Reversible aminal gel compositions, methods, and use

Patent metadata

Field	Value
Publication number	US-9879170-B2
Application number	US-201715423765-A
Country	US
Kind code	B2
Filing date	Feb 3, 2017
Priority date	Feb 3, 2016
Publication date	Jan 30, 2018
Grant date	Jan 30, 2018

Abstract

A well treatment composition for use in a hydrocarbon-bearing reservoir comprising a reversible aminal gel composition. The reversible aminal gel composition includes a liquid precursor composition. The liquid precursor composition is operable to remain in a liquid state at about room temperature. The liquid precursor composition comprises an organic amine composition; an aldehyde composition; a polar aprotic organic solvent; and a metal salt composition with valence 3, 4, or 5. The liquid precursor composition transitions from the liquid state to a gel state responsive to an increase in temperature in the hydrocarbon-bearing reservoir. The gel state is stable in the hydrocarbon-bearing reservoir at a temperature similar to a temperature of the hydrocarbon-bearing reservoir, and the gel state is operable to return to the liquid state responsive to a change in the hydrocarbon-bearing reservoir selected from the group consisting of: a decrease in pH in the hydrocarbon-bearing reservoir and an addition of excess metal salt composition in the hydrocarbon-bearing reservoir.

First claim

What is claimed is:

1. A method for introducing a reversible aminal gel composition into a wellbore in a hydrocarbon-bearing reservoir, the method comprising the steps of:
injecting a reversible aminal gel composition into the hydrocarbon-bearing reservoir, the reversible aminal gel composition comprising:
a liquid precursor composition, the liquid precursor composition operable to remain in a liquid state at about room temperature, where the liquid precursor composition comprises:
an organic amine composition;
an aldehyde composition;
a polar aprotic organic solvent; and
a metal salt composition with valence 3, 4, or 5;

allowing the liquid precursor composition to transition from the liquid state to a gel state responsive to an increase in temperature from the hydrocarbon-bearing reservoir; and
returning the gel state to the liquid state by changing a property in the hydrocarbon-bearing reservoir selected from the group consisting of: pH in the hydrocarbon-bearing reservoir, an amount of metal salt composition in the hydrocarbon-bearing reservoir, and combinations thereof.

2. The method according to claim 1 , further comprising the step of adding a gel time accelerating additive comprising sodium sulfite.

3. The method according to claim 1 , where the polar aprotic organic solvent comprises N-vinyl pyrrolidone and is operable to be polymerized through a radical initialized reaction.

4. The method according to claim 3 , where N-vinyl pyrrolidone is copolymerized with a second polymer thereby modifying hydrophilicity of a gel matrix and altering a release profile of cargo upon time delayed or triggered release.

5. The method according to claim 4 , where the second polymer comprises N-butyl acrylate.

6. The method according to claim 3 , further comprising the step of polymerizing N-vinyl pyrrolidone as either a homopolymer or a copolymer through radical initiation with potassium persulfate.

7. The method according to claim 3 , further comprising the step of polymerizing N-vinyl pyrrolidone as either a homopolymer or a copolymer through radical initiation with UV light.

8. The method according to claim 3 , further comprising the step of polymerizing N-vinyl pyrrolidone as either a homopolymer or a copolymer in a photosensitized gel through radical initiation with light of a wavelength greater than 350 nm.

9. The method according to claim 1 , further comprising the step of maintaining a stable gel state between about 100° C. and about 250° C.

10. The method according to claim 1 , further comprising the step of adjusting a rate of cargo release from the reversible aminal gel composition, where the reversible aminal gel composition comprises a cargo to carry out a wellbore function selected from the group consisting of: modifying viscosity of a wellbore fluid; initiating a cement set; and modifying yield point of a wellbore fluid.

11. The method according to claim 1 , where a molar ratio of the organic amine composition to the aldehyde composition to the polar aprotic organic solvent is between about 1:2:1 and about 1:200:500.

12. The method according to claim 1 , further comprising the step of adding delayed release capsules comprising a compound selected from the group consisting of: acidic solution and a metal salt composition with valence 3, 4, or 5.

13. The method according to claim 1 , further comprising the step of adjusting a ratio of components in the liquid precursor composition to tune a temperature at which the reversible aminal gel composition reverses to the liquid state.

14. The method according to claim 1 , further comprising the step of adjusting a ratio of components in the liquid precursor composition to tune a pH at which the reversible aminal gel composition reverses to the liquid state.

15. The method according to claim 1 , further comprising the step of adjusting a ratio of components in the liquid precursor composition to modify the concentration of excess metal salt required to transform the reversible aminal gel composition into the liquid state.

16. The method according to claim 1 , further comprising the step of adjusting a ratio of components in the liquid precursor composition to alter the amount of time required for a liquid hemiaminal gel form to transform into a greater melting point gel form.

17. The method according to claim 1 , further comprising the step of adjusting a ratio of components in the liquid precursor composition to tune physical properties of the gel state by exchange and reduction in an amount of polar aprotic organic solvent required for producing a homogenous gel.

18. The method according to claim 1 , where the organic amine composition comprises a tris primary amine of polypropylene glycol with an approximate molecular weight of between about 280 and about 100,000 Da.

19. The method according to claim 1 , where the organic amine composition comprises a bis primary amine of polyethylene glycol with an approximate molecular weight of between about 200 and about 100,000 Da.

20. The method according to claim 1 , where the aldehyde composition comprises a compound selected from the group consisting of: formaldehyde, paraformaldehyde, phenol formaldehyde, resorcinol-formaldehyde, phenyl acetate-HMTA, and mixtures thereof.

21. The method according to claim 1 , where the polar aprotic organic solvent comprises a compound selected from the group consisting of: N-alkylpyrrolidone, N,N′-dialkylformamide, dialkylsulfoxide, and mixtures thereof.

22. The method according to claim 1 , where the metal salt composition comprises a metal selected from the group consisting of: iron(III), aluminum(III), and mixtures thereof.

23. The method according to claim 1 , further comprising the step of adding a gel time accelerating additive comprising sodium sulfite to the hydrocarbon-bearing reservoir.

24. The method according to claim 1 , where the gel state comprises triazine-based molecules.

25. The method according to claim 1 , further comprising the step of maintaining a stable gel state between about 110° C. and about 250° C.

26. The method according to claim 1 , where a molar ratio of the organic amine composition to the aldehyde composition to the polar aprotic organic solvent is between about 1:2:1 and about 1:200:500.

27. The method according to claim 1 , further comprising the step of adding delayed release capsules to the hydrocarbon-bearing reservoir comprising a compound selected from the group consisting of: acidic solution and a metal salt composition.

Assignees

• Saudi Arabian Oil Co

Inventors

• Boul Peter J
• Reddy B Raghava
• Hilfiger Matt
• Thaemlitz Carl

Classifications

• C04B28/02

  containing hydraulic cements other than calcium sulfates · CPC title

• C04B24/30

  Condensation polymers of aldehydes or ketones · CPC title

• C09K8/467

  containing additives for specific purposes · CPC title

• C09K2208/12

  Swell inhibition, i.e. using additives to drilling or well treatment fluids for inhibiting clay or shale swelling or disintegrating · CPC title

• C08G2220/00

  Compositions for preparing gels other than hydrogels, aerogels and xerogels · CPC title