Abstract: A method may comprise identifying one or more pressure dissipation mechanisms that drop pressure within a fluid handling system, identifying one or more open flowpath elements, performing a matching algorithm with an information handling system, and initializing the matching algorithm with an estimate of a coefficient. A system may comprise a fluid handling system and an information handling system. The fluid handling system may comprise a fluid supply vessel, wherein the fluid supply vessel is disposed on a surface, pumping equipment, wherein the pumping equipment is attached to the fluid supply vessel and disposed on the surface; a wellbore supply conduit, wherein the wellbore supply conduit is attached to the pumping equipment and disposed in a formation, and a flowpath element, wherein the flowpath element fluidly couples the wellbore supply conduit to the formation.

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: This disclosure presents processes for mitigating wellbore screen-out. The processes can automatically determine an onset of wellbore screen-out by analyzing corrected pressure data from the at least one pressure sensor, select at least one type of mitigation action based on the automatic determination of the onset of the wellbore screen-out, and mitigate the wellbore screen-out with the selected at least one type of mitigation action.

Abstract: This disclosure presents processes for automatically detecting a ball-seat event in a wellbore. The processes can automatically detect a ball-seat event and automatically fracture a formation at a next treatment zone once the ball-seat event has been automatically detected. The processes for automatically detecting the ball-seat event can determine a volume ratio is in a predetermined range and within a minimum and maximum bound, then determine a slurry rate is in a predetermined range and is within a minimum and maximum bound, then determine a slope of a slurry rate is in a predetermined range and within a minimum and maximum bound, and then determine a slope of a pressure change of the fracturing fluid in the wellbore is in a predetermined range and within a minimum and maximum bound.

Abstract: When a child well is hydraulically fractured near the depleted reservoir volume surrounding a previously produced parent well, it is economically efficient to deliver proppant to the formation volume and fractures not reached by the parent well. A fracture length, which is the distance fluid travels from the child well to the depleted region, is calculated as a function of fracture stage. From identified trends in fracture length, fracture length for future stages can be predicted. Based on predicted fracture length, the slurry or treatment volume to cause well interference can be estimated. Proppant concentration or fracturing stage design can be adjusted so that the well interference volume is larger than the treatment volume and proppant is efficiently delivered to the child well fractures.

Abstract: A workflow for fracturing a subterranean formation includes providing fracturing databases or models for the hydrocarbon wellbore, selecting one or more fracturing fluid systems for fracturing the subterranean formation based on the fracturing databases or models and recommending at least one of the one or more selected fracturing fluid systems for fracturing the subterranean formation. Additionally, a workflow controller for fracturing a subterranean formation includes a workflow processing unit having fracturing models or databases to determine functional aspects of one or more fracturing fluid systems to provide a fracturing fluid system recommendation for the subterranean formation, and a fracturing fluid delivery unit that applies the fracturing fluid system recommendation to the subterranean formation. A hydrocarbon wellbore fracturing system for a subterranean formation is also provided.

Abstract: A method may comprise plotting treatment data to form a plot of the treatment data, fitting a function to the plot of the treatment data, determining an intercept of the function, calculating one or more coefficients, plotting the one or more coefficients on a histogram, and identifying one or more active flowpath elements on the histogram. A system may comprise a fluid handling system and an information handling system. The fluid handling system may comprise a fluid supply vessel, wherein the fluid supply vessel is disposed on a surface; pumping equipment, wherein the pumping equipment it attached to the fluid supply vessel and disposed on the surface; wellbore supply conduit, wherein the wellbore supply conduit is attached to the pumping equipment and disposed in a formation; and a plurality of flowpath elements, wherein the flowpath elements fluidly couple the wellbore supply conduit to the formation.

Abstract: A process to determine whether a leak-off event is occurring during the treatment stage of an active borehole. The leak-off event data, such as the severity or magnitude of the potential leak-off, can be communicated to other systems to adjust the treatment stage, the fluid composition, the fluid pressure, or the fluid flow rate. Diverter material can be added to the fluid. The monitoring of the leak-off event can occur over a time interval, such as the time of the treatment stage and periodic adjustments to the treatment stage can be implemented. The leak-off event can be identified when a fluid pressure slope indicates an overall increase in pressure in an adjacent borehole or if the amount of fluid entering an adjacent borehole exceeds a leak-off threshold.

Abstract: Systems and methods of the present disclosure generally relate to monitoring, evaluating, and controlling fracture geometry during a hydraulic fracturing operation, in real time. A method comprises measuring a signal representing a condition in a wellbore; inputting the signal into a model for estimating a dimension of a dominant fracture; determining the dimension of the dominant fracture; determining a target dimension for the dominant fracture; and minimizing a difference between the dimension of the dominant fracture and the target dimension in real time, by adjusting at least an injection pressure or flow rate of a hydraulic fracturing fluid into the wellbore.

Abstract: A system and method to predict or detect screen outs by measuring pressure conditions in the well in real-time, and that conducts mitigation of the condition. Pressure responses of the well are detected during a fracture operation. The system processes the pressure responses by removing the effects of non-screen out related factors. A mathematical model is applied to the pressure responses to detect or predict the screen out. In response to the screen out detection or prediction, corrective action may be initiated.

Abstract: Systems and methods of the present disclosure generally relate to monitoring, evaluating, and controlling fracture geometry during a hydraulic fracturing operation, in real time. A method comprises measuring a signal representing a condition in a wellbore; inputting the signal into a model for estimating a dimension of a dominant fracture; determining the dimension of the dominant fracture; determining a target dimension for the dominant fracture; and minimizing a difference between the dimension of the dominant fracture and the target dimension in real time, by adjusting at least an injection pressure or flow rate of a hydraulic fracturing fluid into the wellbore.

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: An illustrative hydraulic fracturing flow simulation method includes: identifying a network of fractures within a formation rock matrix; modeling each fracture in the network as fluid flow path having discrete points at which a fluid pressure is determined; representing the rock matrix with discrete nodes at which a fluid-solid interaction force is determined, each said discrete node being associated with multiple discrete points along a fluid flow path; deriving the fluid-solid interaction force for each node from the fluid pressure at the associated discrete points; estimating an extent of fracture propagation based in part on the fluid-solid interaction forces; and displaying a visual representation of the fracture propagation extent.

Abstract: A wellbore fracturing system that includes wellbore fracturing resources coupled through a wellbore conveyance to a subterranean formation of the wellbore; The wellbore fracturing system further includes a bottom hole pressure gauge that provides a bottom hole gauge pressure, and a processor coupled to the wellbore fracturing resources and the wellbore conveyance that calculates a wellbore friction pressure using a time-series sampling of bottom-hole gauge pressures for a fracturing fluid system after a uniform fracturing fluid condition is achieved in the wellbore. Also included are methods of calculating and managing a wellbore friction pressure.

Abstract: This disclosure presents processes to determine whether a leak-off event is occurring during the treatment stage of an active borehole. The leak-off event data, such as the severity or magnitude of the potential leak-off, can be communicated to other systems to adjust the treatment stage, the fluid composition, the fluid pressure, or the fluid flow rate. Diverter material can be added to the fluid. The monitoring of the leak-off event can occur over a time interval, such as the time of the treatment stage and periodic adjustments to the treatment stage can be implemented. The leak-off event can be identified when a fluid pressure slope indicates an overall increase in pressure in an adjacent borehole or if the amount of fluid entering an adjacent borehole exceeds a leak-off threshold.

Abstract: A method of determining fracture complexity may comprise receiving one or more signal inputs from a fracturing operation, calculating an observed fracture growth rate based at least partially on the one or more signal inputs, calculating a predicted fracture growth rate, determining a fracture complexity value, and applying a control technique to make adjustments a hydraulic stimulation operation based at least in part on the fracture complexity value. Also provided is a system for determining a fracture complexity for a hydraulic fracturing operation may comprise a hydraulic fracturing system, a sensor unit to receive one or more signal inputs, a calculating unit, a fracture complexity unit, and a controller unit to apply a control technique to adjust one or more hydraulic stimulation parameters on the hydraulic fracturing system.

Abstract: The disclosure provides a method and a computer program product for determining distribution of fracturing components in fracture clusters of a wellbore, and a fracturing controller. An example of the method includes: (1) modifying surface flow rates for pumping a fracturing component into the wellbore, (2) measuring surface pressures for the surface flow rates, and (3) determining flow rates for the fracture clusters employing the surface flow rates, the surface pressures, and a model representing flow distribution of the wellbore. An example fracturing controller includes (1) an interface configured to receive surface flow rates and corresponding surface pressures for pumping a fracturing component into a wellbore, wherein the surface flow rates are modified in a series of steps, and (2) a processor configured to determine flow rates for the fracture clusters employing the surface flow rates, the surface pressures, and a model representing flow distribution of the wellbore.

Abstract: When a child well is hydraulically fractured near the depleted reservoir volume surrounding a previously produced parent well, it is economically efficient to deliver proppant to the formation volume and fractures not reached by the parent well. A fracture length, which is the distance fluid travels from the child well to the depleted region, is calculated as a function of fracture stage. From identified trends in fracture length, fracture length for future stages can be predicted. Based on predicted fracture length, the slurry or treatment volume to cause well interference can be estimated. Proppant concentration or fracturing stage design can be adjusted so that the well interference volume is larger than the treatment volume and proppant is efficiently delivered to the child well fractures.

Abstract: The disclosure is directed to a method and system that estimates the number of active fractures for a given hydraulic fracturing fluid pressure. The hydraulic fracturing pressure can be correlated to a corresponding hydraulic fracturing fluid absorption rate of downhole fractures. Using the pressure and rate correlation, an active fracture ratio can be determined and then utilized to estimate the number of active fractures at a given hydraulic fracturing fluid pressure. In other aspects, a target fluid pressure is represented by a curve or other shape corresponding to a fluid friction model so that the fluid pressure correlation to the fluid absorption rate can be utilized to compute the active fracture ratio. The disclosed system is operable to control a well site pump system to adjust the fluid pressure and fluid composition, to monitor the downhole fluid, to collect the fluid values, and to compute an estimated active fracture ratio.

Abstract: Systems and methods of the present disclosure generally relate to monitoring, evaluating, and controlling fracture geometry during a hydraulic fracturing operation, in real time. A method comprises measuring a signal representing a condition in a wellbore; inputting the signal into a model for estimating a dimension of a dominant fracture; determining the dimension of the dominant fracture; determining a target dimension for the dominant fracture; and minimizing a difference between the dimension of the dominant fracture and the target dimension in real time, by adjusting at least an injection pressure or flow rate of a hydraulic fracturing fluid into the wellbore.