Systems and methods for modeling dispersion curves are disclosed. The method includes obtaining an acoustic dataset along a well that accesses a hydrocarbon reservoir. The method further includes determining a set of depth windows along the well and determining a first subset of dispersion curves for a first subset of depth windows using a dispersion model. The method still further includes initializing a second subset of dispersion curves for a second subset of depth windows using a nearest neighbor search of the first subset of dispersion curves. The method still further includes determining slowness-frequency pairs for the second subset of depth windows using the acoustic dataset and updating the second subset of dispersion curves using a recursive scanning method. The method still further includes characterizing rock properties near the well based, at least in part, on the first subset of dispersion curves and the second subset of dispersion curves.

Methods and systems for assessing cross-well interference and/or optimizing hydrocarbon production from a reservoir by obtaining low frequency DAS and DTS data and pressure data from a monitor well, when both the monitor and production well are shut-in, and then variably opening the production well for production, and detecting the temperature and pressure fluctuations that indication cross-well interference, and localizing the interference along the well length based on the low frequency DAS data. This information can be used to optimize well placement, completion plans, fracturing plans, and ultimately optimize production from a given reservoir.

A data acquisition program, which includes core, image log, microseismic, DAS, DTS, and pressure data, is described. This program can be used in conjunction with a variety of techniques to accurately monitor and conduct well stimulation.

The present disclosure relates to a fracturing system comprising a functional unit, an electricity supply unit, and an energy storage unit. The functional unit is configured to perform procedures of fracturing operations. The electricity supply unit is electrically connected with the functional unit and is configured to supply electrical energy to the functional unit. The energy storage unit is respectively electrically connected with the electricity supply unit and the functional unit, and is configured to store electrical energy from the electricity supply unit and supply electrical energy to the functional unit.

A method of predicting three-dimensional fracture geometry in a subterranean region of interest is disclosed. The method includes obtaining a strain tensor for the subterranean region of interest, calculating a set of principal strain components from the strain tensor, and determining a strain cyclide from the set of principal strain components. The method further includes calculating a set of quadrimodal fault normal vectors from the strain cyclide and determining an in-plane shear strain magnitude and a shear strain orientation from the set of quadrimodal fault normal vectors.

Some systems and methods of hydraulic fracturing a formation of a borehole include receiving a length-to-radius ratio of a borehole segment of the borehole and determining when the length-to-radius ratio is less than a threshold. Responsive to determining that the length-to-radius ratio is less than the threshold, some systems and methods include predicting a breakdown pressure associated with a formation surrounding the borehole segment based on a length of the borehole segment. Responsive to determining that the length-to-radius ratio is greater than or equal to the threshold, some systems and methods include determining, a characteristic diffusion time associated with a fluid diffusing into the formation surrounding the borehole segment. Some systems and methods include pumping the fluid into the borehole segment to fracture the formation surrounding the borehole segment at the determined breakdown pressure.

A fracture model for a hydraulic fracture in a wellbore can be updated and calibrated. Information about a microseismic event can be received from a sensor that is monitoring a subterranean formation. The information can be received subsequent to a fracking fluid being introduced into the formation. An observed geometry of a hydraulic fracture can be determined based on the information and a predicted geometry of the fracture can be determined based on properties of the fracking fluid and a fracture model. The fracture model can be updated using the information about the microseismic event where it is determined that an uncertainty value of the observed geometry does not exceed a pre-set maximum. The uncertainty value can be based on the predicted geometry of the hydraulic fracture.

A method for treating a well includes hydraulically isolating an interval in a first well having a plurality of intervals along the first well, each interval having been fracture treated. A tube wave is induced in the first well in the isolated interval. Reflections are detected from the induced tube wave. Hydraulic boundary condition and hydraulic conductivity of a fracture connected to the first well in the isolated interval are determined using the detected reflections. A refracture treatment is performed in the isolated interval when the hydraulic boundary condition and the hydraulic conductivity are within a predetermine range.

A method evaluating borehole subsurface geologies can include receiving a total response signal by a sensor array disposed in a borehole, the response signal represents a pressure wave propagating in the borehole. A secondary signal can be extracted from the total response signal and a depth location for at least one secondary source that corresponds to the secondary signal is determined. An estimated reflectivity response for the secondary signal as a function of frequency is determined and the estimated reflectivity response is inverted to determine the secondary source includes at least one of a potential fracture or a potential washout. The at least one of a fracture conductivity or a washout volume for the secondary source is compared to one or more borehole images corresponding to the depth location of the secondary source to determine the potential fracture is an actual fracture or the potential washout is an actual washout.

Methods and systems for modeling and predicting fractures within the subsurface region are provided. The methods and systems use multi-layer models to represent stacks of layered rocks, which are used to evaluate shear tractions caused by the relatively higher lateral strains in a more compliant overlying or underlying adjacent layers. As the lateral strains can induce tensional stresses in the brittle layers that can exceed the rocks tensile strength and fail, the formation of natural fractures may be modeled. Accordingly, the method and system model fractures due to stacking using mechanical rock property information from well logs and simulating the farfield loading conditions using basin history.