Fractures treatment

1. A method to treat a subterranean formation penetrated by a wellbore, comprising:

injecting a treatment fluid into the subterranean formation to form a hydraulic fracture system, wherein the treatment fluid comprises:

a viscosified carrier fluid having a viscosity above 50 mPa-s at a shear rate of 170 s-1 and a temperature of 25° C.;

proppant dispersed in the carrier fluid; and

a fiber comprising polylactic acid and non-crosslinked silicones dispersed in the carrier fluid.

2. The method of claim 1 , further comprising injecting a pre-pad, pad, tail or flush stage or a combination thereof.

3. The method of claim 1 , wherein the treatment fluid comprises from 0.06 to 1.8 kg/L of the proppant based on the total volume of the carrier fluid (from 0.5 to 15 ppa, pounds proppant added per gallon of carrier fluid).

4. The method of claim 1 , wherein the treatment fluid comprises fibers at a concentration below 4.8 g/L of the fibers based on the total volume of the carrier fluid (less than 40 ppt).

5. A method of placing a proppant pack into a fracture formed in a subterranean formation, the method comprising:

injecting a treatment fluid comprising proppant and a fiber comprising polylactic acid and non-crosslinked silicones in a linear gel;

allowing dispersion of the fiber in the linear gel before crosslinking of the treatment fluid;

placing the proppant in the fracture in a plurality of proppant clusters forming pillars spaced apart; and,

removing the fiber to form open channels around the pillars for fluid flow from the formation through the fracture toward the wellbore;

wherein the treatment fluid comprises alternating volumes of proppant-rich fluid and proppant-lean fluid.

6. The method of claim 5 , wherein the fiber comprises degradable fibers.

7. The method of claim 5 , wherein the injection comprises:

injecting a proppant-lean carrier stage to initiate the fracture; and

thereafter injecting into the fracture proppant and the fiber.

8. The method of claim 5 , wherein the solid proppant-rich substages and the proppant-lean substages in the treatment stage fluid have an overall volumetric ratio from 60:40 to 95:5.

9. A method to treat a subterranean formation penetrated by a wellbore, comprising:

injecting a treatment fluid, comprising a particulate and at least a fiber comprising polylactic acid and non-crosslinked silicones in a linear gel;

allowing dispersion of the fiber in the linear gel before crosslinking of the treatment fluid;

alternatingly injecting solid particulate-rich and solid particulate-lean substages of the treatment fluid stage into the fracture, wherein a volume of each of the solid particulate-rich substages is larger than a respective volume of an adjacent one of the solid particulate-lean substages to form a plurality of solid particulate-rich island regions in the fracture and an interconnected network of open channel regions between the island regions, wherein the particulate-rich substages comprise the fiber;

channelizing the particulate-rich island regions in situ in the fracture to form particulate clusters within the island regions separated from adjacent particulate clusters by open voids in the island regions;

reducing pressure in the fracture to close the fracture onto the island regions; and

hydraulically conducting fluid flow through the open channel regions between the formation and the wellbore.

10. The method of claim 9 , wherein the solid particulate-rich substages each comprise alternating pulses injected at different rates.

11. The method of claim 9 , wherein the fiber comprises an ester and the method further comprises releasing an acid from the ester.

12. A system to treat a fracture interval of a formation penetrated by a wellbore, comprising:

a subterranean formation penetrated by a wellbore;

a treatment fluid stage disposed at least partially in the wellbore, the treatment fluid stage comprising solid particulate-rich and solid particulate-lean substages, wherein a volume of each of the solid particulate-rich substages is equal or larger than a respective volume of an adjacent one of the solid particulate-lean substages to form a plurality of solid particulate-rich island regions in the fracture and an interconnected network of open channel regions between the island regions;

the solid particulate-rich substages each comprising alternating pulses comprising a substantially uniform distribution of one or more components in the alternate pulses and a heterogeneous distribution between alternate pulses of at least one other component to channelize the particulate-rich island regions in situ in the fracture to form particulate clusters within the island regions separated from adjacent particulate clusters by open voids within the island regions;

a pump system to inject the treatment fluid stage from the wellbore to the formation at a pressure above fracturing pressure to inject the treatment fluid stage into a fracture in the formation; and

a shut in system to close the fracture onto the solid particulate-rich island regions wherein at least the particulate-rich substages comprise fibers comprising polylactic acid and non-crosslinked silicones dispersed in a linear gel.