Stability improvement of CO2 foam for enhanced oil recovery applications using polyelectrolytes and polyelectrolyte complex nanoparticles

Patent metadata

Field	Value
Publication number	US-10214680-B2
Application number	US-201615226525-A
Country	US
Kind code	B2
Filing date	Aug 2, 2016
Priority date	Aug 11, 2015
Publication date	Feb 26, 2019
Grant date	Feb 26, 2019

Abstract

Polyelectrolyte nanoparticles are generated to stabilize foam for use in enhanced oil recovery. Stability is further enhanced by optimizing pH and a ratio of polycationic and polyanioinic materials, resulting in stronger and longer lasting foams in the presence of crude oil. Use of these nanoparticles results in negligible damage to formation permeability.

First claim

The invention claimed is:

1. In a foam including a non-liquid fluid phase and a liquid dispersion phase, the improvement comprising:
the foam having a foam quality ranging from 60% to 90% determined as a percentage total foam volume occupied by the non-liquid fluid phase;
the liquid dispersion phase being a dispersion of polyelectrolyte material and surfactant in water,
the polyelectrolyte material and the surfactant being combined in a ratio of surfactant to polyelectrolyte material ranging from 3:1 to 9:1;
the polyelectrolyte material forming nanoparticles by electrostatic interaction of a cationic and an anionic polyelectrolyte,
the nanoparticles being located at lamellae of the liquid dispersion phase in an effective amount to stabilize the foam;
the polyelectrolyte material being present in an amount ranging from 0.1% to 5% of the liquid phase by weight; and
the non-liquid fluid phase being CO 2 in a supercritical state.

2. The foam of claim 1 , further comprising a pH adjusting agent in an effective amount to reduce pH of the foam to a value ranging from 5 to 9.

3. The foam of claim 1 , wherein the foam quality ranges from 60% to 90% of the non-liquid fluid phase by volume.

4. The foam of claim 1 , wherein the foam quality is assessed at conditions of pressure and temperature in a petroleum reservoir.

5. The foam of claim 1 , wherein the surfactant is a nonionic surfactant.

6. The foam of claim 1 , wherein the surfactant is an anionic surfactant.

7. The foam of claim 1 , wherein the cationic polyelectrolyte is selected from the group consisting of polyethylenimine, polyallylamine, chitosan and combinations thereof.

8. The foam of claim 1 , wherein the anionic polyelectrolyte comprises dextran sulfate.

9. The foam of claim 1 , wherein the cationic polyelectrolyte is selected from the group consisting of polyethylenimine, polyallylamine, chitosan and combinations thereof.

10. A method of CO 2 flooding, comprising the steps of:
introducing the foam of claim 1 into an injection wellbore;
flowing the foam through the wellbore for subsequent introduction into rock of an oil reservoir;
flooding the foam from the injection wellbore on a pathway extending from the injection wellbore through the oil reservoir and towards one or more producing wellbores to enhance recovery of oil in place from the oil reservoir.

11. The method of claim 10 , further comprising a step of forming the foam by use of inline injection to combine the gas phase with the liquid dispersion phase.

12. In a method of hydraulic fracturing of rock for the purpose of stimulating hydrocarbon production from a reservoir, the improvement comprising:
combining proppant with the foam of claim 1 to form a frac fluid; and
injecting the frac fluid into a well under suitable conditions for the hydraulic fracturing of the reservoir rock.

13. A foam comprising:
a CO 2 phase in a supercritical state, and
a liquid dispersion phase;
wherein:
the foam has a foam quality ranging from 60% to 90% determined as a percentage total foam volume occupied by the gas phase, and assessed at conditions of temperature and pressure in a petroleum reservoir;
the liquid dispersion phase is a dispersion of polyelectrolyte material and surfactant in water, wherein:
the polyelectrolyte material and the surfactant are combined in a ratio of surfactant to polyelectrolyte material ranging from 3:1 to 9:1;
the surfactant is selected from a group consisting of anionic surfactants, nonionic surfactants and combinations thereof in an amount that is substantially optimized by selection according to zeta potential;
the polyelectrolyte material includes at least one of polyethylenimine, polyallylamine, chitosan and dextran sulfate, and forms nanoparticles, the nanoparticles being located at lamellae of the liquid dispersion phase in an effective amount to stabilize the foam; and
the polyelectrolyte material is present in an amount ranging from 0.1% to 5% of the liquid phase by weight; and

the pH of the foam is adjusted to a value ranging from 5 to 9 via an effective amount of a pH adjusting agent.

14. A method of CO 2 flooding, comprising the steps of:
introducing the foam of claim 13 into an injection wellbore;
flowing the foam through the wellbore for subsequent introduction into rock of an oil reservoir;
flooding the foam from the injection wellbore on a pathway extending from the injection wellbore through the oil reservoir and towards one or more producing wellbores to enhance recovery of oil in place from the oil reservoir.

15. The method of claim 14 , further comprising a step of forming the foam by use of inline injection to combine the gas phase with the liquid dispersion phase.

16. In a method of hydraulic fracturing of rock for the purpose of stimulating hydrocarbon production form a reservoir, the improvement comprising:
combining proppant with the foam of claim 13 to form a frac fluid; and
injecting the frac fluid into a well under suitable conditions for the hydraulic fracturing of the reservoir rock.

Assignees

• Univ Kansas

Inventors

• Barati Ghahfarokhi Reza

Classifications

• C09K2208/10

  Nanoparticle-containing well treatment fluids · CPC title

• C09K8/594 Primary

  Compositions used in combination with injected gas {, e.g. CO2 orcarbonated gas}(C09K8/592 takes precedence) · CPC title

• E21B43/166

  Injecting a gaseous medium; Injecting a gaseous medium and a liquid medium (CO2 injection E21B43/164; steam injection E21B43/24) · CPC title

• E21B43/26

  by forming crevices or fractures · CPC title

• E21B43/164

  Injecting CO2 or carbonated water (in combination with organic material C09K8/594) · CPC title