Abstract: Methods include designing and performing hydraulic fracturing treatments that utilize tube wave analysis by a combination of a flow rate splitting simulator and a multilayer fracturing (MLF) simulator to optimize treatment design parameters. Methods may also be directed to monitoring, controlling, evaluating and improving hydraulic fracturing treatments in real-time.

Abstract: The present disclosure relates to a method for stimulating a subterranean formation that includes performing an initial stimulation in a wellbore positioned within the subterranean formation to place a designed volume of a first proppant in fractures, determining a near wellbore fracture width of the fractures, determining an unpropped fracture length of the fractures based on a rock bending model, determining an unpropped fracture volume based on the unpropped fracture length and near wellbore width of the fractures and performing a second stimulation treatment to place a proppant in fractures in an amount equal to the unpropped fracture volume. This operation allows to restore the conductivity of fracture in the damaged zone.

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: The present disclosure relates to a method for stimulating a subterranean formation that includes performing an initial stimulation in a wellbore positioned within the subterranean formation to place a designed volume of a first proppant in fractures, determining a near wellbore fracture width of the fractures, determining an unpropped fracture length of the fractures based on a rock bending model, determining an unpropped fracture volume based on the unpropped fracture length and near wellbore width of the fractures and performing a second stimulation treatment to place a proppant in fractures in an amount equal to the unpropped fracture volume. This operation allows to restore the conductivity of fracture in the damaged zone.

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 of predicting hydraulic fracturing and associated risks of hydraulic fracturing operation is proposed. The methods use the mathematical simulation which allow to predict the geometry of a hydraulic fracture and location of fluids, propping agents (proppant), fibers and other materials therein. Reconsidering the fracturing design allows to remedy the possible risks (overflush, screen-out, bridging, gel contamination, temperature effects).

Abstract: Methods include designing and performing hydraulic fracturing treatments that utilize tube wave analysis by a combination of a flow rate splitting simulator and a multilayer fracturing (MLF) simulator to optimize treatment design parameters. Methods may also be directed to monitoring, controlling, evaluating and improving hydraulic fracturing treatments in real-time.

Abstract: Methods may include using geometrical and mechanical properties to generate a model of one or more intervals of a wellbore; designing a fluid pumping schedule for a wellbore treatment fluid system; simulating flow of a fluid system containing solids using the model of the one or more intervals of the wellbore, wherein simulating comprises determining the flow rate distribution within the wellbore and modeling the settling and resuspension of the solids within the flow of the fluid system; and updating the fluid pumping schedule based on the output determined from the simulated flow of the fluid system. Methods may also include determining the critical velocity of the fluid system for various concentrations of one or more of solids and additives; and selecting the concentration of the one or more of solids and additives based on the critical velocities determined.

Abstract: A method of stimulating the inflow of oil and/or gas from the wellbore, in particular, a hydraulic fracturing method, is disclosed. The method of hydraulic fracturing comprises the stages: injecting a slug of a proppant-free fluid through the well into a formation for hydraulic fracture creation and propagation; injecting a slug of proppant-laden slurry into the formation to create a proppant pack in the hydraulic fracture; injecting a slug of slurry that contains a fluid and the polyelectrolyte complex-based proppant aggregates to create permeable channels in the near-wellbore area of the hydraulic fracture; injecting a slug of a displacement fluid into the well. This sequence of operations allows avoiding the proppant slurry overdisplacement deep into the hydraulic fracture, maintaining high fracture conductivity, and increasing the well productivity.

Abstract: Methods may include using geometrical and mechanical properties to generate a model of one or more intervals of a wellbore; designing a fluid pumping schedule for a wellbore treatment fluid system; simulating flow of a fluid system containing solids using the model of the one or more intervals of the wellbore, wherein simulating comprises determining the flow rate distribution within the wellbore and modeling the settling and resuspension of the solids within the flow of the fluid system; and updating the fluid pumping schedule based on the output determined from the simulated flow of the fluid system. Methods may also include determining the critical velocity of the fluid system for various concentrations of one or more of solids and additives; and selecting the concentration of the one or more of solids and additives based on the critical velocities determined.

Abstract: A method of stimulating the inflow of oil and/or gas from the wellbore, in particular, a hydraulic fracturing method, is disclosed. The method of hydraulic fracturing comprises the stages: injecting a slug of a proppant-free fluid through the well into a formation for hydraulic fracture creation and propagation; injecting a slug of proppant-laden slurry into the formation to create a proppant pack in the hydraulic fracture; injecting a slug of slurry that contains a fluid and the polyelectrolyte complex-based proppant aggregates to create permeable channels in the near-wellbore area of the hydraulic fracture; injecting a slug of a displacement fluid into the well. This sequence of operations allows avoiding the proppant slurry overdisplacement deep into the hydraulic fracture, maintaining high fracture conductivity, and increasing the well productivity.

Abstract: According to the claimed method, fracturing fluid is injected into a well containing a plurality of perforated intervals to create, and facilitate the propagation of, a hydraulic fracture in at least one of the perforated intervals; then, the suspension containing insoluble degradable material, oppositely charged polyelectrolytes and/or their precursors is injected into the well; at the same time, a degradable viscous phase, non-miscible with fracturing fluid, is formed from the oppositely charged polyelectrolytes and/or their precursors; a degradable plug is formed in at least one of the perforated intervals, fracture, or wellbore; diversion of the fracturing fluid flow to the next perforated interval is provided with subsequent plug degradation in at least one of the perforated intervals, fracture, or wellbore within the required time.