Propping complex fracture networks in tight formations
Generally, methods for propping complex fracture networks in tight subterranean formations may involve introducing a first treatment fluid comprising a first base fluid and a first propping agent having a mean particulate size distribution ranging from about 0.5 microns to about 20 microns into a fracture network in a subterranean formation; and then introducing a second treatment fluid comprising a second base fluid and a second propping agent having a mean particulate size distribution greater than about 35 microns into the fracture network.
1. A method comprising:
introducing a first treatment fluid comprising a first base fluid and a first propping agent having a mean particulate size in the range of from about 0.5 microns to about 20 microns into a fracture in a zone of a subterranean formation; and then
introducing a second treatment fluid comprising a second base fluid and a second propping agent having a mean particulate size in the range of greater than about 35 microns into the fracture.
2. The method of claim 1 further comprising:
introducing a third treatment fluid into the subterranean formation at a pressure sufficient to create or extend at least a portion of a fracture, wherein introduction of the first treatment fluid and the second treatment fluid occur after at least a portion of the fracture is formed.
3. The method of claim 1 , wherein the first treatment fluid and/or the second treatment fluid are introduced at a pressure sufficient to create or extend at least a portion of the fracture.
4. The method of claim 1 , wherein the first treatment fluid and/or the second treatment fluid is foamed.
5. The method of claim 1 , wherein the first treatment fluid and/or the second treatment fluid is a wet gas.
6. The method of claim 1 further comprising:
atomizing the first propping agent into a flow stream comprising the first base fluid before introducing the first treatment fluid into the fracture.
7. The method of claim 1 , wherein the second propping agent comprises a coating that comprises a consolidating agent.
8. The method of claim 1 , wherein the second propping agent is at least partially degradable.
9. The method of claim 1 further comprising:
repeating the steps of introducing the first treatment fluid and introducing the second treatment fluid successively in the fracture.
10. The method of claim 1 further comprising:
repeating the steps of introducing the first treatment fluid and introducing the second treatment fluid successively in a fracture of a second zone of the subterranean formation.
11. The method of claim 1 further comprising:
repeating the steps of introducing the first treatment fluid and then introducing the second treatment fluid in at least a second zone extending from a second wellbore near the wellbore such that the second zone comprises a second fracture that is in close proximity to the first fracture such that formation stress caused by propping one of the first fracture impacts a structure of the second fracture.
12. A method comprising the following steps in order:
isolating a first zone extending from a wellbore in a subterranean formation, the first zone comprising a first fracture;
introducing a first treatment fluid comprising a first base fluid and a first propping agent having a mean particulate size in the range of from about 0.5 microns to about 20 microns into the first fracture;
introducing a second treatment fluid comprising a second base fluid and a second propping agent having a mean particulate size in the range of greater than about 35 microns into the first fracture;
isolating a second zone extending from the wellbore in the subterranean formation, the second zone comprising a second fracture;
introducing a third treatment fluid comprising a third base fluid and a third propping agent having a mean particulate size in the range of from about 0.5 microns to about 20 microns into the second fracture; and
introducing a fourth treatment fluid comprising a fourth base fluid and a fourth propping agent having a mean particulate size in the range of greater than about 35 microns into the second fracture.
13. The method of claim 12 , wherein the first fracture and the second fracture are connected.
14. The method of claim 12 , wherein the first treatment fluid and/or the third treatment fluid is foamed.
15. The method of claim 12 , wherein the first treatment fluid and/or the third treatment fluid is a wet gas.
16. The method of claim 12 further comprising:
atomizing the first propping agent into a flow stream comprising the first base fluid before introducing the first treatment fluid into the fracture.
17. A method comprising the following steps in order:
isolating a first zone extending from a wellbore in a subterranean formation;
introducing a first treatment fluid into the first zone of the subterranean formation at a pressure sufficient to create or extend at least a portion of a first fracture in the first zone;
introducing a second treatment fluid comprising a first base fluid and a first propping agent having a mean particulate size in the range of from about 0.5 microns to about 20 microns into the first fracture; and
introducing a third treatment fluid comprising a second base fluid and a second propping agent having a mean particulate size in the range of greater than about 35 microns into the first fracture.
18. The method of claim 17 further comprising the following steps in order after introducing the third treatment fluid:
isolating a second zone extending from the wellbore in the subterranean formation, the second zone comprising a second fracture;
introducing a fourth treatment fluid comprising a third base fluid and a third propping agent having a mean particulate size in the range of from about 0.5 microns to about 20 microns into the second fracture network; and
introducing a fifth treatment fluid comprising a fourth base fluid and a fourth propping agent having a mean particulate size in the range of greater than about 35 microns into the second fracture network.
19. The method of claim 1 , wherein the first propping agent is substantially spherical.
20. The method of claim 1 , wherein the first propping agent comprises at least one selected from the group consisting of sand, bauxite, ceramic materials, fly ash, silica flour, glass materials, polymer materials, polytetrafluoroethylene materials, nut shell pieces, cured resinous particulates comprising nut shell pieces, seed shell pieces, cured resinous particulates comprising seed shell pieces, fruit pit pieces, cured resinous particulates comprising fruit pit pieces, wood, composite particulates, and combinations thereof.
21. The method of claim 20 , wherein the composite particulates comprise a binder and filler, further wherein the filler comprises at least one selected from the group consisting of silica, alumina, fumed carbon, carbon black, graphite, mica, titanium dioxide, meta-silicate, calcium silicate, kaolin, talc, zirconia, boron, fly ash, carbon nanofibers, cellulosic nanofibers, natural and synthetic nanoclays, hollow glass microspheres, solid glass, and combinations thereof.
22. The method of claim 1 , wherein the second propping agent has a mean particulate size in the range of from about 35 microns to about 800 microns.
23. The method of claim 12 , wherein the first propping agent is substantially spherical.
24. The method of claim 12 , wherein the first propping agent comprises at least one selected from the group consisting of sand, bauxite, ceramic materials, fly ash, silica flour, glass materials, polymer materials, polytetrafluoroethylene materials, nut shell pieces, cured resinous particulates comprising nut shell pieces, seed shell pieces, cured resinous particulates comprising seed shell pieces, fruit pit pieces, cured resinous particulates comprising fruit pit pieces, wood, composite particulates, and combinations thereof.
25. The method of claim 24 , wherein the composite particulates comprise a binder and filler, further wherein the filler comprises at least one selected from the group consisting of silica, alumina, fumed carbon, carbon black, graphite, mica, titanium dioxide, meta-silicate, calcium silicate, kaolin, talc, zirconia, boron, fly ash, carbon nanofibers, cellulosic nanofibers, natural and synthetic nanoclays, hollow glass microspheres, solid glass, and combinations thereof.
26. The method of claim 12 , wherein the second propping agent has a mean particulate size in the range of from about 35 microns to about 800 microns.
27. The method of claim 17 , wherein the first propping agent is substantially spherical.
28. The method of claim 17 , wherein the first propping agent comprises at least one selected from the group consisting of sand, bauxite, ceramic materials, fly ash, silica flour, glass materials, polymer materials, polytetrafluoroethylene materials, nut shell pieces, cured resinous particulates comprising nut shell pieces, seed shell pieces, cured resinous particulates comprising seed shell pieces, fruit pit pieces, cured resinous particulates comprising fruit pit pieces, wood, composite particulates, and combinations thereof.
29. The method of claim 28 , wherein the composite particulates comprise a binder and filler, further wherein the filler comprises at least one selected from the group consisting of silica, alumina, fumed carbon, carbon black, graphite, mica, titanium dioxide, meta-silicate, calcium silicate, kaolin, talc, zirconia, boron, fly ash, carbon nanofibers, cellulosic nanofibers, natural and synthetic nanoclays, hollow glass microspheres, solid glass, and combinations thereof.
30. The method of claim 17 , wherein the second propping agent has a mean particulate size in the range of from about 35 microns to about 800 microns.