Abstract: A method, wellbore, and pill for treating a region of a subterranean formation adjacent a wellbore zone of the wellbore, including injecting a gellable treatment composition (e.g., as the pill) through the wellbore zone into the region of the subterranean formation adjacent the wellbore zone, allowing the gellable treatment composition to form nanoparticles in-situ in the region and gel in the region via heat provided by the region to prevent or reduce flow of an unwanted fluid from the region into the wellbore zone. The gellable treatment composition may include a zwitterionic gemini surfactant (ZGS).

Abstract: A method of controlling a permeability zone in a reservoir includes introducing a diverter agent comprising a morpholinium based zwitterionic surfactant including a sulfonate terminal moiety, an ammonium-based zwitterionic surfactant, and an activator in a wellbore. Once introduced, the diverter agent contacts a high permeability zone in the reservoir.

Abstract: A method of controlling a permeability zone in a reservoir includes introducing a diverter agent comprising a morpholinium based zwitterionic surfactant including a sulfonate terminal moiety, an ammonium-based zwitterionic surfactant, and an activator in a wellbore. Once introduced, the diverter agent contacts a high permeability zone in the reservoir. The diverter agent heats and gels to form a gelled diverter agent in the high permeability zone, subsequently forming a zone of decreased permeability.

Abstract: A method of controlling a permeability zone in a reservoir includes introducing a diverter agent comprising a morpholinium based zwitterionic surfactant including a sulfonate terminal moiety, an ammonium-based zwitterionic surfactant, and an activator in a wellbore. Once introduced, the diverter agent contacts a high permeability zone in the reservoir.

Abstract: A diverter agent includes a morpholinium based zwitterionic surfactant having a sulfonate terminal moiety; and an ammonium based zwitterionic surfactant.

Abstract: A diverter agent includes a morpholinium based zwitterionic surfactant having a sulfonate terminal moiety; and an ammonium based zwitterionic surfactant.

Abstract: A composition includes a polymer having a structure as shown in Formula (I): where x is from 20 to 70, y is from 20 to 30, z is from 1.0 to 10, and p is from 1.0 to 10. A method of making the polymer is also provided. The polymer composition may be used as a wellbore fluid. Also provided is a method of treating a hydrocarbon bearing formation. The method includes introducing the polymer-containing wellbore fluid into a high permeability zone of a hydrocarbon bearing formation such that it blocks at least a portion of the high permeability zone of the hydrocarbon bearing formation, stimulating the hydrocarbon bearing formation thereby creating pathways for hydrocarbon production, and recovering hydrocarbons.

Abstract: An asymmetric nanocomposite supercapacitor and a method of making the asymmetric nanocomposite supercapacitor. The asymmetric nanocomposite supercapacitor includes a negative electrode with monoclinic tungsten oxide (m-WO3) nanoplates, and a binding compound coated on one face of a substrate, and a positive electrode with a carbonaceous material and a binding compound coated on one face of a substrate. Where the face of the positive electrode and the face of the negative electrode coated with the carbonaceous material and m-WO3 nanoplates, respectively, are separated by and in direct contact with a porous separator.

Abstract: A fracturing fluid may include a first surfactant and a second surfactant. The first surfactant may have a structure represented by formula (I): wherein m is an integer ranging from 2 to 3, and n, o, and k are each, independently, integers ranging from 2 to 10. The second surfactant having a structure represented by Formula (II): wherein R2 is a C15-C27 hydrocarbon group or a C15-C29 substituted hydrocarbon group, R3 is a C1-C10 hydrocarbon group, and p and q are each, independently, an integer ranging from 1 to 4. Methods of treating a hydrocarbon-bearing formation include injecting the fracturing fluid in the hydrocarbon-bearing formation, the fracturing fluid being configured to transport a proppant in fractures of the hydrocarbon-bearing formation.

Abstract: An asymmetric nanocomposite supercapacitor and a method of making the asymmetric nanocomposite supercapacitor. The asymmetric nanocomposite supercapacitor includes a negative electrode with monoclinic tungsten oxide (m-WO3) nanoplates, and a binding compound coated on one face of a substrate, and a positive electrode with a carbonaceous material and a binding compound coated on one face of a substrate. Where the face of the positive electrode and the face of the negative electrode coated with the carbonaceous material and m-WO3 nanoplates, respectively, are separated by and in direct contact with a porous separator.

Abstract: A wellbore fluid including a first surfactant, a second surfactant, an activator and an aqueous base fluid is provided. The first surfactant has a structure represented by Formula (I): where Y1, Y2, Y3, Y4 are each, independently, a sulfonate, a carboxylate, an ester or a hydroxyl group, m is an integer ranging from 2 to 3, and n, o, and k are each, independently, integers ranging from 2 to 10. The second surfactant has a structure represented by Formula (III): where R2 is a C15-C27 hydrocarbon group or a C15-C29 substituted hydrocarbon group, R3 is a C1-C10 hydrocarbon group, and p and q are each, independently, an integer ranging from 1 to 4. A method of using the wellbore fluid for treating a hydrocarbon-containing formation is also provided.

Abstract: A method, wellbore, and pill for treating a region of a subterranean formation adjacent a wellbore zone of the wellbore, including injecting a gellable treatment composition (e.g., as the pill) through the wellbore zone into the region of the subterranean formation adjacent the wellbore zone, allowing the gellable treatment composition to form nanoparticles in-situ in the region and gel in the region via heat provided by the region to prevent or reduce flow of an unwanted fluid from the region into the wellbore zone. The gellable treatment composition may include a zwitterionic gemini surfactant (ZGS).

Abstract: A wellbore fluid including a first surfactant, a second surfactant, an activator and an aqueous base fluid is provided. The first surfactant has a structure represented by Formula (I): where Y1, Y2, Y3, Y4 are each, independently, a sulfonate, a carboxylate, an ester or a hydroxyl group, m is an integer ranging from 2 to 3, and n, o, and k are each, independently, integers ranging from 2 to 10. The second surfactant has a structure represented by Formula (III): where R2 is a C15—C27 hydrocarbon group or a C15—C29 substituted hydrocarbon group, R3 is C1—C10 hydrocarbon group, and p and q are each, independently, an integer ranging from 1 to 4. A method of using the wellbore fluid for treating a hydrocarbon-containing formation is also provided.

Abstract: A method, wellbore, and pill for treating a region of a subterranean formation adjacent a wellbore zone of the wellbore, including injecting a gellable treatment composition (e.g., as the pill) through the wellbore zone into the region of the subterranean formation adjacent the wellbore zone, allowing the gellable treatment composition to form nanoparticles in-situ in the region and gel in the region via heat provided by the region to prevent or reduce flow of an unwanted fluid from the region into the wellbore zone. The gellable treatment composition may include a zwitterionic gemini surfactant (ZGS).

Abstract: An asymmetric nanocomposite supercapacitor and a method of making the asymmetric nanocomposite supercapacitor. The asymmetric nanocomposite supercapacitor includes a negative electrode with monoclinic tungsten oxide (m-WO3) nanoplates, and a binding compound coated on one face of a substrate, and a positive electrode with a carbonaceous material and a binding compound coated on one face of a substrate. Where the face of the positive electrode and the face of the negative electrode coated with the carbonaceous material and m-WO3 nanoplates, respectively, are separated by and in direct contact with a porous separator.

Abstract: A fracturing fluid may include a first surfactant and a second surfactant. The first surfactant may have a structure represented by formula (I): wherein m is an integer ranging from 2 to 3, and n, o, and k are each, independently, integers ranging from 2 to 10. The second surfactant having a structure represented by Formula (II): wherein R2 is a C15-C27 hydrocarbon group or a C15-C29 substituted hydrocarbon group, R3 is a C1-C10 hydrocarbon group, and p and q are each, independently, an integer ranging from 1 to 4. Methods of treating a hydrocarbon-bearing formation include injecting the fracturing fluid in the hydrocarbon-bearing formation, the fracturing fluid being configured to transport a proppant in fractures of the hydrocarbon-bearing formation.

Abstract: A wellbore fluid including a first surfactant, a second surfactant, an activator and an aqueous base fluid is provided. The first surfactant has a structure represented by Formula (I): where m is an integer ranging from 2 to 3, and n, o, and k are each, independently, integers ranging from 2 to 10. The second surfactant has a structure represented by Formula (III): where R2 is a C15-C27 hydrocarbon group or a C15-C29 substituted hydrocarbon group, R3 is a C1-C10 hydrocarbon group, and p and q are each, independently, an integer ranging from 1 to 4. A method for treating a hydrocarbon-containing formation with the wellbore fluid is also provided.

Abstract: A wellbore fluid including a first surfactant, a second surfactant, an activator and an aqueous base fluid is provided. The first surfactant has a structure represented by Formula (I): where Y1, Y2, Y3, Y4 are each, independently, a sulfonate, a carboxylate, an ester or a hydroxyl group, m is an integer ranging from 2 to 3, and n, o, and k are each, independently, integers ranging from 2 to 10. The second surfactant has a structure represented by Formula (III): where R2 is a C15-C27 hydrocarbon group or a C15-C29 substituted hydrocarbon group, R3 is a C1-C10 hydrocarbon group, and p and q are each, independently, an integer ranging from 1 to 4. A method of using the wellbore fluid for treating a hydrocarbon-containing formation is also provided.

Abstract: A wellbore fluid including a first surfactant, a second surfactant, an activator and an aqueous base fluid is provided. The first surfactant has a structure represented by Formula (I): where Y1, Y2, Y3, Y4 are each, independently, a sulfonate, a carboxylate, an ester or a hydroxyl group, m is an integer ranging from 2 to 3, and n, o, and k are each, independently, integers ranging from 2 to 10. The second surfactant has a structure represented by Formula (III): where R2 is a C15-C27 hydrocarbon group or a C15-C29 substituted hydrocarbon group, R3 is a C1-C10 hydrocarbon group, and p and q are each, independently, an integer ranging from 1 to 4. A method of using the wellbore fluid for treating a hydrocarbon-containing formation is also provided.

Abstract: A wellbore fluid including a first surfactant, a second surfactant, an activator and an aqueous base fluid is provided. The first surfactant has a structure represented by Formula (I): where m is an integer ranging from 2 to 3, and n, o, and k are each, independently, integers ranging from 2 to 10. The second surfactant has a structure represented by Formula (III): where R2 is a C15-C27 hydrocarbon group or a C15-C29 substituted hydrocarbon group, R3 is a C1-C10 hydrocarbon group, and p and q are each, independently, an integer ranging from 1 to 4. A method for treating a hydrocarbon-containing formation with the wellbore fluid is also provided.