Composition and method for recovering hydrocarbon fluids from a subterranean reservoir

• US 6,454,003 B1
• Filed: 06/14/2000
• Issued: 09/24/2002
• Est. Priority Date: 06/14/2000
• Status: Expired due to Term

• Current Assignee: Ecolab USA Incorporated (Ecolab, Inc.)
• Original Assignee: Ondeo Nalco Energy Services LP (Ecolab, Inc.)
• Inventors: Chang, Kin-Tai, Frampton, Harry, Morgan, James C.
• Primary Examiner(s): Bagnell, David
• Assistant Examiner(s): Walker, Zakiya
• Application Number:
  US09/593,197
• Time in Patent Office: 832 Days
• Field of Search: 166/270, 166/403, 166/294, 166/295, 166/272--27, 166/275, 523/130, 523/131, 507/903, 507/224, 507/225, 507/261, 507/266
• US Class Current: 166/270
• CPC Class Codes: C09K 8/512 containing cross-linking agents
• CPC Class Codes: C09K 8/516 characterised by their form or by the form of their components, e.g. encapsulated material
• CPC Class Codes: C09K 8/588 characterised by the use of specific polymers polymeric surfactants C09K8/584

Abstract

This invention is directed to a composition comprising expandable cross linked polymeric microparticles having an unexpanded volume average particle size diameter of from about 0.05 to about 10 microns and a cross linking agent content of from about 9,000 to about 200,000 ppm of labile cross linkers and from 0 to about 300 ppm of non-labile cross linkers and to the use of the composition for modifying the permeability of subterranean formations and increasing the mobilization and/or recovery rate of hydrocarbon fluids present in the formations.

Claims

1. A composition comprising highly cross linked expandable polymeric microparticles having an unexpanded volume average particle size diameter of from about 0.05 to about 10 microns and a cross linking agent content of from about 9,000 to about 200,000 ppm of labile cross linkers and from 0 to about 300 ppm of non-labile cross linkers.

2. The composition of claim 1 wherein the unexpanded volume average particle size diameter is from about 0.1 to about 3 microns.

3. The composition of claim 1 wherein the unexpanded volume average particle size diameter is from about 0.1 to about 1 microns.

4. The composition of claim 1 wherein the labile cross linker is selected from diacrylates and polyfunctional vinyl derivatives of a polyalcohol.

5. The composition of claim 1 comprising cross linked anionic, amphoteric, ion-pair or betaine-containing polymeric microparticles.

6. The composition of claim 5 wherein composition is in the form of an emulsion or aqueous suspension.

7. The composition of claim 6 wherein the cross linked polymeric microparticle is anionic.

8. The composition of claim 7 wherein the anionic polymeric microparticle is prepared by free-radical polymerization from about 95 to about 10 mole percent of nonionic monomers and from about 5 to about 90 mole percent anionic monomers.

9. The composition of claim 8 wherein the nonionic monomer is acrylamide.

10. The composition of claim 9 wherein the anionic monomer is 2-acrylamido-2-methyl-1-propanesulfonic acid.

11. The composition of claim 10 wherein the labile cross linker is polymethyleneglycol diacrylate.

12. The composition of claim 11 wherein the non-labile cross linker is methylene bisacrylamide.

13. A method of modifying the permeability to water of a subterranean formation comprising injecting into the subterranean formation a composition comprising highly cross linked expandable polymeric microparticles having an unexpanded volume average particle size diameter of from about 0.05 to about 10 microns and a cross linking agent content of from about 9,000 to about 200,000 ppm of labile cross linkers and from 0 to about 300 ppm of non-labile cross linkers, wherein the microparticles have a smaller diameter than the pores of the subterranean formation and wherein the labile cross linkers break under the conditions of temperature and pH in the subterranean formation to form expanded microparticles.

14. The method of claim 13 wherein from about 100 ppm to about 10,000 ppm of the composition, based on polymer actives, is added to the subterranean formation.

15. The method of claim 13 wherein from about 500 ppm to about 1500 ppm of the composition, based on polymer actives, is added to the subterranean formation.

16. The method of claim 13 wherein from about 500 ppm to about 1000 ppm of the composition, based on polymer actives, is added to the subterranean formation.

17. The method of claim 13 wherein the composition is added to injection water as part of a secondary or tertiary process for the recovery of hydrocarbon from the subterranean formation.

18. The method of claim 17 wherein the injection water is added to the subterranean formation at a temperature lower than the temperature of the subterranean formation.

19. The method of claim 17 wherein the composition is used in a carbon dioxide and water tertiary recovery project.

20. The method of claim 17 wherein the composition is used in a tertiary oil recovery process, one component of which constitutes water injection.

21. The method of claim 17 wherein the injection water is added to a producing well.

22. The method of claim 13 wherein the subterranean formation is a sandstone or carbonate hydrocarbon reservoir.

23. A method of increasing the mobilization or recovery rate of hydrocarbon fluids in a subterranean formation comprising injecting into the subterranean formation a composition comprising highly cross linked expandable polymeric microparticles having an unexpanded volume average particle size diameter of from about 0.05 to about 10 microns and a cross linking agent content of from about 9,000 to about 200,000 ppm of labile cross linkers and from 0 to about 300 ppm of non-labile cross linkers, wherein the microparticles have a smaller diameter than the pores of the subterranean formation and wherein the labile cross linkers break under the conditions of temperature and pH in the subterranean formation to decrease the mobility of the composition.

24. The method of claim 23 wherein from about 100 ppm to about 5000 ppm of the composition, based on polymer actives, is added to the subterranean formation.

25. The method of claim 23 wherein from about 500 ppm to about 1500 ppm of the composition, based on polymer actives, is added to the subterranean formation.

26. The method of claim 23 wherein from about 500 ppm to about 1000 ppm of the composition, based on polymer actives, is added to the subterranean formation.

27. The method of claim 23 wherein the composition is added to injection water as part of a secondary or tertiary process for the recovery of hydrocarbon from the subterranean formation.

28. The method of claim 27 wherein the injection water is added to the subterranean formation at a temperature lower than the temperature of the subterranean formation.

29. The method of claim 23 wherein the subterranean formation is a sandstone or carbonate hydrocarbon reservoir.