Foamed treatment fluids comprising nanoparticles

Patent metadata

Field	Value
Publication number	US-2021207021-A1
Application number	US-201817269195-A
Country	US
Kind code	A1
Filing date	Sep 17, 2018
Priority date	Sep 17, 2018
Publication date	Jul 8, 2021
Grant date	—

Abstract

Foamed treatment fluids for use in subterranean formations are provided. In one embodiment, a method of using a foamed treatment fluid comprises: introducing a foamed treatment fluid into a wellbore penetrating at least a portion of a subterranean formation at or above a pressure sufficient to create or enhance one or more fractures in the subterranean formation, wherein the foamed treatment fluid comprises an aqueous base fluid, one or more surfactants, a natural gas, and a plurality of nanoparticles.

First claim

What is claimed is:

1 . A method comprising:
introducing a foamed treatment fluid into a wellbore penetrating at least a portion of a subterranean formation at or above a pressure sufficient to create or enhance one or more fractures in the subterranean formation, wherein the foamed treatment fluid comprises:
an aqueous base fluid,
one or more surfactants,
a natural gas, and
a plurality of nanoparticles.

2 . The method of claim 1 , wherein the plurality of nanoparticles are present in an amount of at least 5% by weight of the foamed treatment fluid.

3 . The method of claim 1 , wherein the plurality of nanoparticles are present in an amount effective to stabilize the foamed treatment fluid.

4 . The method of claim 1 , wherein the foamed treatment fluid comprises a mixture of natural gas and one or more other gases.

5 . The method of claim 1 , wherein the one or more surfactants are present in an amount of from about 0.5 to about 12 gallons per thousand gallons of the foamed treatment fluid.

6 . The method of claim 1 , further comprising forming the foamed treatment fluid by mixing the aqueous base fluid, the one or more surfactants, and the plurality of nanoparticles with the gas in an in-line mixer.

7 . The method of claim 1 , wherein the plurality of nanoparticles comprise at least one material selected from the group consisting of: silica, carbon black, laponite, graphene, aluminum, iron, titanium, a metal oxide, a hydroxide, an alkali earth metal, an alkali earth metal oxide, a transition metal, a transition metal oxide, a post-transition metal, a post-transition metal oxide, and any combination thereof.

8 . The method of claim 1 , wherein the plurality of nanoparticles comprise at least one material selected from the group consisting of: crystalline nanocellulose, chitin, a lignin, a starch, a protein, and any combination thereof.

9 . The method of claim 1 , further comprising the step of allowing the foamed treatment fluid to at least partially degrade.

10 . The method of claim 1 , further comprising depositing at least a portion of the plurality of nanoparticles in one or more fractures or microfractures in the subterranean formation.

11 . The method of claim 1 , wherein the foamed treatment fluid is introduced into the wellbore using one or more pumps.

12 . A foamed treatment fluid comprising:
an aqueous base fluid; one or more surfactants; a plurality of nanoparticles; and natural gas.

13 . The foamed treatment fluid of claim 12 , further comprising a petroleum distillate.

14 . The foamed treatment fluid of claim 12 , wherein the natural gas is present in the foamed treatment fluid in an amount in the range of from about 20% to about 80% by volume.

15 . The foamed treatment fluid of claim 12 , wherein the one or more surfactants are present in an amount of from about 0.5 to about 12 gallons per thousand gallons of the foamed treatment fluid.

16 . The foamed treatment fluid of claim 12 , further comprising a proppant material.

17 . The foamed treatment fluid of claim 12 , further comprising a micro-proppant material.

18 . A method comprising:
introducing a first foamed treatment fluid into a wellbore penetrating at least a portion of a subterranean formation at or above a pressure sufficient to create or enhance at least one fracture in the subterranean formation, wherein the first foamed treatment fluid comprises
a first gas, a first aqueous base fluid, one or more first surfactants, and a first plurality of nanoparticles;
introducing a second treatment fluid into the wellbore at or above a pressure sufficient to create or enhance at least one microfracture in the subterranean formation, wherein the second treatment fluid comprises
a second gas, a second aqueous base fluid, a second plurality of nanoparticles, and a micro-proppant material; and
introducing a third foamed treatment fluid into the wellbore, wherein the third foamed treatment fluid comprises
a third gas, a third aqueous base fluid, a third plurality of nanoparticles, one or more second surfactants, and a proppant material.

19 . The method of claim 18 , wherein at least one of the first foamed treatment fluid and the second treatment fluid comprise at least one of a hydrolysable in-situ acid generator particle and a hydrolysable in-situ chelating agent generator particle.

20 . The method of claim 18 , wherein at least one of the first gas, the second gas, and the third gas comprises natural gas.

Assignees

• Halliburton Energy Services Inc

Inventors

• Khamatnurova Tatyana V
• Nguyen Philip D
• Dusterhoft Ronald Glen
• An Jun Su

Classifications

• E21B43/2605

  using gas or liquefied gas · CPC title

• C09K8/60

  Compositions for stimulating production by acting on the underground formation · CPC title

• C09K2208/10

  Nanoparticle-containing well treatment fluids · CPC title

• C09K8/80

  Compositions for reinforcing fractures, e.g. compositions of proppants used to keep the fractures open · CPC title

• C09K8/703 Primary

  Foams · CPC title