Abstract: System and methods of controlling fracture growth during multi-well stimulation treatments. The flow distribution of treatment fluid injected into first and second well formation entry points along multiple wellbores is monitored during a current stage of a multi-well, multistage stimulation treatment. Upon determining the fracture growth and/or monitored flow distribution meets a threshold, a remainder of the current stage is partitioned into a plurality of treatment cycles and at least one diversion phase. A portion of the fluid to be injected into the first well and/or second well formation entry points is allocated to each of the treatment cycles of the partitioned stage. The treatment cycles are performed for the remainder of the current stage using the treatment fluid allocated to each treatment cycle, wherein the flow distribution is adjusted so as not to meet the threshold.

Abstract: Aspects of the subject technology relate to systems, methods, and computer-readable media for detecting and marking events that occur during a fracturing operation. Data related to performance of a fracturing operation in a wellbore during performance of a stage of the fracturing operation can be accessed. An event detection algorithm for detecting a specific event during the fracturing operation can be accessed. The event detection algorithm can be applied to the data to determine whether the specific event actually occurs during at least a portion of the stage of the fracturing operation. As follows, an indication of the specific event occurring during the stage of the fracturing operation can generated if it is determined that the specific event actually occurred during the at least a portion of the stage of the fracturing operation.

Abstract: A method of hydraulic fracturing may comprise mixing at least one liquid sand mixture with a fluid to produce a fracturing fluid; and conveying the fracturing fluid to two or more wellbores simultaneously, wherein the wellbores penetrate a subterranean formation.

Abstract: A system comprising engine driven pumps, control units, a rate control algorithm, and a trained algorithmic model. The control units store operation variables for the engine driven pumps. The rate control algorithm includes an instruction set to read the operation variables for the engine driven pumps. The instruction set comprises a trained algorithmic model with a parameter space based on historical operation variables. The trained algorithmic model determines an optimal distribution rate based on an objective. The instruction set generates rate control variables based on the determined optimal distribution rate. Each rate control variable comprises a selected control unit identifier and a rate value. The instruction set distributes each rate control variable based on the selected control unit identifier. The trained algorithmic model determine the optimal distribution rate using an objective that defines a desired mixture between a first fuel and a second fuel.

Abstract: A system for use in hydraulic fracturing of at least one reservoir. The system including at least one pump for injecting a friction modifier into a wellbore, at least one friction modifier controller for controlling an amount of friction modifier channeled through at least one well bore, and at least one injector. The friction modifier controller is configured to monitor at least one of a fluid flow rate and pressure associated with each wellbore, compare the at least one of the fluid flow rate and the pressure with at least one of a desired flow rate and desired pressure, and adjust a friction modifier level for at least one wellbore based on results of the comparison. The injector is configured to control the pump to deliver an amount of a friction modifier into the wellbore based on the friction modifier level.

Abstract: A system comprising engine driven pumps, control units, a rate control algorithm, and a trained algorithmic model. The control units store operation variables for the engine driven pumps. The rate control algorithm includes an instruction set to read the operation variables for the engine driven pumps. The instruction set comprises a trained algorithmic model with a parameter space based on historical operation variables. The trained algorithmic model determines an optimal distribution rate based on an objective. The instruction set generates rate control variables based on the determined optimal distribution rate. Each rate control variable comprises a selected control unit identifier and a rate value. The instruction set distributes each rate control variable based on the selected control unit identifier. The trained algorithmic model determine the optimal distribution rate using an objective that defines a desired mixture between a first fuel and a second fuel.

Abstract: Aspects of the subject technology relate to systems and methods for improving cluster and surface efficiency in hydraulic fracturing by utilizing a stage optimization tool. Systems and methods are provided for receiving one or more perforation parameters of a wellbore, generating a perforation schema based on the one or more perforation parameters, training a stage optimization model based on the perforation schema to generate an optimized perforation schema, estimating a pressure of the wellbore based on the optimized perforation schema, and updating the optimized perforation schema until the estimated pressure is less than a predetermined pressure limit.

Abstract: A method of hydraulic fracturing may comprise mixing at least one liquid sand mixture with a fluid to produce a fracturing fluid; and conveying the fracturing fluid to two or more wellbores simultaneously, wherein the wellbores penetrate a subterranean formation.

Abstract: A method of hydraulic fracturing may comprise mixing at least one liquid sand mixture with a fluid to produce a fracturing fluid; and conveying the fracturing fluid to two or more wellbores simultaneously, wherein the wellbores penetrate a subterranean formation.

Abstract: Creating a fracture network extending from a wellbore into a subterranean formation. The method includes introducing a series of fluids into the fracture network in a subterranean formation, thereby forming a proppant pack in the fracture network. The series of fluids comprise: a microproppant slurry comprising a microproppant having an average diameter less than about 25 microns; a proppant slurry comprising a proppant having an average diameter of about 75 microns to about 500 microns; and a sweep fluid having a microproppant weight percentage by weight of the sweep fluid that is from 0 to about the same of the microproppant weight percentage in the microproppant slurry by weight of the microproppant slurry. The introduction of the microproppant slurry is not immediately followed by introduction of the proppant slurry. The introduction of the proppant slurry is not immediately followed by introduction of the microproppant slurry.

Abstract: A system for use in hydraulic fracturing of at least one reservoir. The system including at least one pump for injecting a friction modifier into a wellbore, at least one friction modifier controller for controlling an amount of friction modifier channeled through at least one well bore, and at least one injector. The friction modifier controller is configured to monitor at least one of a fluid flow rate and pressure associated with each wellbore, compare the at least one of the fluid flow rate and the pressure with at least one of a desired flow rate and desired pressure, and adjust a friction modifier level for at least one wellbore based on results of the comparison. The injector is configured to control the pump to deliver an amount of a friction modifier into the wellbore based on the friction modifier level.

Abstract: A system and method for systemically generating complexity through a formation may include defining a diverter schedule including a set of diverters to be pumped into a wellbore over a duration of time. The system and method may include a first diverter being pumped into the wellbore based on the diverter schedule, the first diverter including matter corresponding to a first mesh value. An onset of pressure response value may be determined using a pressure sensor during or after pumping the first diverter into the wellbore. A next diverter including particles corresponding to a second mesh value may be selected using the onset of pressure response value and the diverter schedule. The next diverter may then pumped into the wellbore.

Abstract: System and methods of controlling fracture growth during multi-well stimulation treatments. The flow distribution of treatment fluid injected into first and second well formation entry points along multiple wellbores is monitored during a current stage of a multi-well, multistage stimulation treatment. Upon determining the fracture growth and/or monitored flow distribution meets a threshold, a remainder of the current stage is partitioned into a plurality of treatment cycles and at least one diversion phase. A portion of the fluid to be injected into the first well and/or second well formation entry points is allocated to each of the treatment cycles of the partitioned stage. The treatment cycles are performed for the remainder of the current stage using the treatment fluid allocated to each treatment cycle, wherein the flow distribution is adjusted so as not to meet the threshold.

Abstract: A method of hydraulic fracturing may comprise mixing at least one liquid sand mixture with a fluid to produce a fracturing fluid; and conveying the fracturing fluid to two or more wellbores simultaneously, wherein the wellbores penetrate a subterranean formation.

Abstract: Systems and methods for treating subterranean formations using proppants. More particularly, the systems and methods use sand or other particles having a wide particle-size distribution as a proppant for treating subterranean formations, including unconventional formations. In some embodiments, the methods comprise: providing a treatment fluid comprising a base fluid and unsieved proppant material; introducing the treatment fluid into a well bore penetrating at least a portion of a subterranean formation; and depositing at least a portion of the unsieved proppant material in at least a portion of the subterranean formation.

Abstract: Methods and systems are disclosed for systemically generating complexity throughout a formation. The system and methods include defining a diverter schedule including a set of diverters to be pumped into a wellbore over a duration of time. A first diverter is pumped into the wellbore based on the diverter schedule, the first diverter including matter corresponding to a first mesh value. An onset of pressure response value is measured using a pressure sensor during or after pumping the first diverter into the wellbore. A next diverter including particles corresponding to a second mesh value is selected using the onset of pressure response value and the diverter schedule. The next diverter then pumped into the wellbore.

Abstract: A method comprises creating a fracture network extending from a wellbore into a subterranean formation; then, introducing a series of fluids into the fracture network in a subterranean formation, thereby forming a proppant pack in the fracture network, wherein the series of fluids comprise: a microproppant slurry comprising a microproppant having an average diameter less than about 25 microns; a proppant slurry comprising a proppant having an average diameter of about 75 microns to about 500 microns; and a sweep fluid having a microproppant weight percentage by weight of the sweep fluid that is from 0 to about the same of the microproppant weight percentage in the microproppant slurry by weight of the microproppant slurry; and wherein introduction of the microproppant slurry is not immediately followed by introduction of the proppant slurry, and wherein introduction of the proppant slurry is not immediately followed by introduction of the microproppant slurry.