Abstract: A method of stimulating fluid production from a well includes defining a candidate stimulation treatment including injection of a slurry comprising acid and proppant, based on measurements of the formation. Fracture propagation and fluid transport in the formation are simulated using particle-in-cell techniques. Etching of rock by the injected acid is simulated. Rock compaction is simulated, including compaction around etched and propped portions of a fracture. A predicted fluid conductivity for acid-stimulated fracture is calculated based on the simulation of fracture geometry and a final stimulation treatment is defined based on the predicted fluid conductivity. An acid-proppant slurry is injected into the formation according to the final stimulation treatment.

Abstract: Design method for hydraulic fracturing of a reservoir is presented that maximize well production rates and minimize proppant flowback. The method comprises employing computer simulators that analyze a fracturing treatment design in the context of well properties, reservoir properties, fluids and proppants, and calculates a critical filtration velocity for a proppant pack. If the fluid flow velocity in the fracture exceeds the critical filtration velocity, there is a risk for proppant flowback. The method is applicable to wells that have not yet been fractured, as well as those that have previously undergone a fracturing treatment.

Abstract: A method for fracturing a subterranean formation, the method comprising injecting a fracturing fluid into a wellbore through the subterranean formation, thereby creating a fracture network in the subterranean formation, the fracturing fluid comprising a proppant and a plurality of polymer fibers having a deflection temperature ranging from about 70° C. to about 150° C. dispersed in a carrier fluid.

Abstract: Embodiments disclosed herein relate to a fluid for use in well treatment having a carrier fluid and a plurality of altered fiber particles having a plurality of defects on a surface of the fiber particles. The fluid may be used for a method of fracturing a subterranean formation. The method includes injecting a fracturing fluid into a wellbore through the subterranean formation, thereby creating a fracture network in the subterranean formation, the fracturing fluid comprising a proppant and a plurality of fibers having a plurality of defects on a surface of the fibers.

Abstract: Embodiments disclosed herein relate to a fluid for use in well treatment having a carrier fluid and a plurality of altered fiber particles having a plurality of defects on a surface of the fiber particles. The fluid may be used for a method of fracturing a subterranean formation. The method includes injecting a fracturing fluid into a wellbore through the subterranean formation, thereby creating a fracture network in the subterranean formation, the fracturing fluid comprising a proppant and a plurality of fibers having a plurality of defects on a surface of the fibers.

Abstract: This method is designed to facilitate the well treatment with the possibilities for non-uniform/heterogeneous proppant placement in the extended and branched fractures produced by hydraulic fracturing. The essence of the method is to inject a proppant-bearing gel into the wellbore drilled into a productive formation. The low-viscosity fracturing fluid is injected into the wellbore together with the gel fluid (simultaneously or in turns). The method also provides for the injection of gas into the proppant-bearing gel and/or the low-viscosity fluid. The gas can be injected upstream of the junction point, at the junction point, or downstream of the junction point of the flows of the proppant-bearing gel and the low-viscosity fluid. The method further provides for the division of the gel fluid into the separate agglomerates with their subsequent injection into the fractures in the subterranean formation to form the proppant structures in the fracture.

Abstract: A method for fracturing a subterranean formation, the method comprising injecting a fracturing fluid into a wellbore through the subterranean formation, thereby creating a fracture network in the subterranean formation, the fracturing fluid comprising a proppant and a plurality of polymer fibers having a deflection temperature ranging from about 70° C. to about 150° C. dispersed in a carrier fluid.

Abstract: This method is designed to facilitate the well treatment with the possibilities for non-uniform/heterogeneous proppant placement in the extended and branched fractures produced by hydraulic fracturing. The essence of the method is to inject a proppant-bearing gel into the wellbore drilled into a productive formation. The low-viscosity fracturing fluid is injected into the wellbore together with the gel fluid (simultaneously or in turns). The method also provides for the injection of gas into the proppant-bearing gel and/or the low-viscosity fluid. The gas can be injected upstream of the junction point, at the junction point, or downstream of the junction point of the flows of the proppant-bearing gel and the low-viscosity fluid. The method further provides for the division of the gel fluid into the separate agglomerates with their subsequent injection into the fractures in the subterranean formation to form the proppant structures in the fracture.

Abstract: The disclosure relates to well systems for producing various fluids, in particular for producing the fluid from the hydrocarbon-bearing formation using hydraulic fracturing. According to the method of hydraulic fracturing of the formation intersected by the wellbore, the wellbore is provided, and the step of injecting the fracturing fluid without proppant to the wellbore is performed to form a fracture in the formation. Then, the step of injecting the fracturing fluid containing a mixture of fine particles and shrinkable polymer fibers is performed and the triggering mechanism is implemented, which causes the shrinkable polymer fibers to shrink, then the flowback of the fracturing fluid is provided and the fracture is cleaned. The provided method allows reducing the impact of the fracturing fluid flow on the proppant pillar geometry, as well as keeping the proppant in a consolidated state inside the agglomerates, pillars, or clogs, and preventing crushing of proppant pillars during the fracture closure.

Abstract: A method for treating a subterranean formation utilizing a composition having a plurality of shrinkable materials. The method of treatment may include providing a hydraulic fracture into the subterranean formation, and injecting a slurry having a plurality of shrinkable materials into a far field. The shrinkable materials may shrink once a threshold is reached.