System and method for hydraulic fracturing with nanoparticles

Patent metadata

Field	Value
Publication number	US-10060244-B2
Application number	US-201515544221-A
Country	US
Kind code	B2
Filing date	Feb 24, 2015
Priority date	Feb 24, 2015
Publication date	Aug 28, 2018
Grant date	Aug 28, 2018

Abstract

A method for controlling fluid loss into the pores of an underground formation during fracturing operations is provided. Nanoparticles are added to the fracturing fluid to plug the pore throats of pores in the underground formation. As a result, the fracturing fluid is inhibited from entering the pores. By minimizing fluid loss, higher fracturing fluid pressures are maintained, thereby resulting in more extensive fracture networks. Additionally, nanoparticles minimize the interaction between the fracturing fluid and the formation, especially in water sensitive formations. As a result, the nanoparticles help maintain the integrity and conductivity of the generated, propped fractures.

First claim

What is claimed is:

1. A method of hydraulically fracturing a tight formation having a fracturing pressure and an average permeability of 1 millidarcy or less, the method comprising:
a. providing a pad fluid. wherein said pad fluid comprises an aqueous based fluid and a plurality of nanoparticles;
b. injecting said pad fluid into a well having a wellbore to interact with said tight formation at a pressure above said fracturing pressure of said tight formation to open a fracture therein such that a plurality of pores having pore throats are exposed, wherein a portion of said nanoparticles plug one or more of said pore throats of said tight formation to thus limit entry of said pad fluid into said tight formation through said pore throats, and wherein said pore throats have an average diameter from about 1 nanometer to about 100 nanometers, said nanoparticles have an average diameter from about 1 nanometer to about 100 nanometers, and said diameter of said nanoparticles allows said nanoparticles to become lodged in said pore throats to thus plug said pore throats;
c. providing a proppant fluid, wherein said proppant fluid comprises an aqueous based fluid and a plurality of proppants; and
d. injecting said proppant fluid through said wellbore and into said tight formation at a flow rate sufficient to place the proppants into said fracture and to extend the length of said fracture.

2. The method of claim 1 wherein a portion of said proppant fluid combines with a portion of said pad fluid in said tight formation to form a flowback fluid, the method further comprising putting the well on production such that said flowback fluid flows out of said tight formation and such that at least a portion of said nanoparticles dislodge from said pore throats and such that at least a portion of said nanoparticles are carried up said wellbore with said flowback fluid.

3. The method of claim 1 , wherein said pad fluid further comprises a clay-stabilizing agent.

4. The method of claim 1 , wherein said lad fluid farther comprises a micro-proppant.

5. The method of claim 4 , wherein said micro-proppant has a particle size ranging from about 0.1 to about 150 microns in diameter.

6. The method of claim 1 , wherein said pore throats have an average diameter of from about 3 nanometers to about 60 nanometers, and said nanoparticles have a particle size ranging from about 3 nanometers to about 60 nanometers in diameter.

7. The method of claim 1 , wherein said pore throats have an average diameter of from about 5 nanometers to about 30 nanometers, and said nanoparticles have a particle size ranging from about 5 nanometers to about 30 nanometers in diameter.

8. The method of claim 1 , wherein said nanoparticles comprise a material or materials selected from the group consisting of silica, graphene, aluminum, iron, titanium, metal oxides, hydroxides and mixtures thereof.

9. The method of claim 1 , wherein said proppant fluid further comprises nanoparticles.

10. The method of claim 1 , wherein said tight formation is a shale formation.

11. The method of claim 1 , wherein said underground tight formation is a sandstone formation.

12. The method of claim 1 , wherein said pad fluid or said proppant fluid contains a chemical elected from the group consisting of a friction reducing agent, a gelling agent and mixtures thereof.

13. The method of claim 1 , wherein said nanoparticles make up from about 0.01 to about 2 grams of nanoparticles per 100 milliliters of said pad fluid.

14. The method of claim 1 , wherein said nanoparticles have at least one flat face to thereby cover said pore throats and inhibits entry of said pad fluid into said pores of said tight formation.

15. The method of claim 1 , further comprising creating a nanoparticle slurry and mixing said nanoparticle slurry and said pad fluid using mixing equipment.

16. The method of claim 1 , wherein the pad fluid or said proppant fluid is introduced into said tight formation using one or more pumps.

17. The method of claim 1 , wherein the proppants have a particle size ranging from about 155 microns to about 1,200 microns in diameter.

18. The method of claim 17 and wherein a portion of said proppant fluid combines with said a portion if said pad fluid in said tight formation to form a flowback fluid, and the method further comprises putting the well on production such that said flowback fluid flows out of said tight formation and such that at least a portion of said nanoparticles dislodge from said pore throats and such that at least a portion of said nanoparticles are carried up said wellbore with said flowback fluid.

19. The method of claim 18 , wherein said nanoparticles make up from about 0.01 to about 2 grams of nanoparticles per 100 millileters of said pad fluid.

20. A method of hydraulically fracturing a tight formation having a fracturing pressure and an average permeability of 1 millidarcy or less, the method comprising:
a. providing a pad fluid having a pressure, wherein said pad fluid comprises an aqueous based fluid, microproppants, first nanoparticles, and a tackifying agent;
b. injecting said pad fluid into a well having a wellbore to interact with said tight formation at a pressure above said fracturing pressure of said tight formation to open a fracture therein such that a plurality of pores having pore throats are exposed, wherein a portion of said nanoparticles plug one or more said pore throats of said tight formation to thus limit entry of said pad fluid into said tight formation through said pores, and wherein said pore throats have an average diameter from about 1 nanometer to about 100 nanometers, said nanoparticles have an average diameter from about 1 nanometer to about 100 nanometers, and said diameter of said nanoparticles allows said nanoparticles to become lodged in said pore throats to thus plug said pore throats;
c. providing a proppant fluid, wherein said proppant fluid comprises an aqueous based fluid, proppants and second nanoparticles;
d. injecting said proppant fluid through said wellbore and into said tight formation at a flow rate sufficient to place the proppants into said fracture and to extend the length of said fracture and wherein said proppant fluid combines with said pad fluid in said tight formation to form a flowback fluid;
e. putting the well on production such that said flowback fluid flows out of said tight formation and such that at least a portion of said first and second nanoparticles dislodge from said pore throats and such that at least a portion of said first and second nanoparticles are carried up said wellbore with said flowback fluid; and
wherein said first and second nanoparticles are selected from the group consisting of: silica, graphene, aluminum, iron, titanium, metal oxides, hydroxides and mixtures thereof; said first nanoparticles make up from about 0.01to about 2 grams of nanoparticles per 100 milliliters of said pad fluid; said first and second nanoparticles have at least one flat face to thereby cover said pore throats and inhibit the movement of said pad fluid into said pores of said tight formation; and said microproppants have a particle size from about 155 microns to about 1,200 microns in diameter.

Assignees

• Halliburton Energy Services Inc

Inventors

• Nguyen Philip D
• Hampton Jesse Clay

Classifications

• E21B43/267 Primary

  reinforcing fractures by propping · CPC title

• C09K8/665

  containing inorganic compounds (proppants C09K8/80) · CPC title

• C09K8/80

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

• C09K2208/10

  Nanoparticle-containing well treatment fluids · CPC title

• C09K2208/28

  Friction or drag reducing additives · CPC title