Wellbore servicing compositions and methods of making and using same

Patent metadata

Field	Value
Publication number	US-2016145486-A1
Application number	US-201314901855-A
Country	US
Kind code	A1
Filing date	Jul 31, 2013
Priority date	Jul 31, 2013
Publication date	May 26, 2016
Grant date	—

Abstract

A wellbore servicing foam comprising a reducible material and a wellbore servicing material, wherein the wellbore servicing material is uniformly dispersed throughout the foam, and wherein the foam has (i) equal to or greater than 5% reticulated structure and (ii) a specific surface area of from about 0.1 m 2 /g to about 1000 m 2 /g as determined by pycnometry. A highly expanded, wellbore servicing foam comprising a reducible material and a wellbore servicing material, wherein the wellbore servicing material is uniformly dispersed throughout the foam, wherein the foam has (i) a percentage expansion of from about 5% to about 6200% when compared to the same amount of the same reducible material in the absence of expansion, (ii) a specific surface area of from about 0.1 m 2 /g to about 1000 m 2 /g as determined by pycnometry, and (iii) equal to or greater than 5% reticulated structure.

First claim

What is claimed is:

1 . A wellbore servicing foam comprising a reducible material and a wellbore servicing material, wherein the wellbore servicing material is uniformly dispersed throughout the foam, and wherein the foam has (i) equal to or greater than 5% reticulated structure and (ii) a specific surface area of from about 0.1 m 2 /g to about 1000 m 2 /g as determined by pycnometry.

2 . (canceled)

3 . The wellbore servicing foam of claim 1 having a pore size of from about 0.1 microns to about 3000 microns.

4 . The wellbore servicing foam of claim 1 having a porosity of from about 10 vol. % to about 99 vol. % based on the total volume of the wellbore servicing foam.

5 . The wellbore servicing foam of claim 1 having a particle size of from about 10 microns to about 12000 microns.

6 . The wellbore servicing foam of claim 1 having a degradation rate that is from about 100% per hour to about 100% per year greater than the degradation rate for the same amount of the same material in the absence of the reticulation.

7 . The wellbore servicing foam of claim 1 wherein the reducible material comprises a frangible material, an erodible material, a dissolvable material, a consumable material, a thermally degradable material, a meltable material, a boilable material, a degradable material, a biodegradable material, an ablatable material, or combinations thereof.

8 . The wellbore servicing foam of claim 1 wherein the reducible material comprises resins, epoxies, rubbers, hardened plastics, phenolic materials, polymeric materials, degradable polymers, composite materials, metallic materials, metals, metal alloys, cast materials, ceramic materials, ceramic based resins, composite materials, resin composite materials, or combinations thereof.

9 .- 13 . (canceled)

14 . The wellbore servicing foam of claim 8 wherein the degradable polymer comprises at least one aliphatic polyester selected from the group consisting of: polylactic acid, polyglycolic acid, and any combination thereof.

15 . (canceled)

16 . The wellbore servicing foam of claim 1 wherein the wellbore servicing material is present in the wellbore servicing foam in an amount of from about 5 wt. % to about 95 wt. % based on the total weight of the wellbore servicing foam.

17 . A wellbore servicing fluid comprising (i) a wellbore servicing foam having equal to or greater than 5% reticulated structure and (ii) an aqueous base fluid.

18 . The wellbore servicing fluid of claim 17 , wherein the wellbore servicing foam comprises a reducible material and a wellbore servicing material, wherein the wellbore servicing material is uniformly dispersed throughout the foam, and wherein the foam has a specific surface area of from about 0.1 m 2 /g to about 1000 m 2 /g as determined by pycnometry.

19 . The wellbore servicing fluid of claim 17 wherein the density of the wellbore servicing foam is about equal to the density of the wellbore servicing fluid.

20 .- 21 . (canceled)

22 . The wellbore servicing fluid of claim 17 further comprising a particulate material.

23 . The wellbore servicing fluid of claim 22 wherein the particulate material is present in the wellbore servicing fluid in an amount of from about 0.1 ppg to about 30 ppg based on the total volume of the wellbore servicing fluid.

24 . The wellbore servicing fluid of claim 22 wherein the wellbore servicing foam is present in the wellbore servicing fluid in an amount of from about 0.01 wt. % to about 100 wt. % based on the total weight of the particulate material.

25 . (canceled)

26 . The wellbore servicing fluid of claim 17 further comprising a viscosifying agent.

27 . A method of servicing a wellbore in a subterranean formation comprising:
preparing a wellbore servicing fluid comprising a wellbore servicing foam having equal to or greater than 5% reticulated structure, a particulate material and an aqueous base fluid; placing the wellbore servicing fluid in the wellbore and/or subterranean formation; and allowing the reticulated material to degrade therein, wherein the degradation of the reticulated material yields a particulate material pack structure comprising a particulate material pack flow channel space.

28 . The method of claim 27 wherein the wellbore servicing foam comprises a reducible material and a wellbore servicing material, wherein the wellbore servicing material is uniformly dispersed throughout the foam, and wherein the foam has a specific surface area of from about 0.1 m 2 /g to about 1000 m 2 /g as determined by pycnometry.

29 . The method of claim 28 wherein the reducible material comprises polylactic acid and the wellbore servicing material comprises a breaker.

30 . The method of claim 27 wherein the particulate material pack flow channel space is from about 10% to about 60% greater than the particulate material pack flow channel space that would be created by the same amount of particulate material in the absence of the wellbore servicing foam.

31 .- 47 . (canceled)

Assignees

• Halliburton Energy Services Inc

Inventors

• Weaver Jim D
• Mccabe Michael A
• Morgan Ronnie G

Classifications

• C09K8/703 Primary

  Foams · CPC title

• C09K2208/32

  Anticorrosion additives · CPC title

• C09K8/38

  Gaseous or foamed well-drilling compositions · CPC title

• C09K8/72

  Eroding chemicals, e.g. acids · CPC title

• C09K8/57

  Compositions based on water or polar solvents (C09K8/565 takes precedence) · CPC title