The method and system describes monitoring and modeling the hydraulic fracturing of a reservoir. The microseismic events caused by hydraulic fracturing on a reservoir are captured by sensor arrays. The data captured by the sensor arrays are then analyzed to determine the source radius, and seismic moment tensor of microseismic events caused by the hydraulic fracturing. This information is then combined with a seismic velocity model to arrive at a discrete fracture network showing at least the orientation, source radius, and source mechanism of each microseismic event. This discrete fracture network is then used to determine the stimulated surface area, stimulated volume, and point of diminishing returns for the hydraulic fracturing process. Hydraulic fracturing engineers can use the algorithms to monitor the well and/or determine well completion.

In some aspects, the present disclosure includes systems and methods for modeling a fracturing operation in a subsurface formation. The method includes generating an earth model of the subsurface formation, wherein the earth model is generated considering unstructured gridding; generating a fracture model of the subsurface formation based, at least in part, on the earth model of the subsurface formation, and wherein the fracture model is generated considering unstructured gridding; and performing a reservoir simulation of at least one reservoir in the subsurface formation based, at least in part, on the earth model and the fracture model, wherein the reservoir simulation is performed using unstructured gridding.

Systems and methods for automatically detecting and identifying seismic wave features in seismic data are provided. In general, the systems and methods utilize a nonparametric time series classification method to detect seismic wave features that may otherwise be difficult to automatically identify in seismic data. Instead of building a model by estimating parameters from the seismic data, the data itself is used to define a trained model. The systems and methods described here provide the ability to detect and identify seismic wave features with reasonably fast and extremely accurate results without needing to compute parameters.

The present invention relates to energetic cocrystals, and to methods for using the same for treatment of a subterranean formation. In various embodiments, the present invention provides a method of treating a subterranean formation, the method including obtaining or providing a composition including energetic cocrystals. Each energetic cocrystal independently includes an energetic compound and a secondary material. The method also includes placing the composition in a subterranean formation.

The embodiments of the present application include acquiring a monitoring region and each observation point therein; partitioning the monitoring region into N layers of grids according to a seismic source positioning accuracy, wherein a side length of a grid cell of an i-th layer of grid is D/2.sup.i-1, i=1, . . . N, and D is an initial side length of the grid cell and not more than a double of a distance between the respective observation points; searching all nodes in a first layer of grid to acquire a node satisfying a preset condition therefrom; from i=2, determining and searching nodes satisfying a first preset requirement in the i-th layer of grid, to acquire a node satisfying the preset condition therefrom, until a search in an N-th layer of grid is completed, wherein a node satisfying the preset condition acquired in the N-th layer of grid is a seismic source point location.

Example methods and systems for near-surface characterization through passive monitoring of rig-generated noise are disclosed. One example method includes positioning a distributed acoustic sensing (DAS) cable in a spiral configuration layout around a drilling rig, where the drilling rig includes one or more pieces of drilling rig equipment, and the DAS cable includes a fiber-optic cable. The DAS cable is interrogated using multiple distributed fiber-optic sensing (DFOS) laser pulses during a drilling operation of the drilling rig. Multiple backscattered laser pulses are received from the DAS cable after the DAS cable is interrogated using the multiple DFOS laser pulses. A respective location of each of one or more anomalies in sub-terrain around the drilling rig is determined based on the multiple backscattered laser pulses.

A method is described for monitoring a stimulated reservoir volume (SRV) including receiving simulation parameters, performing 3D fully coupled quasi-static poro-elastic finite difference modeling using the simulation parameters, wherein the 3D fully coupled quasi-static poro-elastic finite difference modeling is based on a rescaling of solid rock and fluid flow density parameters and generates simulated temporal quasi-static stresses, and pore pressure. In addition, simulated stresses may be used for performing calculation of the 3D rotation of the simulated stresses to principal directions; performing calculation of the temporal 3D Mohr-Coulomb (MC) failure criteria from the calculated principal stresses and the simulated pore pressure for all or selected time steps; and displaying the computed temporal MC failure criteria results on a graphical display. The method may also be used in time-lapse monitoring of the reservoir for microseismic depletion delineation.

A moment tensor is determined using an inversion algorithm for each of a plurality of microseismic events passively detected by receivers. Each of the moment tensors includes two nodal planes. A subset of the microseismic events is grouped into a family of microseismic events. If the microseismic events in the family have a common nodal plane, the common plane is a solution fault plane for the family of microseismic events. Information related to the fault plane is used to optimize fracking operation.

In some aspects, reservoir characterizations of subterranean regions can be enhanced by using realtime fracture matching techniques for capturing the time dependent evolution of fracture parameters based on the occurrence of the time microseismic events generated by stimulation treatments. These microseismic events may further be used to determine hydraulic fracture planes, identify areas of concentration of high density microseismic events, identify and analyze complex fracture networks, and use these and other techniques to enhance the reservoir characterization.

The present disclosure involves a novel way of using drilling vibrations generated by the deformation of a rock formation in response to forces acting on the rock formation, where the forces are related to a drill bit and/or drilling fluid system, to identify the nature and occurrence of fractures, fracture swarms and other mechanical discontinuities (boundaries) such as bedding planes and/or faults that offset or otherwise separate rock formations with different mechanical rock properties.