Heterogeneous proppant placement in a fracture with removable channelant fill
A method of heterogeneous proppant placement in a subterranean fracture is disclosed. The method comprises injecting well treatment fluid including proppant ( 16 ) and proppant-spacing filler material called a channelant ( 18 ) through a wellbore ( 10 ) into the fracture ( 20 ), heterogeneously placing the proppant in the fracture in a plurality of proppant clusters or islands ( 22 ) spaced apart by the channelant ( 24 ), and removing the channelant filler material ( 24 ) to form open channels ( 26 ) around the pillars ( 28 ) for fluid flow from the formation ( 14 ) through the fracture ( 20 ) toward the wellbore ( 10 ). The proppant and channelant can be segregated within the well treatment fluid, or segregated during placement in the fracture. The channelant can be dissolvable particles, initially acting as a filler material during placement of the proppant in the fracture, and later dissolving to leave the flow channels between the proppant pillars. The well treatment fluid can include fibers to provide reinforcement and consolidation of the proppant and, additionally or alternatively, to inhibit settling of the proppant in the treatment fluid.
1. A method, comprising:
introducing a well treatment fluid comprising proppant and fiber through a wellbore and into a fracture in a subterranean formation; and
forming a plurality of proppant clusters comprising proppant and fiber in the fracture;
wherein the fiber consolidates the proppant into clusters, and
wherein the fiber degrades.
2. The method of claim 1 , wherein the fiber degrades by softening, dissolving, or reacting, and wherein the fiber degrades after proppant placement in the fracture.
3. The method of claim 2 , wherein the fiber degradation enables fluid flow from the formation through the fracture toward the wellbore.
4. The method of claim 1 , wherein the fiber comprises at least one of:
a solid acid-precursor capable of generating acid in the fracture, and,
a solid base-precursor capable of generating a base in the fracture.
5. The method of claim 1 , wherein the fiber is capable of generating acid in the fracture.
6. The method of claim 1 , wherein the wellbore is a vertical wellbore, a wellbore deviated at any angle relative a vertical wellbore, or any combination of both.
7. The method of claim 1 , wherein the method is repeated at another fracture in the wellbore.
8. The method of claim 1 , wherein the proppant clusters are placed in transverse or longitudinal fractures along a wellbore deviated at any angle relative a vertical wellbore.
9. The method of claim 1 , wherein a zone contacted by the treatment fluid in the formation comprises fine grained sedimentary rock formed by consolidation of clay and silt sized particles into thin, relatively impermeable layers.
10. The method of claim 1 , further comprising injecting a fluid comprising fibers in a higher concentration than the well treatment fluid into the fracture.
11. The method of claim 1 , wherein the fiber is a channelant.
12. The method of claim 1 , wherein the fiber is not a channelant during the introducing and forming.
13. A method, comprising:
injecting a well treatment fluid comprising proppant and fiber through a wellbore and into a fracture in a subterranean formation; and
placing the proppant in the fracture in a plurality of proppant clusters,
wherein the fiber reinforces the proppant clusters, and
wherein the fiber is a removable material.
14. The method of claim 13 , wherein the fiber is degraded by softening, dissolving, or reacting, and wherein the degradation occurs after proppant placement in the fracture.
15. The method of claim 13 , wherein the degradation of the fiber further enables fluid flow from the formation through the fracture toward the wellbore.
16. The method of claim 15 , wherein the fiber comprises a solid acid-precursor capable of generating acid in the fracture, a solid base-precursor capable of generating a base in the fracture, or both.
17. The method of claim 15 , wherein the fiber comprises fibers capable of generating acid in the fracture.
18. The method of claim 13 , wherein the wellbore is a vertical wellbore, a wellbore deviated at any angle relative a vertical wellbore, or any combination of both.
19. The method of claim 13 , wherein the method is repeated at another fracture in the wellbore.
20. The method of claim 13 , wherein the proppant clusters are in transverse or longitudinal fractures along a wellbore deviated at any angle relative a vertical wellbore.
21. The method of claim 13 , wherein a zone contacted by the treatment fluid in the formation comprises fine grained sedimentary rock formed by consolidation of clay and silt sized particles into thin, relatively impermeable layers.
22. The method of claim 13 , further comprising injecting a fluid comprising fibers in a higher concentration than the well treatment fluid into the fracture.
23. The method of claim 13 , wherein the fiber is a channelant.
24. The method of claim 23 , wherein the fiber is not a channelant during the introducing and forming.
25. The method of claim 13 , wherein the fiber further maintains a structural integrity of the clusters.
26. The method of claim 13 , wherein the fiber further maintains a separation of the proppant clusters.
27. A method, comprising:
a) constructing a system in a subterranean formation penetrated by a wellbore, comprising:
i. fracturing the subterranean formation;
ii. injecting a well treatment fluid comprising proppant and fiber through a wellbore and into the fracture, wherein the fiber is a degradable material;
iii. placing the proppant in the fracture in a plurality of proppant clusters;
b) producing formation fluids from the formation, through the system of a).
28. The method of claim 27 , wherein the fiber consolidates the proppant clusters.
29. The method of claim 27 , further comprising injecting a fluid comprising fibers in a higher concentration than the well treatment fluid into the fracture.
30. The method of claim 27 , wherein the fiber is a channelant.
31. The method of claim 27 , wherein the fiber is not a channelant during the introducing and forming.