Abstract: A method for hydraulically fracturing a subterranean formation includes preparing and sending a first command signal from a master controller to a plurality of pumps of a pump system. The first command signal specifies a flow rate output for each in pump to achieve a first target flow rate for a fracturing fluid being injected into the subterranean formation. A pressure of the fracturing fluid injected into the subterranean formation at the first target flow rate is monitored and, based on the pressure, the master controller determines when to increase a flow rate of the fracturing fluid to a second target flow rate. The master controller prepares and sends a second command signal to the plurality of pumps to specify the flow rate output for each pump to achieve the second target flow rate.

Abstract: A method for hydraulically fracturing a subterranean formation includes preparing and sending a first command signal from a master controller to a plurality of pumps of a pump system. The first command signal specifies a flow rate output for each in pump to achieve a first target flow rate for a fracturing fluid being injected into the subterranean formation. A pressure of the fracturing fluid injected into the subterranean formation at the first target flow rate is monitored and, based on the pressure, the master controller determines when to increase a flow rate of the fracturing fluid to a second target flow rate. The master controller prepares and sends a second command signal to the plurality of pumps to specify the flow rate output for each pump to achieve the second target flow rate.

Abstract: Methods including introducing a first high-viscosity treatment fluid (HVTF) into a subterranean formation through an opening and applying incrementally increased fracturing rate steps (IIFRSs) to the first HVTF to create or enhance a dominate fracture, wherein between each IIFRS applied to the first HVTF a downhole pressure slope over time will increase, decline, or stabilize at a first HVTF measured pressure slope. Evaluating the first HVTF measured pressure slope prior to applying a subsequent IIFRS to the first HVTF. Introducing a first low-viscosity treatment fluid (LVTF) through the opening to create or enhance a secondary azimuth fracture extending from the dominate fracture, and performing a first net pressure operation after the first LVTF is introduced.

Abstract: Methods including introducing a high-viscosity treatment fluid into a subterranean formation through an opening and applying incrementally increased fracturing rate steps (IIFRSs) to create or enhance a dominate fracture, wherein between each IIFRS a downhole pressure slope over time will increase, decline, or stabilize at a HVTF measured pressure slope. Further evaluating the HVTF measured pressure slope prior to applying a subsequent IIFRS. Performing a particulate sequence transport operation with a first, second, and third low-viscosity treatment fluid (LVTF), wherein the LVTFs collectively create or enhance at least one near-wellbore secondary azimuth fracture and at least one far-field secondary azimuth fracture extending from the dominate fracture, and further propping the dominate fracture, near-wellbore, and far-field secondary azimuth fractures with the particulates.

Abstract: Methods including isolating a first treatment zone comprising an opening into a subterranean formation. A high-viscosity treatment fluid (HVTF) is introduced through the opening and incrementally increased fracturing rate steps (IIFRSs) are applied to create or enhance a dominate fracture, wherein between each IIFRS a downhole pressure slope over time will increase, decline, or stabilize at a measured pressure slope. The measured pressure slope is evaluated to determine whether an increasing pressure slope, a stabilizing pressure slope, or a declining pressure slope exists to determine whether and when to apply a subsequent IIFRS. The result is increasing a volume of the dominate fracture due to efficient dominate fracturing with generated back pressure until a first maximum fracturing rate is reached.

Abstract: Methods including introducing a first high-viscosity treatment fluid (HVTF) into a subterranean formation through an opening and applying incrementally increased fracturing rate steps (IIFRSs) to the first HVTF to create or enhance a dominate fracture, wherein between each IIFRS applied to the first HVTF a downhole pressure slope over time will increase, decline, or stabilize at a first HVTF measured pressure slope. Evaluating the first HVTF measured pressure slope prior to applying a subsequent IIFRS to the first HVTF. Introducing a first low-viscosity treatment fluid (LVTF) through the opening to create or enhance a secondary azimuth fracture extending from the dominate fracture, and introducing a low-viscosity diversion fluid pill (LVDF) pill through the opening to create a fluidic seal therein.

Abstract: Methods including introducing a first high-viscosity treatment fluid (HVTF) into a subterranean formation through an opening and applying incrementally increased fracturing rate steps (IIFRSs) to the first HVTF to create or enhance a dominate fracture, wherein between each IIFRS applied to the first HVTF a downhole pressure slope over time will increase, decline, or stabilize at a first HVTF measured pressure slope. Evaluating the first HVTF measured pressure slope prior to applying a subsequent IIFRS to the first HVTF. Introducing a first low-viscosity treatment fluid (LVTF) through the opening to create or enhance a secondary azimuth fracture extending from the dominate fracture, and performing a first net pressure operation after the first LVTF is introduced.

Abstract: Methods including introducing a first high-viscosity treatment fluid (HVTF) into a subterranean formation through an opening and applying incrementally increased fracturing rate steps (IIFRSs) to the first HVTF to create or enhance a dominate fracture, wherein between each IIFRS applied to the first HVTF a downhole pressure slope over time will increase, decline, or stabilize at a first HVTF measured pressure slope. Evaluating the first HVTF measured pressure slope prior to applying a subsequent IIFRS to the first HVTF. Introducing a first low-viscosity treatment fluid (LVTF) through the opening to create or enhance a secondary azimuth fracture extending from the dominate fracture, and introducing a low-viscosity diversion fluid pill (LVDF) pill through the opening to create a fluidic seal therein.

Abstract: Methods including isolating a first treatment zone comprising an opening into a subterranean formation. A high-viscosity treatment fluid (HVTF) is introduced through the opening and incrementally increased fracturing rate steps (IIFRSs) are applied to create or enhance a dominate fracture, wherein between each IIFRS a downhole pressure slope over time will increase, decline, or stabilize at a measured pressure slope. The measured pressure slope is evaluated to determine whether an increasing pressure slope, a stabilizing pressure slope, or a declining pressure slope exists to determine whether and when to apply a subsequent IIFRS. The result is increasing a volume of the dominate fracture due to efficient dominate fracturing with generated back pressure until a first maximum fracturing rate is reached.

Abstract: Methods including introducing a high-viscosity treatment fluid into a subterranean formation through an opening and applying incrementally increased fracturing rate steps (IIFRSs) to create or enhance a dominate fracture, wherein between each IIFRS a downhole pressure slope over time will increase, decline, or stabilize at a HVTF measured pressure slope. Further evaluating the HVTF measured pressure slope prior to applying a subsequent IIFRS. Performing a particulate sequence transport operation with a first, second, and third low-viscosity treatment fluid (LVTF), wherein the LVTFs collectively create or enhance at least one near-wellbore secondary azimuth fracture and at least one far-field secondary azimuth fracture extending from the dominate fracture, and further propping the dominate fracture, near-wellbore, and far-field secondary azimuth fractures with the particulates.

Abstract: A multi-layer composite synthetic test bed may be used to model fracture propagation and fracture networks. For example, a fracturing fluid may be introduced into a multi-layer composite synthetic test bed at a pressure and a flow rate sufficient to create a fracture network therein. Then, the fracture network may be analyzed to produce synthetic fracture data, which may be used in a fracture model.

Abstract: A multi-layer composite synthetic test bed may be used to model fracture propagation and fracture networks. For example, a fracturing fluid may be introduced into a multi-layer composite synthetic test bed at a pressure and a flow rate sufficient to create a fracture network therein. Then, the fracture network may be analyzed to produce synthetic fracture data, which may be used in a fracture model.