Compositions for enhanced fracture cleanup using redox treatment

Patent metadata

Field	Value
Publication number	US-10053614-B2
Application number	US-201615205994-A
Country	US
Kind code	B2
Filing date	Jul 8, 2016
Priority date	Apr 17, 2014
Publication date	Aug 21, 2018
Grant date	Aug 21, 2018

Abstract

A cleanup fluid for reducing a viscosity of a residual viscous material in fractures of a hydrocarbon-bearing formation is disclosed. The cleanup fluid includes an acid precursor, the acid precursor operable to trigger an exothermic reaction component and the exothermic reaction component operable to generate heat, where the heat is operable to reduce a viscosity of the residual viscous material to create a reduced viscosity material, the reduced viscosity material operable to flow from the fractures.

First claim

What is claimed is:

1. A cleanup fluid for reducing a viscosity of a viscous material in and around a wellbore of a hydrocarbon-bearing formation, the cleanup fluid comprising:
an optional acid precursor, the optional acid precursor present at a low concentration not greater than about 5% by volume of the cleanup fluid, if present, to trigger an exothermic reaction component in addition to or alternative to heat in the wellbore, and the acid precursor comprising at least one component selected from the group consisting of: triacetin; methyl acetate; hydrochloric acid; acetic acid; and mixtures thereof; and
the exothermic reaction component operable to generate heat, and the exothermic reaction component comprising at least one component selected from the group consisting of: urea; sodium hypochlorite; ammonium chloride; ammonium bromide; ammonium nitrate; ammonium sulfate; ammonium carbonate; ammonium hydroxide; sodium nitrite; potassium nitrite; and mixtures thereof, and the exothermic reaction component comprising at least one ammonium containing compound at about 3 molar (M) concentration and at least one nitrite containing compound at about 3 molar (M) concentration,
where the cleanup fluid comprises only liquid components in solution prepared to be fluidly compatible with a viscous fluid component such that the cleanup fluid and viscous fluid component quickly mix and the heat reduces a viscosity of the viscous fluid component to create a reduced viscosity material in less than about 1 minute, and
where the cleanup fluid does not include viscosifying components at concentrations that generate foam or introduce foam into the wellbore.

2. The cleanup fluid of claim 1 , where the ammonium containing compound comprises NH 4 Cl and the nitrite containing compound comprises NaNO 2 .

3. The cleanup fluid of claim 2 , where the concentration of the NH 4 Cl and NaNO 2 is about 3 M.

4. The cleanup fluid of claim 1 , where the acid precursor comprises triacetin.

5. The cleanup fluid of claim 1 , where the exothermic reaction component reacts when a temperature within the hydrocarbon-bearing formation reaches about 120° F.

6. The cleanup fluid of claim 1 , further comprising a cross-linked gel.

7. The cleanup fluid of claim 1 , where the viscous fluid component comprises a compound selected from the group consisting of: carboxymethyl cellulose, hydroxyethyl cellulose, carboxymethyl hydroxyethyl cellulose, hydroxypropyl cellulose, methyl hydroxyl ethyl cellulose, hydroxypropyl guar, carboxymethyl guar, guar cross-linked boron ions from an aqueous borax/boric acid solution, guar cross-linked with organometallic compounds, aluminum phosphate-ester oil gels, and mixtures thereof.

8. The cleanup fluid of claim 1 , further comprising an aqueous guar solution having a concentration of guar gum between about 0.1% and about 15% by volume.

9. The cleanup fluid of claim 1 , further comprising an aqueous guar solution having a concentration of guar gum between about 0.1% and about 10% by volume.

10. The cleanup fluid of claim 1 , further comprising an aqueous guar solution having a concentration of guar gum between about 1% and about 10% by volume.

11. The cleanup fluid of claim 1 , further comprising an aqueous guar solution having a concentration of guar gum between about 2% and about 8% by volume.

12. The cleanup fluid of claim 1 , further comprising an aqueous guar solution having a concentration of guar gum between about 4% and about 6% by volume.

13. The cleanup fluid of claim 1 , further comprising an ammonium containing compound selected from the group consisting of: ammonium chloride, ammonium bromide, ammonium nitrate, ammonium sulfate, ammonium carbonate, ammonium hydroxide, and mixtures thereof.

14. The cleanup fluid of claim 1 , further comprising a nitrite containing compound selected from the group consisting of: sodium nitrite, potassium nitrite, and mixtures thereof.

15. A method for use of a cleanup fluid in a wellbore or reservoir, the method comprising the steps of:
optionally preparing an acid precursor, the acid precursor present at a low concentration not greater than about 5% by volume of the cleanup fluid, if present, to trigger an exothermic reaction component, in addition to or alternative to heat in the wellbore or reservoir, and the acid precursor comprising at least one component selected from the group consisting of: triacetin; methyl acetate; hydrochloric acid; acetic acid; and mixtures thereof;
preparing the exothermic reaction component operable to generate heat, and the exothermic reaction component comprising at least one component selected from the group consisting of: urea; sodium hypochlorite; ammonium chloride; ammonium bromide; ammonium nitrate; ammonium sulfate; ammonium carbonate; ammonium hydroxide; sodium nitrite; potassium nitrite; and mixtures thereof, and the exothermic reaction component comprising at least one ammonium containing compound at about 3 molar (M) concentration and at least one nitrite containing compound at about 3 molar (M) concentration,
where the cleanup fluid comprises only liquid components in solution prepared to be fluidly compatible with a viscous fluid component such that the cleanup fluid and viscous fluid component quickly mix and the heat reduces a viscosity of the viscous fluid component to create a reduced viscosity material in less than about 1 minute,
where the cleanup fluid does not include viscosifying components at concentrations that generate foam or introduce foam into the wellbore;
injecting the acid precursor, if present, and the exothermic reaction component into the wellbore;
allowing the exothermic reaction component to react in situ to produce heat and nitrogen gas, the heat and nitrogen gas operable to increase the temperature and pressure in situ, the viscous material comprising at least one of asphaltenes or corrosion products in the wellbore, to create the reduced viscosity material.

16. The method of claim 15 , where the ammonium containing compound comprises NH 4 Cl and the nitrite containing compound comprises NaNO 2 .

17. The method of claim 15 , where the exothermic reaction component comprises an ammonium containing compound selected from the group consisting of: ammonium chloride, ammonium bromide, ammonium nitrate, ammonium sulfate, ammonium carbonate, ammonium hydroxide, and mixtures thereof.

18. The method of claim 15 , where the exothermic reaction component comprises a nitrite containing compound selected from the group consisting of: sodium nitrite, potassium nitrite, and mixtures thereof.

19. The method of claim 15 , where the viscous material comprises asphaltenes and corrosion products in the wellbore.

20. The method of claim 19 , where the corrosion products are selected from the group consisting of: iron oxides, iron sulfides, sodium chloride, calcium carbonate, silica, and mixtures thereof.

21. The method of claim 15 , wherein the step of reducing the viscosity of the viscous material to create the reduced viscosity material increases the injectivity of the wellbore.

22. The method of claim 15 , wherein the step of reducing the viscosity of the viscous material to create the reduced viscosity material increases the productivity of the hydrocarbon-bearing reservoir.

23. The method of claim 15 , further comprising the step of increasing nitrogen lift in the wellbore.

Assignees

• Saudi Arabian Oil Co

Inventors

• Al-Nakhli Ayman R
• Abass Hazim H
• Al-Otaibi Ahmad S

Classifications

• C09K8/528

  inorganic depositions, e.g. sulfates or carbonates · CPC title

• C09K8/592

  Compositions used in combination with generated heat, e.g. by steam injection · CPC title

• C09K8/524 Primary

  organic depositions, e.g. paraffins or asphaltenes · CPC title

• E21B43/267

  reinforcing fractures by propping · CPC title

• C09K2208/32

  Anticorrosion additives · CPC title