Methods of zonal isolation and treatment diversion
Methods of treating a subterranean formation penetrated by a well bore, by providing a treatment fluid comprising a blend including a first amount of particulates having a first average particle size between about 3 mm and 2 cm and a second amount of particulates having a second average size between about 1.6 and 20 times smaller than the first average particle size or a second amount of flakes having a second average size up to 10 times smaller than the first average particle size; by introducing the treatment fluid into the well bore; and by creating a plug with the treatment fluid.
1. A method of treating a subterranean formation penetrated by a well bore having a well bore volume, comprising:
providing a treatment fluid comprising a blend including a first amount of particulates having a first average particle size between about 3 mm and 2 cm and a second amount of particulates having a second average size between about 1.6 and 20 times smaller than the first average particle size, wherein the second amount of particulates has a trefoil cross sectional shape having enhanced friction force from about 1000 g to 6000 g per about 30 g to about 50 g of the second amount of particulates;
introducing the treatment fluid into the well bore;
creating a plug with said treatment fluid; and
increasing stability of the created plug with the enhanced friction force of the second amount of particulates.
2. The method of claim 1 , wherein the treatment fluid comprises a carrier fluid, and a viscosifying agent or friction reducer.
3. The method of claim 2 , wherein the carrier fluid is a treatment fluid selected from the group consisting of slickwater, spacer, mutual solvent, flush, formation dissolving fluid, fracturing fluid, scale dissolution fluid, paraffin dissolution fluid, asphaltene dissolution fluid, diverter fluid, water control agent, chelating agent, viscoelastic diverting acid, self-diverting acid, acid, and mixtures thereof.
4. The method according to claim 1 , further comprising removing the plug.
5. The method according to claim 1 , wherein the blend comprises a degradable material, a soluble material, or a meltable material at downhole conditions.
6. The method of claim 5 , wherein the blend comprises the degradable material, and the degradable material is a polylactic acid material.
7. The method according to claim 1 , wherein the treatment fluid further comprises fibers.
8. The method of claim 1 , wherein the introducing of the treatment fluid takes place during a single- or multi-stage fracturing treatment.
9. The method according to claim 1 , wherein the first amount of particulates has an aspect ratio smaller than 5.
10. The method according to claim 1 , wherein the first average particle size is between about 3 mm and 20 mm.
11. The method according to claim 1 , wherein the treatment fluid further comprises a third amount of particulates or flakes having a third average size smaller than the second average size.
12. The method of claim 11 , wherein the treatment fluid further comprises a fourth and a fifth amount of particulates or flakes having a fourth average size smaller than the third average size, and a fifth average size smaller than the fourth average size, respectively.
13. The method according to claim 1 , wherein the treatment fluid is such that a packed volume fraction of the blend exceeds 0.7.
14. A method of treating a subterranean formation of a well bore having a volume, wherein the well bore comprises a casing and at least one hole on said casing, said hole having a diameter, the method comprising:
a. providing a treatment fluid comprising a blend including a first amount of particulates having a first average particle size between about 50 to 100% of said diameter and a second amount of particulates having a second average size between about 1.6 and 20 times smaller than the first average particle size, wherein the second amount of particulates comprises a rod-shaped proppant that has a cross sectional trefoil shape having enhanced friction force from about 1000 g to 6000 g per about 30 g to about 50 g of the second amount of particulates;
b. introducing the treatment fluid into the hole;
c. creating a plug with said treatment fluid in the hole;
d. increasing stability of the created plug with the enhanced friction force of the second amount of particulates; and
e. removing the plug.
15. The method of claim 14 , wherein the first average particle size is between about 3 mm and 2 cm.
16. The method according to claim 14 , wherein the first amount of particulates has an aspect ratio smaller than 5.
17. The method according to claim 14 , wherein the treatment fluid is such that a packed volume fraction of the blend exceeds 0.7.
18. The method according to claim 14 , wherein the blend comprises a degradable material, a soluble material, or a meltable material at downhole conditions.
19. The method of claim 18 , wherein the blend comprises the degradable material, and the degradable material is a polylactic acid material.
20. The method according to claim 14 , wherein the treatment fluid further comprises fibers.
21. The method according to claim 14 , wherein the treatment fluid further comprises a third amount of particulates or flakes having a third average size smaller than the second average size.
22. The method of claim 21 , wherein the treatment fluid further comprises a fourth and a fifth amount of particulates or flakes having a fourth average size smaller than the third average size, and a fifth average size smaller than the fourth average size, respectively.
23. A method of fracturing a subterranean formation of a well bore having a volume, wherein the well bore comprises a casing and at least one hole on said casing, said hole having a diameter, the method comprising:
a. providing a diverting fluid comprising a blend including a first amount of particulates having a first average particle size between about 50 to 100% of said diameter and a second amount of particulates having a second average size between about 1.6 and 20 times smaller than the first average particle size, wherein the second amount of particulates comprises a rod-shaped proppant that has a cross sectional trefoil shape having enhanced friction force from about 1000 g to 6000 g per about 30 g to about 50 g of the second amount of particulates;
b. introducing the diverting fluid into the hole;
c. creating a diverting plug with said diverting fluid in the hole;
d. increasing stability of the created diverting plug with the enhanced friction force of the second amount of particulates;
e. fracturing the subterranean formation by using said diverting plug; and
f. removing the diverting plug.