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: 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 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: The disclosure presents a technique for determining how downhole material will be distributed among two or more active perforation clusters in a hydraulic fracturing well system. The determination can be conducted during the execution of a treatment stage allowing modifications prior to completion of the treatment stage. The technique utilizes a three-step process where a first step can determine a predictive model of the wellbore, such as subterranean formation properties, wellbore properties, and target goal of the treatment stage. A second step can calibrate for unknown parameters, such as downhole HF fluid pressure at the active perforation clusters and downhole HF fluid flow rate at the perforation clusters. A third step can predict how downhole material will be distributed to the active perforation clusters and fracture clusters. The prediction result can be utilized to modify a pumping plan of the treatment stage to better achieve the targeted goal.

Abstract: The disclosure presents a process for calibrating a diversion model for a treatment stage of a hydraulic fracturing well site. The process can pump a portion of the proppant into the wellbore, flush the wellbore with clean HF fluid, and then perform a diagnostic test to determine a near-wellbore (NWB) flow resistance parameter. Next, diverter material can be distributed into the wellbore and the amount of diverter material delivered to each active perforation cluster can be estimated. A second diagnostic test can be performed followed by computing diversion model parameters such as a near-wellbore zone length parameter for perforation clusters capable of receiving HF fluid. In another aspect, a system is disclosed that can direct operations of a well site pump and collect data from surface and downhole diagnostic sensors, and then use the collected data for the diversion model calibration process.

Abstract: System and methods of optimizing proppant placement for stimulation treatments are provided. Properties of a reservoir formation and a treatment fluid to be injected into the formation are determined for a multistage stimulation treatment to be performed along a wellbore drilled within the formation. A proppant transport model uses the properties to determine a proppant profile for a fractured area of the formation for each treatment stage along the wellbore. A proppant pack conductivity for each stage is determined based on a proppant conductivity model and the proppant profile for that stage. A rate of hydrocarbon production expected from the wellbore is estimated based on a well production model and the proppant pack conductivity. A distribution of proppant to be injected into the formation during the treatment is determined, based on the production rate and one or more constraints. The stimulation treatment is performed based on the determined proppant distribution.

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: 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: System and methods of optimizing proppant placement for stimulation treatments are provided. Properties of a reservoir formation and a treatment fluid to be injected into the formation are determined for a multistage stimulation treatment to be performed along a wellbore drilled within the formation. A proppant transport model uses the properties to determine a proppant profile for a fractured area of the formation for each treatment stage along the wellbore. A proppant pack conductivity for each stage is determined based on a proppant conductivity model and the proppant profile for that stage. A rate of hydrocarbon production expected from the wellbore is estimated based on a well production model and the proppant pack conductivity. A distribution of proppant to be injected into the formation during the treatment is determined, based on the production rate and one or more constraints. The stimulation treatment is performed based on the determined proppant distribution.

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: 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 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: 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: The disclosure presents a technique for determining how downhole material will be distributed among two or more active perforation clusters in a hydraulic fracturing well system. The determination can be conducted during the execution of a treatment stage allowing modifications prior to completion of the treatment stage. The technique utilizes a three-step process where a first step can determine a predictive model of the wellbore, such as subterranean formation properties, wellbore properties, and target goal of the treatment stage. A second step can calibrate for unknown parameters, such as downhole HF fluid pressure at the active perforation clusters and downhole HF fluid flow rate at the perforation clusters. A third step can predict how downhole material will be distributed to the active perforation clusters and fracture clusters. The prediction result can be utilized to modify a pumping plan of the treatment stage to better achieve the targeted goal.

Abstract: The disclosure presents a process for calibrating a diversion model for a treatment stage of a hydraulic fracturing well site. The process can pump a portion of the proppant into the wellbore, flush the wellbore with clean HF fluid, and then perform a diagnostic test to determine a near-wellbore (NWB) flow resistance parameter. Next, diverter material can be distributed into the wellbore and the amount of diverter material delivered to each active perforation cluster can be estimated. A second diagnostic test can be performed followed by computing diversion model parameters such as a near-wellbore zone length parameter for perforation clusters capable of receiving HF fluid. In another aspect, a system is disclosed that can direct operations of a well site pump and collect data from surface and downhole diagnostic sensors, and then use the collected data for the diversion model calibration process.

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: Methods for growing a reduced dislocation crystal ingot in an ingot growing system are disclosed. The system has a first crucible with a first base and a first sidewall extending upward from the first base to define an outer cavity. The method includes placing a weir in the outer cavity, placing a second crucible on the weir, placing feedstock material into the outer cavity, and melting the feedstock material to allow movement of the melt from the outer cavity inward of an intermediate cavity and into an inner cavity.

Abstract: Production of silicon ingots in a crystal puller that involve reduction in the formation of silicon deposits on the puller exhaust system are disclosed.

Abstract: Production of silicon ingots in a crystal puller that involve reduction of the erosion rate at the crucible contact point are disclosed.

Abstract: Methods for growing single crystal ingots doped with volatile dopants and ingots grown according to the methods are described herein.