Abstract: A formation treatment fluid may include a wettability alteration agent, a solvent, an injection gas, and an optional foaming agent. The wettability alteration agent may include a fluorinated surfactant, a silicon-based surfactant, charged nanoparticles partially modified with fluorine containing groups, or combinations thereof. Methods for altering a hydrocarbon-bearing reservoir surface wettability may include providing the formation treatment fluid, injecting the formation treatment fluid into the hydrocarbon-bearing reservoir, and recovering fluids produced from the hydrocarbon-bearing reservoir.

Abstract: A 3D printed proppant includes a core having support bars extending from the core to a shell, the shell encapsulating the core and the support bars. Another 3D printed proppant includes a porous core and a shell encapsulating the porous core, where the porous core has a porosity from 25% to 75%. The 3D printed proppant has a particle size from 8 mesh to 140 mesh. The core, the support bars, the porous core, the shell, or combinations thereof includes metal, polymer, ceramic, composite, or combinations thereof. Additionally, a method for producing a 3D printed proppant is provided.

Abstract: A process for designing a coated proppant particle for downhole transportation and placement. A carrier fluid may transport the coated proppant particle downhole. The process may include selecting a proppant particle material and a coating material. The process may also include selecting a target reduction in a settling velocity and determining a diameter of the coating material disposed on the proppant particle material based on the selected proppant particle material and the density of the coating material. The process for designing a coated proppant particle may include selecting a coating material thickness for coating on the proppant particle material and determining a coating material and design for coating on the proppant particle with the coating material thickness based on the selected proppant particle material and thickness of the coating material to achieve the target reduction in settling velocity.

Abstract: Gas and condensate productivities from a hydrocarbon reservoir can be enhanced using a chemical treatment composition. The chemical treatment composition includes a solvent mixture and a wettability alteration chemical. The solvent mixture includes a solvent that is operable to increase the relative permeability of gas within the hydrocarbon reservoir and the wettability alteration chemical is operable to alter the wettability of surfaces of the hydrocarbon reservoir, in each case enhancing the gas and condensate productivities from the hydrocarbon reservoir. The solvent mixture is selected to provide a chemical treatment composition with a flash point of at least 40° C. (104° F.).

Abstract: Gas and condensate productivities from a hydrocarbon reservoir can be enhanced using a chemical treatment composition. The chemical treatment composition includes a solvent mixture and a wettability alteration chemical. The solvent mixture includes a solvent that is operable to increase the relative permeability of gas within the hydrocarbon reservoir and the wettability alteration chemical is operable to alter the wettability of surfaces of the hydrocarbon reservoir, in each case enhancing the gas and condensate productivities from the hydrocarbon reservoir. The solvent mixture is selected to provide a chemical treatment composition with a flash point of at least 40° C. (104° F.).

Abstract: Gas and condensate productivities from a hydrocarbon reservoir can be enhanced using a chemical treatment composition. The chemical treatment composition includes a solvent mixture and a wettability alteration chemical. The solvent mixture includes a solvent that is operable to increase the relative permeability of gas within the hydrocarbon reservoir and the wettability alteration chemical is operable to alter the wettability of surfaces of the hydrocarbon reservoir, in each case enhancing the gas and condensate productivities from the hydrocarbon reservoir. The solvent mixture is selected to provide a chemical treatment composition with a flash point of at least 40° C. (104° F.).

Abstract: The present invention relates to a process to treat a subterranean formation by introducing a composition containing between 1 and 40 wt % on total weight of the composition of a chelating agent selected from the group of glutamic acid N,N-diacetic acid or a salt thereof (GLDA), aspartic acid N,N-diacetic acid or a salt thereof (ASDA), and methylglycine N,N-diacetic acid or a salt thereof (MGDA) into the formation, wherein the process comprises a soaking step.

Abstract: The present invention relatestoa process to treat a subterranean formation by introducing a composition containing between 1 and 40 wt % on total weight of the composition of a chelating agent selected from the group of glutamic acid N,N-diacetic acid or a salt thereof (GLDA), aspartic acid N,N-diacetic acid or a salt thereof (ASDA), and methylglycine N,N-diacetic acid or a salt thereof (MGDA) into the formation, wherein the process comprises a soaking step.

Abstract: Gas and condensate productivities from a hydrocarbon reservoir can be enhanced using a chemical treatment composition. The chemical treatment composition includes a solvent mixture and a wettability alteration chemical. The solvent mixture includes a solvent that is operable to increase the relative permeability of gas within the hydrocarbon reservoir and the wettability alteration chemical is operable to alter the wettability of surfaces of the hydrocarbon reservoir, in each case enhancing the gas and condensate productivities from the hydrocarbon reservoir. The solvent mixture is selected to provide a chemical treatment composition with a flash point of at least 40° C. (104° F.).

Abstract: The present invention relates to a composition containing a dispersed phase emulsified in a continuous phase, wherein at least 5 wt % on total weight of the dispersed phase of the composition is a chelating agent selected from the group of glutamic acid N,N-diacetic acid or a salt thereof (GLDA), aspartic acid N,N-diacetic acid or a salt thereof (ASDA), and methylglycine N,N-diacetic acid or a salt thereof (MGDA), and a process for treating a subterranean formation comprising a step of introducing the above composition into the formation.