Abstract: A perforation tool for perforating casing in a borehole. The perforation tool may include a body, charges spaced along an axial length of the body, and a first compartment positioned along the axial length of the body. The compartment may be filled with a diverter material and operable to selectively release the diverter material.

Abstract: Disclosed are systems and methods for receiving surface data and downhole sensor data associated with at least one first hydraulic fracturing well, generating a prediction model for the at least one first hydraulic fracturing well that determines a prediction for a subsurface value for the at least one first hydraulic fracturing well, generating an error model for the at least one first hydraulic fracturing well that determines an estimated prediction error between the prediction for the subsurface value for the at least one first hydraulic fracturing well and an actual subsurface value for the at least one first hydraulic fracturing well, determining a status of at least one feature associated with the estimated prediction error between a prediction for a subsurface value for at least one second hydraulic fracturing well and an actual subsurface value for the at least one second hydraulic fracturing well, and collecting additional downhole sensor data.

Abstract: Aspects of the subject technology relate to systems and methods for controlling a hydraulic fracturing job.

Abstract: Aspects of the subject technology relate to systems and methods for controlling a hydraulic fracturing job. Systems and methods are provided for receiving diagnostics data of a hydraulic fracturing completion of a wellbore, accessing a fracture formation model that models formation characteristics of fractures formed through the wellbore into a formation surrounding the wellbore during the hydraulic fracture completion with respect to surface variables of the hydraulic fracturing completion, selecting one or more subsurface objective functions from a plurality of subsurface objective functions for changing one or more of the formation characteristics of the fractures, and applying the fracture formation model based on the diagnostics data to determine values of the surface variables for controlling the formation characteristics of the fractures to converge on the one or more subsurface objective functions.

Abstract: Aspects of the subject technology relate to systems, methods, and computer-readable media for controlling a hydraulic fracturing job. Diagnostics data of a hydraulic fracturing completion of a wellbore can be received. A fracture formation model that models formation characteristics of fractures formed through the wellbore into a formation surrounding the wellbore during the hydraulic fracturing completion with respect to surface variables can be accessed. A subsurface objective function of fracture complexity can be selected from a plurality of subsurface objective functions for changing one or more of the formation characteristics of the fractures. The fracture formation model can be applied based on the diagnostics data to determine values of the surface variables for controlling the formation characteristics of the fractures to converge on the subsurface objective function of fracture complexity. As follows, a fracture completion plan can be formed based on the values of the surface variables.

Abstract: Aspects of the subject technology relate to systems and methods for controlling a hydraulic fracturing job. Systems and methods are provided for receiving diagnostics data of a hydraulic fracturing completion of a wellbore, accessing a fracture formation model that models formation characteristics of fractures formed through the wellbore into a formation surrounding the wellbore during the hydraulic fracturing completion with respect to surface variables of the hydraulic fracturing completion, selecting one or more subsurface objective functions from a plurality of subsurface objective functions for changing one or more of the formation characteristics of the fractures, the one or more subsurface objective functions including an objective function for wellbore interference, the objective function for wellbore interference including interference information from a neighboring wellbore, and applying the fracture formation model based on the diagnostics data to determine values of the surface variables.

Abstract: A system for downhole wellbore vector strain sensing including a strain sensor positionable between an outer surface of a wellbore casing and a subterranean formation for sensing a plurality of strain tensor elements, the plurality of strain tensor elements comprising multiple components of a strain tensor; a computing device positionable at a surface of a wellbore and communicatively coupled to the strain sensor; and a communication link between the strain sensor and the computing device for communicatively coupling the strain sensor to the computing device to relay strain data, the strain data comprising the plurality of strain tensor elements.

Abstract: A system for downhole wellbore vector strain sensing including a strain sensor positionable between an outer surface of a wellbore casing and a subterranean formation for sensing a plurality of strain tensor elements, the plurality of strain tensor elements comprising multiple components of a strain tensor; a computing device positionable at a surface of a wellbore and communicatively coupled to the strain sensor; and a communication link between the strain sensor and the computing device for communicatively coupling the strain sensor to the computing device to relay strain data, the strain data comprising the plurality of strain tensor elements.

Abstract: A flow rate control sequence for modulating the flow rate at the surface, so as to increase and/or reduce the rate of flow at specific times and increments so that the flow rate of the diverter material downhole is correspondingly reduced or increased such that it enters dominant fractures and avoids entry of marginal fractures. To achieve this, a diversion plan may be developed involving a plurality of planning stages. These stages may include a first overall planning stage, a second downhole planning stage taking into account downhole rate schedule, and the third surface planning stage taking into account parameters at the surface which may impact a diversion plan.

Abstract: A perforation tool for perforating casing in a borehole. The perforation tool may include a body, charges spaced along an axial length of the body, and a first compartment positioned along the axial length of the body. The compartment may be filled with a diverter material and operable to selectively release the diverter material.

Abstract: A first flow distribution to one or more entry points into a subsurface formation may be monitored. Stimulation criteria may be identified based on the first flow distribution. At least one characteristic associated with a first treatment fluid to be injected into a wellbore associated with the subsurface formation may be determined based on the first flow distribution, where the at least one characteristic is based on the stimulation criteria. The subsurface formation may be stimulated with the first treatment fluid and a second flow distribution monitored based on the stimulation. A determination is made whether the second flow distribution meets the stimulation criteria. The subsurface formation may be stimulated with a second treatment fluid based on the determination that the second flow distribution does not meet the stimulation criteria.

Abstract: A flow distribution may be monitored to one or more clusters of perforations. Plugging criteria may be identified based on the flow distribution and characteristics associated with perforation plugs to be dropped into a wellbore associated with the subsurface formation may be determined based on the flow distribution, characteristics of the one or more clusters, and the plugging objective. The perforation plugs may be dropped into the wellbore. The perforation plugs may have tracers which indicate whether the perforation plugs reached a location associated with the one or more clusters.

Abstract: The systems and methods described herein are be used in controlling an injection treatment. An electric pump is used to provide variable modulation of the flow rate of a treatment fluid. Modulating the flow rate in real-time provides pressure diagnostics that can be used to improve fracture growth parameters, wellbore conditions, and well performance. A method of stimulating a wellbore, comprises of injecting, by an electric pump, one or more fluids downhole into the wellbore; producing, based on the one or more injected fluids, one or more fractures that extend from the wellbore into a subterranean formation; receiving, by one or more sensors, one or more measurements; modulating an injection flow rate of the one or more injected fluids; evaluating fracture growth parameters of the one or more fractures; and adjusting fracture complexity of the one or more fractures based on the evaluation of the fracture growth parameters.

Abstract: Aspects of the subject technology relate to systems and methods for controlling a hydraulic fracturing job. A fracturing completion model can be applied to identify a plurality of possible fracturing completion plans for completing one or more wellbores at a target completion. The plurality of possible fracturing completion plans can include varying values of fracturing completion parameters and/or reservoir parameters. Completion characteristic data of the one or more wellbores can be gathered in response to application of at least a portion of a fracturing completion plan of the possible fracturing completion plans. Further, the completion characteristic data can be used to determine whether to apply a different fracturing completion plan of the possible fracturing completion plans. In turn, if it is determined to apply the different fracturing completion plan, then the method can include facilitating switching to the different fracturing completion plan in completing the one or more wellbores.

Abstract: A system and method to determine closure pressure in a wellbore that can include, flowing a fracturing fluid into the wellbore during a fracturing operation of at least one stage and forming a fracture, sensing fluid pressure and a flow rate of the fracturing fluid during the fracturing operation and communicating the sensed data to a controller, plotting data points of the sensed data to a visualization device which is configured to visually present the data points to an operator as a plot, fitting a curve to the data points which represent statistically-relevant minimum pressure data at various flow rates, determining an intercept of the first curve with a zero flow rate axis of the plot, determining the closure pressure based on a pressure value of the intercept, and determining an average fracture permeability based on the closure pressure.

Abstract: System and methods of controlling fluid flow during reservoir stimulation treatments are provided. A flow distribution of treatment fluid injected into formation entry points along a wellbore path is monitored during a current stage of a multistage stimulation treatment. Upon determining that the 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 for diverting the fluid to be injected away from one or more formation entry points between consecutive treatment cycles. A portion of the fluid to be injected into the 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: System and methods of controlling diverter placement during stimulation treatments are provided. Data relating to at least one downhole parameter is obtained for a current treatment stage within a subsurface formation. A response of the diverter to be injected during a diversion phase of the current stage on the downhole parameter is estimated, based on the obtained data and a diagnostic data model. Values for diversion control parameters are calculated, based on the estimated response. As the diverter is injected into the formation, an actual response of the diverter is monitored. Upon determining that a difference between the actual and estimated response exceeds an error tolerance threshold, the model is updated. The model is further updated over subsequent iterations of the diversion phase when the actual response is less than the estimated response. Subsequent diversion phases are performed over a remainder of the current stage, based on the updated model.