Methods of selective and non-selective plugging for water flooding in enhanced oil recovery
View Patent ↗Materials and methods for enhanced oil recovery are provided. In particular, a composition for improved selective and non-selective plugging is provided, the composition comprising one or more biological polymers selected from polysaccharides, in addition to one or more bio surfactants Methods are also provided for enhanced oil recovery wherein the biological polymer composition, one or more biosurfactants and one or more solvents are injected into an oil-bearing formation undergoing water flooding.
1. A method of enhancing recovery of oil from an oil-bearing formation having non-uniform permeability which comprises simultaneously injecting xanthan gum and guar gum at a ratio of 50% or greater than xanthan gum to 50% or less of guar gum and additionally injecting a sophorolipid biosurfactant into the oil-bearing formation via an injection well; injecting one or more solvents selected from the group consisting of isopropyl alcohol and ammonium hydroxide into the oil-bearing formation via the injection well; injecting a flooding liquid into the injection well to displace the oil from the oil-bearing formation; and recovering the displaced oil via a production well.
2. The method of claim 1 , wherein the biosurfactant is mixed with the xanthan gum and guar gum prior to being injected into the formation.
3. The method of claim 1 , wherein the biosurfactant is injected after the xanthan gum and guar gum are injected into the formation.
4. The method of claim 1 , wherein the sophorolipid biosurfactant is injected at a concentration of 0.01 to 5.0 g/L.
5. The method of claim 1 , wherein the one or more solvents comprise 1.0% to 10.0% v/v isopropyl alcohol and 1% to 5% v/v ammonium hydroxide.
6. The method of claim 1 , used to control water intrusion into a producing oil well.
7. The method of claim 1 , used to selectively reduce a permeability of zones in the oil-bearing formation having greater relative permeability compared to the surrounding zones of permeability in the formation.
8. The method of claim 1 , further comprising injecting 0.5 to 3 g/L of a de-scaling agent selected from the group consisting of ethylenediaminetetraaceticacid (EDTA), sodium citrate and citric acid into the formation via the injection well.