Hybrid 3D geocellular grids are generated to represent a subset of a natural fracture network (“NFN”) directly in the simulation, while the remainder of the NFN is approximated by a multi-continuum formulation. The resulting output is a 3D geocellular grid that possesses a higher level of mesh resolution in those areas surrounding the first fracture subsets, and lower mesh resolution in the areas of the second fracture subset.

The present invention relates to a method for determining hydrocarbon production for a reservoir. The method comprises determining a projector matrix based on a Jacobian matrix function of the gridded model, then splitting the Jacobian matrix into subsets of consecutive lines. For each subset of consecutive lines, creating a respective square matrix based on said subset. A determining eigenvectors and respective eigenvalues associated with the respective square matrix and then determining relevant eigenvectors having respective eigenvalues below a predetermined threshold. The projector is determined as a concatenation of the extended eigenvectors ordered according to multiple criteria: the respective order value of the subset; and the respective eigenvalue of the relevant eigenvector.

A method of predicting hydraulic fracturing and associated risks of hydraulic fracturing operation is proposed. The methods use the mathematical simulation which allow to predict the geometry of a hydraulic fracture and location of fluids, propping agents (proppant), fibers and other materials therein. Reconsidering the fracturing design allows to remedy the possible risks (overflush, screen-out, bridging, gel contamination, temperature effects).

Systems and methods of the present disclosure are directed to reservoir simulation modeling using upon rock compaction tables derived from physical pore compressibility tests. The illustrative methods transform rock mechanics-based pore compressibility tests into compliant rock compaction tables for reservoir simulators using Dimensionless Stress to Pore Pressure Conversion, to thereby transfer geomechanical changes due to confining stress into expressions of geomechanical changes due to pore pressure.

One or more methods for validating reservoir simulation models. At least one of the methods include determining one or more time segments of fluid recovery of a reservoir by analyzing a production history of the reservoir; running a simulation model, for the first time segment, to generate one or more drainage volumes; generating, for a first time segment, a plurality of grid regions along one or more no-flow boundaries of the one or more drainage volumes; generating, for the first time segment, a plurality of sector models corresponding to the plurality of grid regions; and performing, for the first time segment, a history matching process corresponding to a time phase simultaneously on each of the plurality of sector models to generate, for each of the sector models, a history matching output.

Methods for validating reservoir simulation models can include determining one or more time segments of fluid recovery of a reservoir; generating, for a first time segment, one or more streamlines on a full simulation grid corresponding to the reservoir by performing one or more reservoir simulations; generating, for the first time segment, one or more drainage volumes; generating, for the first time segment, grid regions along one or more no-flow boundaries of the one or more drainage volumes; generating, for the first time segment, sector models corresponding to the grid regions; performing, for the first time segment, a history matching process corresponding to a time phase simultaneously on each of the sector models to generate, for each sector model, a history matching output; and comparing, for the first time segment and for each sector model, the history matching output for that sector model to a tolerance threshold.

A computer-implemented method and a related system for determining seismic hazard related data. The method includes processing geological/seismological data associated with an area of unknown hazard using a simulation model, and determining simulated ground motion intensity data associated with the area of unknown hazard. The simulation model is determined based on geological/seismological data associated with an area of known hazard and ground motion intensity data associated with the area of known hazard. Alternatively, or additionally, the method includes processing simulated ground motion intensity data associated with the area of unknown hazard with another simulation model. Such simulation model is determined at least partly based on: geological/seismological data associated with an area of unknown hazard, geological/seismological data associated with an area of known hazard, ground motion intensity data associated with the area of known hazard, and simulated ground motion intensity data associated with the area of known hazard.

A wireline width measuring apparatus and associated method which may be used to measure static and dynamic fracture width in fractures used for energy storage, water injection, or hydrocarbon production. In one embodiment, the method comprises determining a depth of the formation fracture, determining the depth of the bottom of the wellbore, positioning a caliper tool string comprising a caliper apparatus at the bottom of the wellbore, wherein the caliper apparatus is positioned at a depth capable of measuring movement of a window cut into a casing of the wellbore at the depth of the formation fracture, inflating the fracture by injecting a fluid into the fracture, uninflating the fracture by producing the fluid from the fracture, and measuring movement of the window cut into the wellbore while the fracture is inflated and uninflated.

A system for determining completion parameters for a wellbore includes a sensor and a computing device. The sensor can be positioned at a surface of a wellbore to detect data prior to finishing a completion stage for the wellbore. The computing device can receive the data, perform a history match for simulation and production using the sensor data and historical data, generate inferred data for completion parameters using the historical data identified during the history match, predict stimulated area and production by inputting the inferred data into a neural network model, determine completion parameters for the wellbore using Bayesian optimization on the stimulated area and production from the neural network model, profit maximization, and output the completion parameters for determining completion decisions for the wellbore.

Techniques for determining a geologic parameter include determining, with an analytical solution, a change to at least one control point of a boundary of a control volume defined in a subterranean formation that is caused by a hydraulic fracture formed in or adjacent the subterranean formation; determining, with a numerical solution, a fluid pressure change of the control volume based on the change to the at least one control point; and determining, with a solver, at least one dimension of at least one of the control volume or the hydraulic fracture based at least in part on the determined fluid pressure change of the control volume.