Enhancing conductivity of microfractures

Patent metadata

Field	Value
Publication number	US-9896619-B2
Application number	US-201514963036-A
Country	US
Kind code	B2
Filing date	Dec 8, 2015
Priority date	Dec 8, 2015
Publication date	Feb 20, 2018
Grant date	Feb 20, 2018

Abstract

A method of fracturing a subterranean formation and forming a fracture network therein that includes at least one primary fracture and at least one microfracture is provided. A plurality of micro-proppant particulates is mixed with the fracturing fluid and placed in the microfracture, and a plurality of primary proppant particulates are mixed with the fracturing fluid and placed in the primary fracture. The step of mixing the micro-proppant particulates with the fracturing fluid continues for so long as the primary proppant particulates are mixed with the fracturing fluid and the fracturing fluid and primary proppant particulates are pumped into the formation.

First claim

What is claimed is:

1. A method of fracturing a subterranean formation, comprising:
(a) providing a fracturing fluid, said fracturing fluid including a base carrier fluid;
(b) pumping said fracturing fluid into the subterranean formation at a pressure above the fracture gradient of the formation to fracture the formation and form a fracture network therein that includes at least one primary fracture and at least one microfracture;
(c) mixing a plurality of micro-proppant particulates with said fracturing fluid and placing micro-proppant particulates in said microfracture;
(d) mixing a plurality of primary proppant particulates with said fracturing fluid and placing primary proppant particulates in said primary fracture, wherein said step of mixing said micro-proppant particulates with said fracturing fluid is initiated at a point before or after said fracturing fluid is first pumped into said formation but before primary proppant particulates are mixed with said fracturing fluid such that fracturing fluid containing micro-proppant particulates is pumped into said subterranean formation prior to said step of mixing said plurality of primary proppant particulates with said fracturing fluid and wherein said step of mixing micro-proppant particulates with said fracturing fluid continues for so long as said primary proppant particulates are mixed with said fracturing fluid and said fracturing fluid and primary proppant particulates are pumped into the formation, wherein said steps (b), (c) and (d) result in said micro-proppant particulates holding open said microfracture and said primary proppant particulates holding open said primary fracture such that fluid flow through said fracture network is enhanced without plugging of primary-proppant particle packs in said fracture network; and
(e) ceasing pumping of said fracturing fluid into the subterranean formation thereby causing the pressure at which said fracturing fluid is pumped into the foimation to fall below said fracture gradient of the formation.

2. The method of claim 1 , wherein said base carrier fluid of said fracturing fluid is an aqueous-based carrier fluid.

3. The method of claim 1 , wherein said micro-proppant particulates have a D50 particulate size distribution no greater than 30 microns.

4. The method of claim 1 , wherein said micro-proppant particulates are selected from the group consisting of silica flour, glass beads, fly ash, ceramics, bauxite, polymer materials, polymeric composites, mica, and combinations thereof.

5. The method of claim 1 , wherein said primary proppant particulates have a D50 particulate size distribution of at least 35 microns.

6. The method of claim 1 , wherein said primary proppant particulates are selected from the group consisting of sand, walnut hulls, resin pre-coated proppant particulates, man-made proppant particulates, and mixtures thereof.

7. The method of claim 1 , wherein said micro-proppant particulates are mixed with said fracturing fluid in an amount in the range of from about 0.01 pounds to about 1 pound per gallon of said fluid.

8. The method of claim 1 , wherein said primary proppant particulates are mixed with said fracturing fluid in an amount in the range of from about 0.01 pounds to about 6 pounds per gallon of said fluid.

9. A method of fracturing a subterranean formation, comprising:
(a) providing a pad fracturing fluid, said pad fracturing fluid including a base carrier fluid and does not include primary proppant particulates;
(b) pumping said pad fracturing fluid into the subterranean formation at a pressure above the fracture gradient of the formation to fracture the formation and form a fracture network therein that includes at least one primary fracture and at least one microfracture;
(c) mixing a plurality of micro-proppant particulates with said pad fracturing fluid and placing micro-proppant particulates in said microfracture;
(d) providing a proppant slurry, said proppant slurry including a base carrier fluid and a plurality of primary proppant particulates;
(e) pumping said proppant slurry into the subterranean formation at a pressure above the fracture gradient of the formation and placing primary proppant particulates in said primary fracture;
(f) mixing a plurality of micro-proppant particulates with said proppant slurry, wherein said step of mixing micro-proppant particulates with said proppant slurry is initiated at a point before or after said proppant slurry is first pumped into said formation and continues for so long as said proppant slurry is pumped into said formation, wherein said steps Lb), (c), (d), (e) and (f) result in said micro-proppant particulates holding open said microfracture and said primary proppant particulates holding open said primary fracture such that fluid flow through said fracture network is enhanced without plugging of primary-proppant particle packs in said fracture network; and
(g) ceasing pumping of said proppant slurry into the subterranean formation thereby causing the pressure at which said proppant slurry is pumped into the formation to fall below said fracture gradient of the formation.

10. The method of claim 9 , wherein said base carrier fluid of said pad fracturing fluid and said proppant slurry is an aqueous-based carrier fluid.

11. The method of claim 9 , wherein said micro-proppant particulates have a D50 particulate size distribution no greater than 30 microns.

12. The method of claim 9 , wherein said D50 particle size distribution of said micro-proppant particulates mixed with said pad fracturing fluid is greater than the D50 particle size distribution of said micro-proppant particulates mixed with said proppant slurry.

13. The method of claim 9 , wherein said micro-proppant particulates are selected from the group consisting of silica flour, glass beads, fly ash, ceramics, bauxite, polymer materials, polymeric composites, mica, and combinations thereof.

14. The method of claim 9 , wherein said primary proppant particulates have a D50 particulate size distribution of at least 35 microns.

15. The method of claim 9 , wherein said primary proppant particulates are selected from the group consisting of sand, walnut hulls, resin pre-coated proppant particulates, man-made proppant particulates, and mixtures thereof.

16. The method of claim 9 , wherein said micro-proppant particulates are mixed with each of said pad fracturing fluid and said proppant slurry in an amount in the range of from about 0.01 pounds to about 1 pound per gallon of said fluid or slurry.

17. The method of claim 9 , wherein said primary proppant particulates are mixed with said proppant slurry in an amount in the range of from about 0.01 pounds to about 6 pounds per gallon of said slurry.

18. The method of claim 9 , wherein said primary proppant particulates are coated with a consolidating agent, and said method further comprises:
allowing said primary proppant particulates to consolidate in said fracture.

19. The method of claim 9 , wherein said proppant slurry further includes a cross-linkable gelling agent, cross-linker and gel breaker, wherein said proppant slurry is also pumped into the formation in a manner such that said gelling agent cross-links and increases the viscosity of said proppant slurry, and wherein said method further comprises:
allowing said cross-linked gel to break down thereby decreasing the viscosity of said proppant slurry; and
flowing back the well to remove broken gel in said proppant slurry from the formation.

20. The method of claim 9 , wherein said

Assignees

• Halliburton Energy Services Inc

Inventors

• Nguyen Philip D
• Martysevich Vladimir Nikolayevich
• Heeter Jessica Lynn

Classifications

• E21B43/267

  reinforcing fractures by propping · CPC title

• C09K2208/04

  Hulls, shells or bark containing well drilling or treatment fluids · CPC title

• C09K8/685

  containing cross-linking agents · CPC title

• C09K8/80 Primary

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

• C09K2208/26

  Gel breakers other than bacteria or enzymes · CPC title