic moieties covalently bonded to the molecule, and a net molecular charge of zero as they are electrically neutral compounds having formal unit electrical charges of opposite sign.

As used herein, the word “treatment” refers to any treatment for changing a condition of a wellbore or a subterranean formation. Examples of treatments include fluid-loss control, isolation, stimulation, or conformance control; however, the word “treatment” does not necessarily imply any particular treatment purpose.

As used herein, the term “water source” means a source of water comprising, consisting essentially of, or consisting of fresh water, tap water, well water, deionized water, distilled water, produced water, municipal water, waste water such as runoff water, “gray” water, or municipal waste water, treated or partially treated waste water, brackish water, or sea water, or a combination of two or more such water sources as determined by context. In some embodiments, a water source includes one or more salts, ions, buffers, acids, bases, surfactants, or other dissolved, dispersed, or emulsified compounds, materials, components, or combinations thereof. In some embodiments, a water source includes about 0 wt % to 35 wt % total dissolved solids. In some such embodiments, the total dissolved solids are substantially non-polymeric solids. In some such embodiments, the dissolved solids comprise, consist essentially of ionic compounds. Generally, the term “water source” includes all of the following unless otherwise specified or determined by context: water, connate, produced water, water having high total dissolved solids, water having high temperature, and water having both high total dissolved solids and high temperature. The terms “water based”, “water solution”, “aqueous” and the like generally refer to a composition including a water source

The term “weight percent,” “wt-%,” “percent by weight,” “% by weight,” and variations thereof, as used herein, refer to the concentration of a substance as the weight of that substance divided by the total weight of the composition and multiplied by 100. It is understood that, as used here, “percent,” “%,” and the like are intended to be synonymous with “weight percent,” “wt-%,” etc.

As used herein, the term “well” refers to a fluid connection between a hydrocarbon within a subterranean formation, and a point proximal to the surface of the earth suitably situated to collect at least a portion of the hydrocarbon. Optionally, the point of collection is further adapted to collect the hydrocarbon, or to inject an injectate into the subterranean formation, or both. Similarly, the term “wellbore” refers to a man-made fluid connection to a hydrocarbon within a subterranean formation. A wellbore is adapted to collect the hydrocarbon, or to inject an injectate into the subterranean formation, or both, for example by including one or more pipes, tanks, pumps and the like. A well may include one wellbore, or two or more wellbores.

Compositions

The gas lift flow improving compositions comprise a functionalized nanoparticle and at least one foaming surfactant comprising an amphoteric, anionic and/or nonionic surfactant, wherein the composition is dispersed in an aqueous medium. The compositions can be provided as concentrates, injectates, fracturing fluids, and/or the like.

Functionalized Nanoparticles

As referred to herein, the functionalized nanoparticles are surface modified nanoparticles. The functionalized nanoparticles provide improved stable nanoparticles suitable for synergistic combination with surfactants to improve gas lift flow in the various applications of use described herein. The gas lift flow is understood to refer to a lowering of the fluid density to improve gas lift flow which increases production in the subterranean formation or well.

Nanoparticles are particles that have at least one dimension less than about 1000 nm. The nanoparticles selected for amine functionalization for improved thermal and brine stability have at least one dimension ranging from about 1-1000 nm. In some embodiments, the nanoparticles range from 1-500 nm; 1-400 nm; 1-250 nm; 1-100 nm; 1-50 nm; 200-500 nm; 200-400 nm; or 300-400 nm. In some embodiments a nanoparticle can have one of its dimensions larger than 1000 nm while another dimension is less than about 1000 nm and therefore it is considered a nanoparticle. In some embodiments, the size of a nanoparticle refers to the diameter or approximate diameter of a nanoparticle. For a population of nanoparticles, this can also be referred to as a Z-average particle size, which can be measured according to routine protocols known to one skilled in the art. In some embodiments, the size is measured by dynamic light scattering (DLS) (Z-average). In some embodiments, the size is measured by Transmission Electron Microscopy (TEM).

In some embodiments the nanoparticles selected for functionalization and use in the gas lift flow improving compositions have an average particle size that is from about 1-1000 nm. In some embodiments, the nanoparticles average particle size range from 1-500 nm; 1-400 nm; 1-250 nm; 1-100 nm; 1-50 nm; 200-500 nm; 200-400 nm; or 300-400 nm.

The nanoparticles can assume a variety of geometries, such as spheres, hollow shells, rods, plates, ribbons, prisms, stars, and combinations thereof. All geometries of nanoparticles can be employed as described herein.

Various nanoparticles can be modified to be functionalized, including silica and metal-based nanoparticles. Silica nanoparticles include nanosilica, silicate nanoparticles, polyhedral oligomeric silsesquioxane (POSS) nanoparticles, colloidal silica, silicon dioxide nanoparticle dispersion (SDND), etc. Metal based nanoparticles include, for example, aluminum, chromium, cobalt, copper, gold, iron, magnesium, nickel, platinum, silver, tin, titanium, zinc, and zirconium nanoparticles. In embodiments, the metal-based nanoparticles are transition metals. The nanoparticles described herein can also include mineral oxide nanoparticles. For example, the nanoparticles are aluminum oxide, antimony dioxide, copper oxide, iron oxide, magnesium oxide, nickel oxide, silicon dioxide, titanium oxide, zinc oxide, or zirconium dioxide nanoparticles.

In some embodiments, the nanoparticles are selected from are Al₂O₃, Al(OH)₃, Bi₂O₃, CeO₂, CoO, Co₂O₃, CO₃O₄, Cr₂a₃, CuO, Cu₂O, Cu(OH)₂, Fe₂O₃, Fe₃O₄, MgO, Mg(OH)₂, MgCO₃, MnO₂, Mn₃O₄, Ni(OH)₂, NiO, SiO₂, SnO₂, TiO₂, ZnO, ZnCO₃, ZrO₂, and Zr(OH)₄. In some embodiments, any of the nanoparticles described herein are selected from the group consisting of BaCO₃, BaTiO₃, BaSO₄, CoFc₂O₄, CaCO₃, MnFc₂O₄, MgCO₃, ZnCO₃, SrCO₃, and SrTiO₃.

In embodiments where non-silica nanoparticles are employed, they can be treated or prepared to have a surface layer of silica for further surface modification (hereinafter referred to as silica surface-modified nanoparticles). In some embodiments, the nanoparticles are silica nanoparticles or alumina nanoparticles. In further embodiments, the nanoparticles are colloidal silica nanoparticles or colloidal alumina nanoparticles. In exemplary embodiments, the silica nanoparticles are silicon dioxide nanoparticles or colloidal silicon dioxide nanoparticles.

In embodiments, the nanoparticles do not include ceramics, which are convention for use in improving tensile strength properties. Without being limited to a particular mechanism of action or intended use, the size of ceramics exceed that of desired nanoparticles and prevent further challenges in its ability to stabilize in aqueous system. In further embodiments, the nanoparticles for amine functionalization do not include carbon nanoparticles which require distinct surface modification from those described herein. The nanoparticles do not include carbon or carbon-based materials, such as carbon nanotubes (e.g., single-walled carbon nanotubes (SWCNTs), multi-walled carbon nanotubes (MWCNTs), and combinations thereof), carbon nanodiamonds, graphite, graphene, graphene oxide, fullerenes, and combinations thereof.

Several methods are known for attaching functional groups (e.g. silica) to the nanoparticles to provide surface-modified nanoparticles such as silica. See, e.g., Ralph K. Iler, The Chemistry of Silica: Solubility, Polymerization, Colloid and Surface Properties, and Biochemistry, Wiley-Interscience, NY, 1979; VanDerVoort, P. and Vansant, E. F., Journal of Liquid Chromatography and Related Technologies, 19:2723-2752, 1996; or Energy & Fuels 2017, 31, 2663-2668; Soft Matter, 2016, 12, 2025-2039; SPE-179576-MS presented at the SPE Improved Oil Recovery Conference, 11-13 Apr. 2016; SPE-186328-MS presented at the SPE/ATMI Asia Pacific Oil & Gas Conference and Exhibition, 17-19 Oct. 2017; Energy & Fuels 2018, 32, 287-293.

The chemical group can itself be the functional group, or it can serve as a substrate to which other functional groups can be coupled. Therefore, in some embodiments, the morphology for nanoparticles is a “core-shell” morphology, where a core comprises material other than silica and the shell comprises silica.

In some embodiments the silica nanoparticles are surface treated with silane surface-coupling agents. In some embodiments, the nanoparticle surfaces are modified with surface-coupling agents derived from organic silane surface groups. The surface-coupling agent is selected from silane, aryl silane, alkoxysilane, alkyl, and combinations thereof. In some embodiments, the silane surface-coupling agents have epoxy groups. In some embodiments the silane coupling agents are 3-glycidoxypropyltrimethoxysilane, 3-glycidoxypropyltriethoxysilane, 3-glycidoxypropylmethyldimethoxysilane, 3-glycidoxypropylmethyldiethoxysilane, 3-glycidoxypropyltriethoxysilane, 2-(3,4-epoxycyclohexyl) propyltrimethoxysilane, 2-(3,4-epoxycyclohexyl)propyltriethoxysilane, 2-(3,4-epoxycyclohexyl)ethyltrimethoxysilane, 2-(3,4-epoxycyclohexyl)ethyltriethoxysilane, 2-(3,4-epoxycyclohexyl)methyltrimethoxysilane, 2-(3,4-epoxycyclohexyl)methyltriethoxysilane, [(3-ethyl-3-oxethanyl) methoxy]propyltrimethoxysilane, and [(3-ethyl-3-oxethanyl) methoxy]propyltriethoxysilane.

In some embodiments, the ratio of the surface modification compound to the nanoparticle (e.g. colloidal nanoparticles) is 0.1 to 15; 0.1:10; or 0.1:5 based on the mass of silica solid content. In some embodiments, the ratio of silane compound to the silica (e.g. colloidal silica) is 0.01 to 15; 0.1 to 15; 0.1:10; 0.1:5; or 0.01 to 5 based on the mass of silica solid content.

In some embodiments, the surface-modified nanosilica particles are used for producing zwitterionic groups as a reaction of a silane molecule with a silica surface. In some embodiments the silane is a zwitterionic silane. In some embodiments a zwitterionic silane is zwitterionic sulfonate functional silane, zwitterionic carboxylate functional silane, zwitterionic phosphate functional silane, zwitterionic phosphonic acid functional silane. In some embodiments a zwitterionic silane is N,N-dimethyl,N-(2-ethyl phosphate ethyl)-aminopropyltri-methyoxysilane (DMPAMS) or 3-(dimethyl (3-(trimethoxysilyl) propyl)-ammonio) propane-1-sulfonate or 3-(dimethyl (3-(triethoxysilyl) propyl)-ammonio) propane-1-sulfonate; or 3-(diethyl (3-(trimethoxysilyl) propyl)-ammonio) propane-1-sulfonate.

Additional description of exemplary functionalized, i.e. surface-modified, nanoparticles is described in U.S. Patent Publication No. 2023/0037819, which is incorporated herein in its entirety.

In embodiments the functionalized nanoparticle can further be an amine functionalized nanoparticle. In exemplary embodiments the nanoparticles have a core-shell nanoparticle morphology. The nanoparticle has as amine functionalized group covalently bonded to a trialkoxyorganosilane coated nanoparticle. In particular the trialkoxyorganosilane is covalently bonded to the amine-functionalized silanes. The covalent bonding between the core-shell structure of the nanoparticle is distinct from various types of functionalized or modified nanoparticles that do not have covalently bonded functional groups and instead rely on sol-gel formulations which can easily be converted to different structures (i.e., gel by cooling and sol by heating). Often the sol-gel structures are used for combining with nanoparticles, e.g., in composites, as opposed to providing a stabilized nanoparticle for dispersion in an aqueous medium.

As referred to herein, the core-shell nanoparticle morphology refers to a trialkoxyorganosilane coated nanoparticle as the core and the shell comprising an amine functionalized group provided by an amine-containing silane on the surface of the nanoparticle. The core is the nanoparticle that is first functionalized with a covalently bonded trialkoxyorganosilane to provide a functional group on the surface of the coated nanoparticle for further functionalization. The second step adds the amine functionalized silane.

An exemplary trialkoxyorganosilane suitable for coating the nanoparticle for the core of the amine functionalized nanoparticle includes 3-glycidyloxypropyl) trimethoxysilane (also referred to as glymo silane). Additional trialkoxyorganosilanes can include epoxy functional silanes, hydroxylic hydrophilic silane, hydroxyl functional silanes, and thiol functional silanes. Exemplary epoxy functional silanes that can be used as the trialkoxyorganosilane suitable for coating the nanoparticle, include for example (3-glycidyloxypropyl)triethoxysilane (CAS 2602-34-8), 5,6-epoxyhexyltriethoxysilane (CAS 86138-01-4), 2-(3,4-epoxycyclohexyl)ethyltriethoxysilane (CAS 10217-34-2), and 2-(3,4-epoxycyclohexyl)ethyltrimethoxysilane (CAS 338-04-3). Exemplary hydroxylic hydrophilic silanes that can be used as the trialkoxyorganosilane suitable for coating the nanoparticle, include for example hydroxymethyltriethoxysilane (CAS 162781-73-9), 3-[bis(2-hydroxyethyl)amino]propyl-triethoxysilane (CAS 7538-44-5), [hydroxy (polyethyleneoxy)propyl]triethoxysilane, and N-(3-triethoxysilylpropyl)gluconamide (CAS 104275-58-3). Exemplary hydroxyl functional silanes that can be used as the trialkoxyorganosilane suitable for coating the nanoparticle, include for example hydroxymethyltriethoxysilane (CAS 162781-73-9), N(-hydroxyethyl)-N-methylaminopropyltrimethoxysilane (CAS 330457-46-0), and N-(3-triethoxysilylpropyl) gluconamide (CAS 104275-58-3). The hydroxyl functional silanes can include 1 or more hydroxyl groups. Exemplary thiol functional silanes that can be used as the trialkoxyorganosilane suitable for coating the nanoparticle, include for example 3-mercaptopropyltrimethoxysilane (CAS 4420-74-0), 3-mercaptopropyltriethoxysilane (CAS 14814-09-6), 11-mercaptoundecyltrimethoxysilane (CAS 877593-17-4), (mercaptomethyl)methyldiethoxysilane (CAS 55161-63-2), 3-mercaptopropylmethyldimethoxysilane (CAS 31001-77-1), etc.

Suitable amine-functionalized silanes for providing the amine functionalized group on the surface of the nanoparticle include the formula I as shown:

[Image Omitted]

- wherein:
- R¹, R², and R³are independently -OMCH₃, —OH, —CH₃, or —Cl and wherein M is absent, (CH₂)_m—, or —(CH₂Y)_n—, wherein m is an integer from 1 to 5, n is an integer from 1 to 5, wherein Y is O, N, or S; and
- R⁴is —CH₂, or a substituted or an unsubstituted, linear or branched C2-C20 alkyl group, or —(Ar)—.

Additional suitable amine-functionalized silanes for providing the amine functionalized group on the surface of the nanoparticle include the formula II as shown

[Image Omitted]

- wherein:
- R¹, R², and R³are independently -OMCH₃, —OH, —CH₃, or —Cl and wherein M is absent, (CH₂)_m—, or —(CH₂Y)_n—, wherein m is an integer from 1 to 5, n is an integer from 1 to 5, wherein Y is O, N, or S; and
- R⁴is —CH₂, or a substituted or an unsubstituted, linear or branched C2-C20 alkyl group, or —(Ar)—;
- R⁵is absent or H; and
- R⁶is —CH₃, a substituted or an unsubstituted, linear or branched C2-C20 alkyl group or a primary, secondary, tertiary or quaternary alkyl amine, —(Ar)—, ═(CNH₂NH₂), —((CH₂)_oNH₂), —((CH₂)_oNHCH₃), —((CH₂)_oNH(CH₂)_pNH₂), —((CH₂)_oNH(CH₂)_pAr), wherein o and p are independently integers from 1 to 15.

In a preferred embodiment the amine-functionalized silane is (3-aminopropyl) trimethoxysilane as shown in the following formula:

[Image Omitted]

In embodiments the amine-functionalized silanes can have 0, 1, 2, or 3 alkyl oxy groups attached to the silica, such that R¹, R², and R³are independently —OCH₃, —OH, —CH₃, or —Cl Exemplary amine-functionalized silanes having 3, 2, 1, or 0 alkyl oxy groups attached to the silica are shown here respectively as (3-aminopropyl) trimethoxysilane (CAS 919-30-2), (3-Aminopropyl)methyldimethoxysilane (CAS 3663-44-3), (3-aminopropyl)dimethylmethoxysilane (CAS 31024-26-7), and 3-aminopropylsilanetriol (CAS 58160-99-9):

[Image Omitted]

An additional amine-functionalized silanes having 3, 2, 1, or 0 alkyl oxy groups attached to the silica includes (3-aminopropyl)methyldiethoxysilane (CAS 3179-76-8).

In embodiments the amine-functionalized silanes can have 0, 1, 2, or 3 alkyl oxy groups attached to the silica, wherein the alkyl oxy groups have different number of carbons and heteroatoms, such that R¹, R², and R³are independently -OMCH₃, —OH, —CH₃, or —Cl and wherein M is absent, —(CH₂)_m, or —(CH_2mY)_n, wherein m is an integer from 1 to 5, n is an integer from 1 to 5, wherein Y is O, N, or S. Exemplary amine-functionalized silanes shown with 3 alkyl oxy groups attached to the silica and different number of carbons and heteroatoms are shown here respectively as (3-aminopropyl) trimethoxysilane (CAS 919-30-2), 3-triethoxysilylpropan-1-amine (CAS 919-30-2), and 3-[tris[2-(2-methoxyethoxy)ethoxy]silyl]propan-1-amine (CAS 87994-64-7).

[Image Omitted]

In embodiments the amine-functionalized silanes can have varying chain lengths between the amine group and the silica atom, such that R⁴is —CH₂, or a substituted or an unsubstituted, linear or branched C2-C20, C2-C15, or C2-C11 alkyl group. Exemplary amine-functionalized silanes having varying chain lengths between the amine group and the silica atom are shown here respectively as (3-aminopropyl) trimethoxysilane (CAS 919-30-2), 4-triethoxysilylbutan-1-amine (CAS 3069-30-5), and 2,2-dimethyl-4-trimethoxysilylbutan-1-amine (CAS 157923-74-5).

[Image Omitted]

In embodiments the amine-functionalized silanes can have varying chain lengths and spacers between the amine group and the silica atom, such that R⁵is absent or H; and R⁶is —CH₃, a substituted or an unsubstituted, linear or branched C2-C20, C2-C15, or C2-C10 alkyl group, a primary, secondary, tertiary or quaternary alkyl amine, —(Ar)—, —((CH₂)_oNH₂), —((CH₂)_oNHCH₃), —((CH₂)_oNH(CH₂)_pNH₂), —((CH₂)_oNH(CH₂)_pAr), wherein o and p are independently integers from 1 to 15, 1 to 10, or 1 to 5. Exemplary amine-functionalized silanes having varying chain lengths and space groups between the amine group and the silica atom are shown here respectively as 3-(3-trimethoxysilylpropoxy) aniline (CAS 71550-66-8) and N′-benzyl-N-(3-trimethoxysilylpropyl) ethane-1,2-diamine (CAS 62604-61-9).

[Image Omitted]

In embodiments the amine-functionalized silanes can have multiple amines on the silane molecule, such that R⁵is absent or H; and R⁶is —CH₃, a substituted or an unsubstituted, linear or branched C2-C20 alkyl group, a primary, secondary, tertiary or quaternary alkyl amine, —(Ar)—, ═(CNH₂NH₂), —((CH₂)_oNH₂), —((CH₂)_oNHCH₃), —((CH₂)_oNH(CH₂)_pNH₂), —((CH₂)_oNH(CH₂)_pAr), wherein o and p are independently integers from 1 to 15. Exemplary amine-functionalized silanes having multiple amines on the silane molecules are shown here respectively as 2-(3-trimethoxysilylpropyl) guanidine (CAS 128310-21-4), N′-[2-(3-trimethoxysilylpropylamino)ethyl]ethane-1,2-diamine (CAS 35141-30-1), and N′-[3-[dimethoxy(methyl)silyl]propyl]ethane-1,2-diamine (CAS 3069-29-2):

[Image Omitted]

In embodiments the amine-functionalized silanes can have primary, secondary, tertiary, or quaternary amines on the silane molecule, such that R⁵is absent or H; and R⁶is —CH₃, a substituted or an unsubstituted, linear or branched C2-C20 alkyl group or primary, secondary, tertiary or quaternary alkyl amine, —(Ar)—, ═(CNH₂NH₂), —((CH₂),NH₂), —((CH₂)_oNHCH₃), —((CH₂)_oNH(CH₂)_pNH₂), —((CH₂)_oNH(CH₂)_pAr), wherein o and p are independently integers from 1 to 15, 1 to 10, or 1 to 5. Exemplary primary, secondary, tertiary, or quaternary amines on the silane molecules are shown here respectively as (3-aminopropyl) trimethoxysilane (CAS 919-30-2), trimethyl(3-trimethoxysilylpropyl)azanium; chloride (CAS 35141-36-7), N-methyl-3-trimethoxysilylpropan-1-amine (CAS 3069-25-8), and N,N-diethyl-3-trimethoxysilylpropan-1-amine (CAS 41051-80-3).

[Image Omitted]

In some embodiments, the amine functionalized group is provided by an amine-functionalized silane according to formula I or II,

[Image Omitted]

- wherein:
- R¹, R², and R³are independently -OMCH₃, —OH, —CH₃, or —Cl and wherein M is absent, (CH₂)_m—, or —(CH₂Y)_n—, wherein m is an integer from 1 to 5, or 1 to 2, n is an integer from 1 to 5, wherein Y is O, N, or S;
- R⁴is —CH₂, or a substituted or an unsubstituted, linear or branched C2-C20, C2-C15, or C2-C11 alkyl group, or —(Ar)—;
- R⁵is absent or H; and
- R⁶is —CH₃, a substituted or an unsubstituted, linear or branched C2-C20 alkyl group or a primary, secondary, tertiary or quaternary alkyl amine, —(Ar)—, ═(CNH₂NH₂), —((CH₂)_oNH₂), —((CH₂)_oNHCH₃), —((CH₂)_oNH(CH₂)_pNH₂), —((CH₂)_oNH(CH₂)_pAr), wherein o and p are independently integers from 1 to 15, 1 to 10, or 1 to 5.

In some embodiments, the ratio (based on mass) of the trialkoxyorganosilane (e.g. (3-glycidylkoxypropyl) trimethoxysilane) to the amine-functionalized silane on the surface of the nanoparticles is at least about 1:1. In further embodiments the molar ratio of the trialkoxyorganosilane (e.g. (3-glycidylkoxypropyl) trimethoxysilane) to the amine-functionalized silane is from about 100:1 to about 1:100, preferably about 1:1 to about 100:1, about 1:1 to about 20:1, about 1:1 to about 10:1, or about 1:1 to about 5:1.

In some embodiments, the ratio (based on mass) of the nanoparticle coated with the trialkoxyorganosilane to the amine-functionalized silane on the surface of the coated nanoparticle is at least about 1:1. In further embodiments the mass ratio of the nanoparticle coated with the trialkoxyorganosilane to the amine-functionalized silane on the surface of the coated nanoparticle is from about 1:100 to about 100:1, preferably from about 1:1 to about 100:1, 1:1 to about 40:1, or 1:1 to about 15:1.

In an embodiment the nanoparticle coated with the trialkoxyorganosilane and thereafter functionalized with the amine-functionalized silane on the surface of the coated nanoparticle can have varying extent of coating. For example, in embodiments the nanoparticle is at least partially coated with the trialkoxyorganosilane, and preferably substantially or fully coated with the trialkoxyorganosilane. As one skilled in the art will ascertain, the extent of the coating of the nanoparticle with the trialkoxyorganosilane will then determine the extent of functionalization of the surface of the nanoparticle with the amine-functionalized silane as it covalently bonds to the trialkoxyorganosilane.

Additional description of exemplary functionalized, i.e. surface-modified, nanoparticles and methods of making are described in U.S. patent Ser. No. 18/300,625, which is incorporated herein in its entirety.

The total amount of functionalized nanoparticle included in the concentrate composition is about 1 wt % to 80 wt %, or about 10 wt % to 80 wt %, or about 20 wt % to 80 wt %, or about 20 wt % to 60 wt % based on the total weight of a concentrate composition.

Foaming Surfactants

The gas lift flow improving composition comprise at least one amphoteric, anionic and/or nonionic foaming surfactant. The surfactants in combination with the nanoparticles increases foaming or lower the density of the treated fluids to improve gas lift and therefore hydrocarbon yields, such as crude oil, from subterranean formations, increase the rate of hydrocarbon recovery or both, by lowering a subterranean interfacial tension.

In some embodiments the composition has a ratio on an actives basis (ppm) of functionalized nanoparticle to surfactant of at least about 1:1. In other embodiments, the composition has a ratio of functionalized nanoparticle to surfactant of at least about 1:1 to about 1:100, or about 1:1 to about 1:10, or about 1:1 to about 1:5.

In some embodiments the surfactants include an amphoteric, anionic and/or nonionic surfactant. In some embodiments the surfactants are a blend of two or more amphoteric surfactants. The amphoteric surfactant, also termed a zwitterionic surfactant, includes at least one internal anionic moiety, at least one internal cationic moiety, and has a net internal charge of zero. In some embodiments, the amphoteric surfactant comprises, consists essentially of, or consists of a single internal cation, a single internal anion, and a hydrophobic moiety selected from linear, branched, alicyclic, aryl, and alkaryl groups having 6 to 50 carbon atoms. In some embodiments, the amphoteric surfactant includes at least one internal cationic moiety comprising ammonium or phosphonium; and at least one internal anionic moiety comprising sulfonate, sulfate, oxide, carboxylate, phosphate, phosphite, or phosphonate. In some embodiments, the amphoteric surfactant includes at least one internal cationic moiety comprising ammonium or phosphonium; and at least one internal anionic moiety comprising sulfonate. In some embodiments, the amphoteric surfactant includes at least one internal hydroxyl group.

Examples of useful amphoteric surfactants include those having a hydrophobic moiety selected from linear, branched, alicyclic, aiyl, and alkaryl groups having 6 to 50 carbon atoms, or 8 to 50 carbon atoms, or 10 to 50 carbon atoms, or 12 to 50 carbon atoms, or 6 to 40 carbon atoms, or 6 to 30 carbon atoms, or 8 to 30 carbon atoms, or 10 to 30 carbon atoms, or 10 to 16 carbon atoms, or 12 to 30 carbon atoms. One useful class of amphoteric surfactants is amino acids having a hydrophobic moiety selected from linear, branched, alicyclic, aryl, and alkaryl groups having 6 to 50 carbon atoms, or 8 to 50 carbon atoms, or 10 to 50 carbon atoms, or 12 to 50 carbon atoms, or 6 to 40 carbon atoms, or 6 to 30 carbon atoms, or 8 to 30 carbon atoms, or 10 to 30 carbon atoms, or 10 to 16 carbon atoms, or 12 to 30 carbon atoms, including for example N-dodecyl-N,N-dimethyl glycine. Another class of useful amphoteric surfactants is trialkylamine oxides having a hydrophobic moiety selected from linear, branched, alicyclic, aryl, and alkaryl groups having 6 to 50 carbon atoms, or 8 to 50 carbon atoms, or 10 to 50 carbon atoms, or 12 to 50 carbon atoms, or 6 to 40 carbon atoms, or 6 to 30 carbon atoms, or 8 to 30 carbon atoms, or 10 to 30 carbon atoms, or 10 to 16 carbon atoms, or 12 to 30 carbon atoms. Representative examples of such amphoteric surfactants include N,N-dimethyl-N-dodecyl amine oxide, N,N-dimethyl-N-hexadecyl amine oxide, N,N-dimethyl-N-octadecyl amine oxide, and N,N-dimethyl-N—(Z-9-octadecenyl)-N-amine oxide.

Another class of useful amphoteric surfactants is betaines, which include one internal carboxylate moiety, one internal ammonium moiety, and a hydrophobic moiety selected from linear, branched, alicyclic, alkyl, aryl, and alkaryl groups having 6 to 50 carbon atoms, or 8 to 50 carbon atoms, or 10 to 50 carbon atoms, or 12 to 50 carbon atoms, or 6 to 40 carbon atoms, or 6 to 30 carbon atoms, or 8 to 30 carbon atoms, or 10 to 30 carbon atoms, or 10 to 16 carbon atoms, or 12 to 30 carbon atoms. Representative but nonlimiting examples of betaines include lauroylamide propylbetaine, 2-(dodecyldimethylammonio)acetate (CAS No. 683-10-3), cocamidopropyl betaine (2-[3-(dodecanoylamino) propyl-dimethy lazaniumyl] acetate), dodecanamidopropyl betaine ({2-[3-(dodecanoylamino)propyl]triazan-2-ium-2-yl)acetate), cetyl betaine (2-[hexadecyl(dimethyl)azaniumyl]acetate), oleamidopropyl betaine ((Z)-(carboxymethyl)dimethyl-3-((1-oxo-9-octadecenyl)amino)propylammonium hydroxide), caprylamidopropyl betaine (2-[dimethyl-[3-(octanoylamino)propyl]azaniumyl] acetate), and C10-16-alkyl (2-hydroxy-3-sulfopropyl)dimethyl (Mackam™ LHS supplied by Solvay.)

Another class of useful amphoteric surfactants is sultaines, which include one internal sulfonate moiety and one internal ammonium moiety (also referred to as sulfobetaines). Examples of sultaines are lauryl sulfobetaine (3-(dodecyldimethylammonio)propane-1-sulfonate), caprylyl sulfobetaine (3-[decyl(dimethyl)azaniumyl]propane-1-sulfonate), myristyl sulfobetaine (3-[dimethyl(tetradecyl)azaniumyl]propane-1-sulfonate), Sulfobetaine 10 (CAS No. 15163-36-7), Sulfobetaine 3-14 (N-tetradecyl-N,N-dimethyl-3-ammonio-1-propanesulfonate), Sulfobetaine 3-10 (N-decyl-N,N-dimethyl-3-ammonio-1-propanesulfonate); alkylether hydroxypropyl sultaines and alkyldimethylhydroxysultaines such as lauryl hydroxy sultaine (3-[dodecyl(dimethyl) ammonio]-2-hydroxypropane-1-sulfonate; 351.55 g/mol; CAS No. 13197-76-7), myristamidopropyl hydroxysultaine (2-hydroxy-N,N-dimethyl-N-(3-((1-oxotetradecyl)amino)propyl)-3-sulfo-, inner salt); cocoamidopropyl hydroxysultaine, and the like. Mixtures of such surfactants having various carbon chain lengths are obtained in some embodiments; for example, 3-((C10-C16)-alkyldimethylammonio)-2-hydroxypropanesulfonate (CAS No. 72869-77-3) is a mixture of alkylated moieties having an average of 10 to 16 carbons.

Another class of useful amphoteric surfactants is phosphate functional amphoteric surfactants, which include one internal phosphate moiety, one internal ammonium moiety, optionally a carboxylate moiety, and either one or two hydrophobic moieties, wherein each hydrophobic moiety is selected from linear, branched, alicyclic, aryl, and alkaryl groups having 6 to 50 carbon atoms, or 8 to 50 carbon atoms, or 10 to 50 carbon atoms, or 12 to 50 carbon atoms, or 6 to 40 carbon atoms, or 6 to 30 carbon atoms, or 8 to 30 carbon atoms, or 10 to 30 carbon atoms, or 12 to 30 carbon atoms. Representative but nonlimiting examples of phosphate functional amphoteric surfactants include phosphatidylserines, phosphatidylethanolamines, phosphatidylcholines such as 1-oleoyl-2-palmitoyl-phosphatidylcholine, and sphingomyelins.

In some embodiments the nonionic surfactants are one or more surfactants selected from the group comprising, consisting essentially of, or consisting of alkoxylated alcohols, alkoxylated alkyl phenols, or ethylene oxide/propylene oxide copolymers. In other embodiments the nonionic surfactants are alkoxylated alcohols, alkoxylated alkyl phenols, or ethylene oxide/propylene oxide copolymers having an hydrophilic-lipophilic balance (HLB) greater than about 10, for example about 10 to 20, or about 10 to 18, or about 10 to 16, or about 10 to 14, or about 11 to 20, or about 11 to 18, or about 11 to 17, or about 11 to 16, or about 11 to 15, or about 11 to 14, or about 11 to 13, and mixtures of these compounds.

In some embodiments, the nonionic surfactants are ethoxylated C6-C14 or C10-C14 alcohols and alkyl phenols. In some embodiments the nonionic surfactants are polyoxyethylene alkyl ether, polyoxyethylene alkylphenol ether, ethylene oxide-propylene oxide block copolymers, alkyl glucoside, polyoxyethylene fatty acid ester, sucrose fatty acid ester, sorbitan fatty acid ester, polyoxyethylene sorbitan fatty acid ester, and fatty acid alkanolamide. In some embodiments the nonionic surfactant is ethoxylated castor oil, dimethyl-lauryl-amine, 00-16 alkyl dimethylamines, alkoxylated ethylenediamine, ethoxylated alcohol, ethoxylated hexanol or mixtures thereof.

In some embodiments the surfactants are a blend of amphoteric surfactants, anionic surfactants, nonionic surfactants and mixtures thereof. In some embodiments, the anionic surfactants are salts (including, for example, sodium, potassium, ammonium, and substituted ammonium salts such as mono-, di-, and triethanolamine salts) of the anionic sulfate, sulfonate, carboxylate and sarcosinate surfactants. In other embodiments, the anionic surfactants are isethionates such as the acyl isethionates, N-acyl taurates, fatty acid amides of methyl tauride, alkyl succinates, sulfoacetates, and sulfosuccinates, monoesters of sulfosuccinate (e.g., saturated and unsaturated C12-C18 monoesters), diesters of sulfosuccinate (e.g., saturated and unsaturated C6-C14 diesters), and N-acyl sarcosinates.

In some embodiments the anionic surfactant is a sulfosuccinate. In some embodiments the sulfosuccinate are C8-C22 sulfosuccinates. In still other embodiments the anionic surfactant is sodium dodecylbenzene sulfonate, nacconol 90G, dioctyl sodium sulfosuccinate, sodium-toluene sulfonate, sodium benzene sulfonate, linear alkylbenzene sulfonates (LAS) or sodium dodecyl sulfate (SDS).

In an embodiment, the foaming amphoteric surfactants comprises an alkyl betaines, preferably lauroylamide propylbetaine or cocamidopropyl betaine. In other embodiments, the foaming surfactants comprise a sulfonate moiety, such as alkyldiphenyloxide disulfonate.

The total amount of surfactant included in the concentrate composition is about 0.1 wt % to 70 wt %, or about 1 wt % to 60 wt %, or about 10 wt % to 60 wt %, or about 10 wt % to 50 wt % based on the total weight of a concentrate composition.

Solvents

The compositions can include a solvent (which may be referred to as a co-solvent or a mutual solvent) to provide an aqueous medium. Solvents employed in the compositions (concentrates, injectates, and/or fracturing fluids) comprise, consist essentially of, or consist of coupling agents and water sources. In embodiments the solvent is water and additional coupling agent.

Suitable solvents comprise, consist essentially of, or consist of linear, branched, or cyclic aliphatic alcohols having 1 to 6 carbon atoms, diols having 1 to 6 carbon atoms, alkyl ethers of alkylene glycols wherein the alkyl moiety has 1 to 6 carbon atoms (e.g., ethylene glycol mono-n-butyl ether), polyalkylene glycols, and mixtures thereof. Also useful as solvents are glycol and glycerol-based acetals and ketals, such as those formed from the condensation of e.g., glycerol with formaldehyde, acetone, or oxocarboxylic acids, semialdehydes, and esters thereof such as levulinic acid or an alkyl levulinate. In some embodiments, the solvent comprises, consists essentially of, or consists of methanol, ethanol, propanol, butanol, glycerol, ethylene glycol, ethylene glycol monoalkyl ether wherein the ether moiety comprises 1 to 6 carbon atoms, or a combination of two or more thereof. In some embodiments, the solvent is ethylene glycol and diethylene glycol.

The total amount of solvent included in the concentrate composition is about 0.01 wt % to 30 wt %, about 0.1 wt % to 30 wt %, about 1 wt % to 30 wt %, about 5 wt % to 30 wt %, or about 10 wt % to 30 wt % based on the total weight of a concentrate composition.

The solvent is generally not included in the list of “actives” or active ingredients, but is present in the concentrate to promote and increase storage stability of the concentrate as well as facilitate stability of the composition during dilution of the concentrate to form an injectate. Additionally, in some embodiments the solvent further suppress the freezing point of the concentrate which is advantageous for winter storage and transportation purposes. Finally, in some embodiments the solvent reduce the viscosity of a concentrate, increasing the pumpability and pourability of the concentrate over a range of field use temperatures.

The composition comprising, consisting essentially of, or consisting of combination of the functionalized nanoparticles, solvent and/or surfactants can be variously formulated. In some embodiments, the composition is an injectate. An injectate is any aqueous composition that is injected into a subterranean formation to bring about a gas lift, increase in yield or rate of recovery of a hydrocarbon from the subterranean formation. In some embodiments, the composition is a concentrate. In some embodiments the composition is a fracturing fluid or drilling fluid.

In some embodiments, the composition comprises, consists essentially of, or consists of functionalized nanoparticles, a surfactant comprising an amphoteric surfactant and a solvent selected from a water source, mutual solvents or mixture thereof. In further embodiments, the composition comprises, consists essentially of, or consists of functionalized nanoparticles, a surfactant comprising amphoteric surfactants, nonionic surfactants, anionic surfactants, or mixtures thereof, and a solvent selected from a water source, mutual solvents or mixture thereof.

In some embodiments, the disclosed compositions are made using produced water and are suitable for injection into a subterranean formation, where the fluids remain stable and do not cause precipitation, separation, or another behavior attributable to instability, while flowing underground. This in turn results improve recovery of hydrocarbons from the subterranean formations.

The disclosed compositions may include additional components or additives, such oxidizing agents, water-soluble enzymes, clay stabilizers, corrosion inhibitors, scale inhibitors, viscosifying agents, flow back aids, friction reducers, proppants, biocides, buffers, or in various combinations depending on the chemical and physical attributes of the particular subterranean formation. In some embodiments the additive includes oil field additives conventionally used in hydraulic fracturing or post-primary fracturing of subterranean hydrocarbon-containing formations. In some embodiments, the additives are added to the concentrates, and the resulting concentrates are stable, or even storage stable. In other embodiments, the additives are not added to the concentrate, but rather are added to the subterranean formation contemporaneously with dilution of the concentrate to form an injectate, or are added to the injectate after the injectate is formed.

In some embodiments, the additional components or additives comprises a corrosion inhibitor, scale inhibitor, or combinations thereof.

In some embodiments, an injectate is formed by combining the gas lift improver composition comprising the functionalized nanoparticles, one or more foaming surfactants, solvent, and optional additional components or additives with a water source. In further embodiments, an injectate is formed by combining a water source and gas lift flow improving components comprising functionalized nanoparticles having an average particle size from about 1 nm to about 1000 nm and a foaming surfactant comprising an amphoteric, anionic and/or nonionic surfactant. In some embodiments the water source is water with one or more solids dissolved therein, or with total dissolved solids less than about 300,000 mg/L. The methods descried herein are suitable for use in water with high total dissolved solids.

Beneficially, the injectate compositions are suitable for use to increase the gas lift of hydrocarbon from a subterranean formation, rate of hydrocarbon recovery from a subterranean formation, total yield of hydrocarbon recovered from a subterranean formation, or combinations thereof.

Methods of Use

The injectates and gas lift flow improving compositions described herein can be used to increase the gas lift of hydrocarbon from a subterranean formation or well (i.e. production), rate of hydrocarbon recovery from a subterranean formation or well, total yield of hydrocarbon recovered from a subterranean formation or well, or combinations thereof. Without being limited to a particular mechanism of action, in embodiment, the increase the gas lift of hydrocarbon from a subterranean formation or well (i.e. production), rate of hydrocarbon recovery from a subterranean formation or well, total yield of hydrocarbon recovered from a subterranean formation or well, or combinations thereof as a result of the injectate or gas lift flow improving composition lowering the fluid density within a subterranean formation or well. The methods provide the increased liquid unloading, leading to a production increase from the subterranean formation or well.

The methods of using the injectates and gas lift flow improving compositions provide benefits of using chemical solution with or without mechanical gas lift, including higher production at the same gas lift injection rate or a similar production at a lower gas injection rate. The methods of using the injectates and gas lift flow improving compositions also beneficially overcome various drawbacks of gas lift without chemicals, including ineffective for low reservoir pressure despite high gas injection flow rates, limits on gas injection rate for stable casing and tubing fluid flow, and/or unreliable backpressure systems and low max operating pressure.

Disclosed herein are methods of treating a subterranean formation or well for improving gas lift flow, comprising, consisting essentially of, or consisting of, introducing into the subterranean formation or well an injectate or the gas lift flow improving compositions described herein. In some embodiments, the introduction is by injecting the fluid into a subterranean formation or well to be treated. In embodiments, the fluid is introduced into the subterranean formation or well with a drilling fluid, a fracturing fluid, or an injectate.

In some embodiments, the injectate or composition breaks up deposits present in the subterranean formation or well, alters the wettability of the subterranean formation or well to water wet, decreases fluid density within the subterranean formation or well, and increases the relative permeability of the subterranean formation or well to hydrocarbons or combinations thereof. In some embodiments, the injectate or composition break up of deposits, the alteration of the wettability of the subterranean formation or well to water wet, decreases fluid density within the subterranean formation or well, and/or the increase of the relative permeability of the subterranean formation or well for hydrocarbons results in the increased flow of hydrocarbons from the subterranean formation or well. In some embodiments, the injectate or compositions can be used to lower and improve relative density of the fluids to improve gas lift flow from the subterranean formation or well.

In some embodiments the methods are particularly suitable for subterranean formation or well comprising a low permeability formation, such as permeability formation of less than 0.1 mD, or less than 0.01 mD. In some embodiments, the low permeability formation can include wells with loading that occurs when water and condensate enter the bottom of the well.

The injectate or compositions described herein can also be used to increase the production of hydrocarbons from a subterranean formation or well that has already been subject to prior subterranean formation stimulation such as hydraulic fracturing or matrix stimulation. In some embodiments, the injectate or compositions can be used to enhanced oil recovery stimulation where compositions are pumped with water into injection well(s) and the oil is recovered from production well(s). In some embodiments, the injectate or compositions can be used as additives to stimulation fluids (such as hydraulic fracturing fluids). In some embodiments, the injectate or compositions can be injected with other treatment fluids into the formation prior to pumping the stimulation fluids.

A concentration of the functionalized nanoparticles (or nanoparticles in a composition) can be between about 1 ppm and about 5,000 ppm, such as 50 ppm and about 5,000 ppm, between about 100 ppm and about 1,000 ppm, between about 100 ppm and about 500 ppm, or between about 100 ppm and about 300 ppm, or between about 100 ppm and about 200 ppm. However, the disclosure is not so limited and the concentration of the nanoparticles in the composition may be lower or higher depending on a particular application.

A concentration of the foaming surfactant(s) can be between about 1 ppm and about 500,000 ppm, such as 50 ppm and about 5,000 ppm, between about 100 ppm and about 1,000 ppm, between about 100 ppm and about 500 ppm, or between about 100 ppm and about 300 ppm, or between about 100 ppm and about 200 ppm. However, the disclosure is not so limited and the concentration of the nanoparticles in the composition may be lower or higher depending on a particular application.

In some embodiments the composition has a ratio on an actives basis (ppm) of functionalized nanoparticle to surfactant of at least about 1:1. In other embodiments, the composition has a ratio of functionalized nanoparticle to surfactant of at least about 1:1 to about 1:100, or about 1:1 to about 1:10, or about 1:1 to about 1:5.

A pH of the compositions may be between about 3.0 and about 12.0. In some embodiments, the compositions may exhibit a basic pH, such as a pH greater than about 9.0, greater than about 10.0, or even greater than about 11.0. In other embodiments, the compositions may exhibit a pH between about 7.0 and about 9.0, such as about 8.0. In other embodiments, the compositions may exhibit an acidic pH, such as a pH between about 3.0 and about 7.0, such as between about 3.0 and about 5.0, or between about 5.0 and about 7.0. In some embodiments, the pH of the compositions may be about 3.0. However, the disclosure is not so limited, and the compositions may exhibit a different pH.

In some embodiments, the injectate or composition is disposed within the subterranean formation or well for at least 7 to 90 days, where it does not separate, precipitate or coagulate.

After subterranean injection, hydrocarbon fluids contacted by the composition decrease fluid density to enhance amount and/or rate of hydrocarbon recovery from the subterranean formation or well.

In some embodiments, the introducing (e.g., injecting) of the composition is carried out after hydraulic fracturing of the subterranean formation. In some embodiments, the composition is injected into a subterranean formation wherein no hydraulic fracturing has been carried out. In other embodiments, injecting of the composition is carried out contemporaneously with hydraulic fracturing of the subterranean formation. In some embodiments the composition and methods are particularly useful in secondary and tertiary oil recovery, collectively referred to herein as enhanced oil recovery, which is any injection carried out after the fluid connection of a well is already established. In some embodiments, the composition and methods are particularly useful in obtaining hydrocarbon from tight or very tight subterranean rock formation in need of lowering the fluid density to improve gas lift flow or increase production in the subterranean formation or well.

In some embodiments, a method to enhance hydrocarbon recovery is to alter the hydrocarbon fluid density in the subterranean formation. Fluid density is measured in mass divided by volume. However, a primary outcome measured in the field is production rate from a subterranean formation or well.

The methods described herein can further be combined with high gas flaw rates to further enhance oil recovery. However, the use of the injectates and compositions described herein beneficially does not require any additional or high efficiency pumps (as required with high gas flaw rates). Instead the use of the injectates and compositions described herein reduces the amount of gas and equipment used in the field.

The disclosed compositions and methods are used to enhance hydrocarbon recovery from subterranean formations that have previously been depleted. In some embodiments, the disclosed compositions and methods are used to obtain oil from subterranean formations that are tight rock formations or very tight rock formations.

The compositions and methods are most effective in enhancing hydrocarbon recovery from subterranean formations having a water cut less than about 39% or greater than about 76%.

The compositions and methods are most effective in enhancing hydrocarbon recovery from subterranean formations having a fluid with a total dissolved solid of less than about 300,000 mg/L.

Embodiments

The present disclosure is further defined by the following numbered embodiments:

- 1. A gas lift flow improving composition comprising: a functionalized nanoparticle, wherein the nanoparticle has an average particle size from about 1 nm to about 1000 nm; a foaming surfactant comprising an amphoteric, anionic and/or nonionic surfactant; and wherein the composition is dispersed in an aqueous medium.
- 2. The composition of embodiment 1, wherein ratio of the functionalized nanoparticle to the surfactant is about 1:1 or greater on an actives (ppm) basis, or between about 1:1 to about 1:100 on an actives (ppm) basis.
- 3. The composition of any one of embodiments 1-2, wherein the foaming surfactant comprises an amphoteric alkyl betaine.
- 4. The composition of any one of embodiments 1-3, wherein the aqueous medium comprises a coupler and/or a solvent.
- 5. The composition of any one of embodiments 1-4, wherein the nanoparticle has an average particle size from about 1 nm to about 500 nm, or from about 1 nm to about 200 nm.
- 6. The composition of any one of embodiments 1-3, wherein the nanoparticles are selected from silica and metal-based nanoparticles.
- 7. The composition of embodiment 4, wherein the silica is selected from the group consisting of colloidal silica, nanosilica, silicate nanoparticle, polyhedral oligomeric silsesquioxane nanoparticle, and silicon dioxide nanoparticle dispersion.
- 8. The composition of any one of embodiments 1-5, wherein the functionalized nanoparticle is surface modified with a silane compound.
- 9. The composition of embodiment 8, wherein the silane compound comprising one or more of 3-glycidoxypropyltrimethoxysilane, 3-glycidoxypropylmethyldimethoxysilane, 3-glycidoxypropylmethyldiethoxysilane, 3-glycidoxypropyltriethoxysilane, 2-(3,4-epoxycyclohexyl)propyltrimethoxysilane, 2-(3,4 epoxycyclohexyl)propyltriethoxysilane, 2-(3,4-epoxycyclohexyl)ethyltrimethoxysilane, 2-(3,4-epoxycyclohexyl)ethyltriethoxysilane, 2-(3,4-epoxycyclohexyl)methyltrimethoxysilane, 2-(3,4 epoxycyclohexyl)methyltriethoxysilane, [(3-ethyl-3 oxethanyl)methoxy]propyltrimethoxysilane, or [(3-ethyl-3-oxethanyl) methoxy]propyltriethoxysilane.
- 10. The composition of embodiment 8, wherein the silane compound is a zwitterionic silane comprising one or more of 3-(dimethyl (3-(trimethoxysilyl) propyl)-ammonio) propane-1-sulfonate, 3-(dimethyl (3-(triethoxysilyl) propyl)-ammonio) propane-1-sulfonate, or 3-(diethyl (3-(trimethoxysilyl) propyl)-ammonio) propane-1-sulfonate.
- 11. The composition of any one of embodiments 1-7, wherein the functionalized nanoparticle has a core-shell nanoparticle morphology comprising a trialkoxyorganosilane coated nanoparticle core and an amine functionalized group on the surface of the nanoparticle as a shell.
- 12. The composition of embodiment 11, wherein the wherein the trialkoxyorganosilane is an epoxy functional silane, hydroxylic hydrophilic silane, hydroxyl functional silane, or thiol functional silane.
- 13. The composition of any one of embodiments 11-12, wherein the amine functionalized group is provided by an amine-functionalized silane according to formula I or II,

[Image Omitted]

wherein: R¹, R², and R³are independently -OMCH₃, —OH, —CH₃, or —Cl and wherein M is absent, —(CH₂)_m—, or —(CH₂Y)_n—, wherein m is an integer from 1 to 5, n is an integer from 1 to 5, wherein Y is O, N, or S; and R⁴is —CH₂, or a substituted or an unsubstituted, linear or branched C2-C20 alkyl group, or —(Ar)—; R⁵is absent or H; and R⁶is —CH₃, a substituted or an unsubstituted, linear or branched C2-C20 alkyl group or a primary, secondary, tertiary or quaternary alkyl amine, —(Ar)—, ═(CNH₂NH₂), —((CH₂),NH₂), —((CH₂)_oNHCH₃), —((CH₂)_oNH(CH₂)_pNH₂), —((CH₂)_oNH(CH₂)_pAr), wherein o and p are independently integers from 1 to 15.

- 14. The composition of any one of embodiments 11-13, wherein the amine functionalized group is covalently bonded to the trialkoxyorganosilane coated nanoparticle.
- 15. The composition of any one of embodiments 11-14, wherein the molar ratio of the trialkoxyorganosilane to the amine-functionalized silane is about 1:1 to about 100:1 or about 1:1 to about 20:1, and the mass ratio of the trialkoxyorganosilane coated nanoparticle core to the amine-functionalized silane on the coated nanoparticle is about 1:1 to about 100:1 or about 1:1 to about 40:1.
- 16. The composition of any one of embodiments 11-15, wherein the functionalized nanoparticle is a reaction product obtained by a first step of coating a nanoparticle with a trialkoxyorganosilane and thereafter covalently bonding an amine-functionalized silane to the surface of the coated nanoparticle, wherein the reaction product has a core-shell nanoparticle morphology comprising the trialkoxyorganosilane coated nanoparticle core and the amine functionalized group on the surface of the coated nanoparticle core as a shell.
- 17. The composition of embodiment 16, wherein the amine functionalized group is covalently bonded to the trialkoxyorganosilane coated nanoparticle.
- 18. The composition of any one of embodiments 1-17, wherein the functionalized nanoparticle comprises from about 20-80 wt-% of the composition, wherein the foaming surfactant comprises from about 10-60 wt-% of the composition, and wherein the aqueous medium comprises from about 10-30 wt-% of the composition.
- 19. The composition of any one of embodiments 1-18, further comprising a corrosion inhibitor, scale inhibitor, or combinations thereof.
- 20. An injectate composition comprising: a water source and the composition of any one of embodiments 1-19, or a water source and gas lift flow improving components comprising functionalized nanoparticles having an average particle size from about 1 nm to about 1000 nm and a foaming surfactant comprising an amphoteric, anionic and/or nonionic surfactant.
- 21. Use of the injectate composition of embodiment 20 to increase the gas lift of hydrocarbon from a subterranean formation or well, rate of hydrocarbon recovery from a subterranean formation or well, total yield of hydrocarbon recovered from a subterranean formation or well, or combinations thereof.
- 22. A method of improving gas lift flow in a subterranean formation or well comprising: introducing an injectate according to embodiment 17 or a gas lift flow improving composition according to any one of embodiments 1-19 into a fluid comprising hydrocarbon or condensate in a subterranean formation or well, and lowering the fluid density to improve gas lift flow or increase production in the subterranean formation or well.
- 23. The method of embodiment 22, wherein the introducing step is injecting the composition into the subterranean formation or well.
- 24. The method of any one of embodiments 22-23, wherein the injectate or the composition is introduced into the subterranean formation or well with a drilling fluid, a fracturing fluid, or an injectate.
- 25. The method of any one of embodiments 22-24, wherein the fluid has a water cut less than about 39% or greater than 76%.
- 26. The method of any one of embodiments 22-25, wherein the fluid has a total dissolved solid of less than about 300,000 mg/L.
- 27. The method of any one of embodiments 22-26, wherein the subterranean formation or well comprises a low permeability formation of less than 0.1 mD, or less than 0.01 mD.
- 28. The method of any one of embodiments 22-27, further comprises recovering hydrocarbon from the treated subterranean formation or well.
- 29. The method of embodiment 28, wherein the recovered hydrocarbon comprises an oil or a condensate.
- 30. The method of any one of embodiments 28-29, wherein the method results in an increase in recovered hydrocarbon in comparison to a subterranean formation or well treated with an injectate or gas lift flow improving composition that is free of the functionalized nanoparticle.

EXAMPLES

Embodiments of gas lift flow improving compositions comprising functionalized nanoparticles combined with surfactants are further defined in the following non-limiting Examples. It should be understood that these Examples, while indicating one or more preferred embodiments, are given by way of illustration only and are non-limiting. From the above discussion and these Examples, one skilled in the art can ascertain the essential characteristics of the disclosure, and without departing from the spirit and scope thereof, can make various changes and modifications of the embodiments of the disclosure to adapt it to various usages and conditions. Thus, various modifications of the embodiments, in addition to those shown and described herein, will be apparent to those skilled in the art from the foregoing description. Such modifications are also intended to fall within the scope of the appended claims.

The following materials are utilized in the Examples:

- Alkyl betaine (2), cocamidopropyl betaine surfactant, commercially available from ChampionX Inc.
- Alkyl betaine, Lauroylamide propylbetaine surfactant, commercially available from ChampionX Inc.
- Dowfax 3B2, anionic alkyldiphenyloxide disulfonate surfactant, commercially available from Dow.
- Glymo-NP, functionalized nanoparticle with glymo ((3-Glycidoxypropyl). trimethoxysilane, CAS Number 2530-83-8) modification to a Colloidal Silica nanoparticle
- SiO₂—NH₂NP, APTMS Functionalized GLYMO-nanosilica.

Example 1

Testing was conducted to assess if nanoparticles improve performance in foaming tests as an indicator of use as a gas lift flow improvers. Amine functionalized nanoparticles utilized in the Example were trialkoxyorganosilane coated nanoparticles coated with an amine-functionalized silane. The amine functionalized nanoparticles were used in the study in combination with an alkyl betaine surfactant composition (surfactant is the only active). The study evaluated varying concentrations in a 1000-mL jacketed graduated cylinder at designed temperature. The concentrations were from 1000 ppm of actives to 200 ppm actives at a constant temperature of 70° C. in a synthetic brine with approximately 150,000 mg/L TDS (total dissolved solids), with iron and carbonate ions removed to avoid oxidation and scale formation. The measurements were conducted using 100 mL of fluid sample was agitated with sparging gas of nitrogen at a flow rate of 1 LPM. Testing was conducted in a 20% water cut. A total 200 ppm actives was further tested as an actives concentration that did not cause over foaming in the tests.

Foam height in mL was recorded every 15 seconds up to 5 minutes with sparging gas stopped for recording foam half-life; the time taken for the foam column reduced to its half. The tests measured foam height and these results are shown in FIGS. 1A-1B, where the nanoparticle (NP) alone did not show improvement above a blank (No additives) test point as a negative control. The combinations of NP and alkyl betaine surfactant showed improvement by increased foam height. The best performance was achieved at a 1:1 ratio of the NP to alkyl betaine surfactant (100 ppm/100 ppm).

The tests also measured the maximum foam height and half-life of the foam from FIGS. 1A-1B, which are depicted in FIGS. 2A-2B. The half-life of foam is indicative of foam stability, where the increase in half-life provides a more stable foam. The 1:1 ratio (100 ppm NP) showed the greatest maximum foam height and the longest foam half-life of the evaluated compositions, again demonstrating best performance achieved at a 1:1 ratio of the NP to alkyl betaine surfactant (100 ppm/100 ppm). The evaluate compositions providing foaming that has a maximum height and long half-life is illustrative of the compositions lowering the density of the treated fluids, wherein the quick formation (i.e. decrease in density of the fluid) and long-lasting effect is desired to provide which gas lift flow improving compositions.

Example 2

Additional testing according to the methods described in Example 1 was conducted in a 95% water cut. The results are shown in FIGS. 3A-3B, where the nanoparticle (NP) alone did not show improvement above a blank (No additives) test point as a negative control, as shown in FIG. 3B. The combinations of NP and alkyl betaine surfactant showed improvement by increased foam height. Again the best performance was achieved at a 1:1 ratio of the NP to alkyl betaine surfactant (100 ppm/100 ppm). The measurement of maximum foam height and foam half-life is shown in FIGS. 4A-4B, where the 1:1 ratio (100 ppm NP) showed the greatest maximum foam height, again demonstrating best performance achieved at a 1:1 ratio of the NP to alkyl betaine surfactant (100 ppm/100 ppm). In these tests the longest foam half-life was achieved from the 50 ppm NP/150 ppm alkyl betaine.

All test series showed a benefit of the inclusion of the NP (including at 50 ppm) to extend the half-life of the foam, indicative of decreasing the density of the treated fluid. In applications of use both foam height and foam half-life (i.e. stability) are important.