Wellbore servicing materials and methods of making and using same

Patent metadata

Field	Value
Publication number	US-9725639-B2
Application number	US-201314901785-A
Country	US
Kind code	B2
Filing date	Jul 31, 2013
Priority date	Jul 31, 2013
Publication date	Aug 8, 2017
Grant date	Aug 8, 2017

Abstract

A method of servicing a wellbore in a subterranean formation comprising preparing a wellbore servicing fluid comprising a particulate material, an aqueous base fluid, an oleaginous fluid, and a macromolecular surfactant, and placing the wellbore servicing fluid in the wellbore and/or subterranean formation to consolidate and/or enhance conductivity of at least a portion of the wellbore and/or subterranean formation. A method of servicing a wellbore in a subterranean formation comprising preparing a wellbore servicing fluid comprising a particulate material, an aqueous base fluid, an oleaginous fluid, and a macromolecular surfactant, wherein the particulate material comprises sand, and the macromolecular surfactant comprises a hydrophobically modified polyethyleneimine, and placing the wellbore servicing fluid in the wellbore and/or subterranean formation to consolidate and/or enhance conductivity of at least a portion of the wellbore and/or subterranean formation.

First claim

What is claimed is:

1. A method of servicing a wellbore in a subterranean formation comprising:
preparing a wellbore servicing fluid comprising a particulate material, an aqueous base fluid, an oleaginous fluid, and a macromolecular additive, wherein the macromolecular additive is a hydrophobically modified polyethyleneimine comprising a compound characterized by Structure I:

and wherein R 1 and R 2 can each independently be a C 11 -C 26 alkyl group, a C 4 -C 28 fatty acid, or combinations thereof; the ethyleneimine (—CH 2 CH 2 N—) unit occurs x times with the value of x ranging from about 2 to about 30,000; the ethyleneimine (—CH 2 CH 2 NH—) unit occurs y times with the value of y ranging from about 2 to about 30,000; and “*” represents the remainder of the polymer molecule;
forming an oil-in-water emulsion with the oleaginous fluid discontinuously dispersed throughout a continuous aqueous phase, wherein the oil-in-water emulsion suspends the particulate material within the wellbore servicing fluid during transport and the oil-in-water emulsion is characterized by a particulate material settling velocity of from about 10 −10 m/s to about 10 −2 m/s; and
placing the wellbore servicing fluid in the wellbore and/or subterranean formation to consolidate and/or enhance conductivity of at least a portion of the wellbore and/or subterranean formation.

2. The method of claim 1 wherein the macromolecular additive has a weight average molecular weight of from about 300 Da to about 4,000,000 Da.

3. The method of claim 1 wherein the macromolecular additive is present in the wellbore servicing fluid in an amount of from about 0.1 wt. % to about 5 wt. % based on the total weight of the wellbore servicing fluid.

4. The method of claim 1 wherein the wellbore servicing fluid is a fracturing fluid or a gravel packing fluid.

5. The method of claim 1 wherein the particulate material comprises a proppant, a gravel, or combinations thereof.

6. The method of claim 1 wherein placing the wellbore servicing fluid in the wellbore and/or subterranean formation forms a particulate material pack in a fracture, wherein the particulate material pack comprises a particulate material and a macromolecular additive.

7. The method of claim 6 wherein the volume of the particulate material pack is from about 10% to about 300% greater than the volume of a particulate material pack that would be created by the same amount of particulate material in the absence of the macromolecular additive.

8. The method of claim 6 wherein the wellbore servicing fluid breaks and yields a particulate material pack structure comprising a particulate material pack flow channel space.

9. The method of claim 8 wherein the particulate material pack flow channel space is from about 1% to about 50% greater than a particulate material pack flow channel space that would be created by the same amount of particulate material in the absence of the macromolecular additive.

10. The method of claim 6 wherein the particulate material pack further comprises fines, wherein the fines are retained by interactions with hydrophobic modifications of the macromolecular additive.

11. The method of claim 1 wherein the particulate material is present in the wellbore servicing fluid in an amount of from about 0.1 ppg to about 28 ppg based on the total volume of the wellbore servicing fluid.

12. The method of claim 1 wherein the wellbore servicing fluid further comprises a coupling agent selected from the group consisting of: silanes, vinyl silane, vinyltrichlorosilane, vinyltrimethoxysilane, vinyltriethoxysilane, vinyltris(2-methoxyethoxy)silane, vinyltrisisopropoxysilane, vinyltris(t-butylperoxy)silane, vinyldimethylchlorosilane, vinyldimethylethoxysilane, vinylmethyldichlorosilane, vinylmethyldimethoxysilane, vinylmethyldiethoxysilane, methylvinyldi(N-methylacetylamido)silane, methylvinyldi(5-caprolactam)silane, bis(methyldichlorosilyl)ethane, 2,4,6,8-tetramethyl-2,4,6,8-tetravinyl-cyclotetrasiloxane, 1,3,5-trivinyl-1,3,5-trimethylcyclotrisiloxane, epoxy silanes, 3-glycidoxypropyltrimethoxysilane, 3-glycidoxypropyltriethoxysilane, 3-glycidoxypropyl-methyldiethoxysilane, 3-glycidoxypropylmethyldimethoxysilane, 2-(3,4-epoxycyclohexyl)-ethyltrimethoxysilane, 2-(3,4-epoxycyclohexyl)-ethyltriethoxysilane, amino silanes, N-(3-triethoxysilylpropyl)amine, 3-aminopropylsilanetriol, bis[(3-triethoxysilyl)propyl]amine, N-(3-trimethoxysilylpropyl)amine, bis[(3-trimethoxysilyl)propyl]amine, N-(3-methyldimethoxysilylpropyl)amine, 3-methyldimethoxysilylpropylamine, N-(2-aminoethyl)-3-aminopropyl-trimethoxysilane, N-(2-aminoethyl)-3-aminopropyltriethoxysilane, N-(2-aminoethyl)-3-aminopropylmethyldimethoxysilane, N-(3-trimethoxysilylpropyl)diethylenetriamine, N-(3-methyldimethoxysilylpropyl)diethylenetriamine, methyldimethoxysilylpropylpiperazine, N-3-(trimethoxysilyl)-propylcyclohexylamine, N-3-(methyldimethoxysilyl)-propylcyclohexylamine, N-(trimethoxysilylmethyl) aniline, N-(triethoxysilylmethyl)aniline, N-(3-trimethoxysilyl-propyl)aniline, N-(3-triethoxysilylpropyl)aniline, diethylaminomethyltriethoxysilane, diethyl-aminomethylmethyldiethoxysilane, 3-(trimethoxysilylpropyl)diethylamine, 3-(N,N-dimethyl-aminopropyl)-aminopropyl-methyldimethoxysilane, sulfur silanes, ureido silanes, isocyanate silanes, mercapto silanes, methacryloxy silanes, chloro silanes, alkyl silanes, alkoxy silanes, oximino silanes, acetoxy silanes, phenyl silanes, silazanes, siloxanes, silanols, or combinations thereof.

Assignees

• Halliburton Energy Services Inc

Inventors

• Vo Loan
• Liang Feng
• Tang Tingji
• Nguyen Philip D

Classifications

• C09K8/26

  Oil-in-water emulsions · CPC title

• C09K8/885

  obtained otherwise than by reactions only involving carbon-to-carbon unsaturated bonds · CPC title

• C09K8/602

  containing surfactants · CPC title

• C09K8/68 Primary

  containing organic compounds · CPC title

• C09K8/88

  macromolecular compounds · CPC title