Methods may include using geometrical and mechanical properties to generate a model of one or more intervals of a wellbore; designing a fluid pumping schedule for a wellbore treatment fluid system; simulating flow of a fluid system containing solids using the model of the one or more intervals of the wellbore, wherein simulating comprises determining the flow rate distribution within the wellbore and modeling the settling and resuspension of the solids within the flow of the fluid system; and updating the fluid pumping schedule based on the output determined from the simulated flow of the fluid system. Methods may also include determining the critical velocity of the fluid system for various concentrations of one or more of solids and additives; and selecting the concentration of the one or more of solids and additives based on the critical velocities determined.

Systems and methods for estimating reservoir productivity as a function of depth in a subsurface volume of interest are disclosed. Exemplary implementations may: obtain subsurface data and well data corresponding to a subsurface volume of interest; obtain a parameter model; use the subsurface data and the well data to generate multiple production parameter maps; apply the parameter model to the multiple production parameter maps to generate refined production parameter values; generate multiple refined production parameter graphs; display the multiple refined production parameter graphs; generate one or more user input options; receive the one or more user input options selected by a user to generate limited production parameter values; generate a representation of estimated reservoir productivity as a function of depth in the subsurface volume of interest using visual effects; and display the representation.

Systems and methods include a method for generating a high-resolution advanced three-dimensional (3D) transient model that models multiple wells by integrating pressure transient data into a static geological model. A crude 3D model is generated from a full-field geological model that models production for multiple wells in an area. A functional 3D model is generated from the crude 3D model. An intermediate 3D model is generated by calibrating the functional 3D model with single-well data. An advanced 3D transient model is generated by calibrating multi-well data in the functional 3D model.

Methods and systems for generating heterogeneity indices for reservoirs is provided. The method includes generating a geological model based on physical locations of a plurality of wells in a reservoir, wherein the geological model provides: graphical representations corresponding to the physical locations of the plurality of wells, a plurality of pseudo locations of pseudo wells in the reservoir, and graphical representations corresponding to the pseudo locations of the pseudo wells, determining reservoir properties associated with the pseudo locations of the pseudo wells in the reservoir, determining vertical heterogeneity indices associated with each location of the pseudo locations of the pseudo wells in the reservoir, determining using an interpolation operation associated with the vertical heterogeneity indices, lateral heterogeneity indices associated with each pseudo location of the pseudo locations of the pseudo wells, and generating for display a heterogeneity property model based on the vertical heterogeneity indices and the lateral heterogeneity indices.

The disclosure is directed to a method of utilizing an acoustic sensing cable, such as a fiber optic distributed acoustic sensing (DAS) cable, in a borehole to detect microseismic events and to generate three dimensional fracture plane parameters utilizing the detected events. Alternatively, the method can use various categorizations of microseismic data subsets to generate one or more potential fracture planes. Also disclosed is an apparatus utilizing a single acoustic sensing cable capable of detecting microseismic events and subsequently calculating fracture geometry parameters. Additionally disclosed is a system utilizing a processor to analyze collected microseismic data to generate one or more sets of fracture geometry parameters.

Methods and systems for evaluating a distribution and recoverability of a light non-aqueous phase liquid (LNAPL) or a dense non-aqueous phase liquid (DNAPL) in fractured substrate are provided. Also provided are methods and systems for evaluating a distribution and recoverability of a light non-aqueous phase liquid (LNAPL) or a dense non-aqueous phase liquid (DNAPL) in other substrates, including a layered porous media substrate. Also provided are methods and systems for calibrations related to DNAPL transmissivity.

A free-space well connection method of determining parameters for modeling a reservoir is disclosed. The method is conducted by a computer system (100) having a processor (110) and non-transitory memory (120) that stores data including instructions to be executed by the processor (110), the processor (110) executing a modeling module (102) stored in the memory (120), the modeling module (102) having data representing a grid with a well-cell (202) and at least one link-cell (204), each of the at least one link-cell (204.sub.i) having a common face (Γ.sub.i) with the well-cell (202), the well-cell (202) and the at least one link-cell (204) being a local cell array. The method comprises steps of modeling, by the modeling module (102), the local cell array as having an infinite outer boundary by modeling the grid as an infinite space around the local cell array for determination of parameters for the well-cell (202) and determining, by the modeling module (102), one or more of a well connection transmissibility factor (T.sub.w) and at least one inter-cell transmissibility multiplier (M.sub.i).

Systems, methods, and computer readable media, of which the method includes calculating strains, stresses, or both resulting from pressure changes in a subterranean volume using a geomechanical model, determining one or more local correlations between pressure changes and changes in permeability, porosity, or both in the subterranean volume using the calculated strains and stresses, generating one or more compaction tables for the subterranean volume using the local correlations, calculating pressure changes in the subterranean volume by simulating fluid flow in the subterranean volume using a reservoir model, and modifying the reservoir model using the one or more compaction tables and the calculated pressure changes.

It is proposed a method which comprises providing a geomechanical model of the geological environment, measurements of a first geological attribute each performed at a respective first position of the geological environment, constraints on a second geological attribute related to a yield criterion and each assigned to a respective second position of the geological environment, and a geomechanical simulator. The method also comprises determining the stress field derivable from the data outputted by the geomechanical simulator taking as input the geomechanical model and an optimal set of one or more boundary conditions. This provides an improved solution for estimating in situ stress field of a geological environment.

The present invention discloses an optimization design method for volumetric fracturing construction parameters of an infilled well of an unconventional oil and gas reservoir. The method comprises the following steps: S1, establishing a three-dimensional geological model with physical and geomechanical parameters; S2, establishing a natural fracture network model through integration of rock core-logging-seismic data; S3, generating old well hydraulic fracturing complex fractures based on the natural crack model; S4. establishing a three-dimensional shale gas reservoir seepage model; S5, establishing a three-dimensional geomechanical model; S6, analyzing and calculating a dynamic geostress field; S7, establishing a numerical model for horizontal fracturing complex fractures in the infilled well based on the calculation results of old well complex fractures and dynamic geostress; and S8, performing optimization design on volumetric fracturing construction parameters of the infilled well. The method of the present invention has the following beneficial effects: the effects of long-term exploitation of shale reservoirs in which natural fractures are developed on volumetric fracturing of the infilled well can be reflected accurately, the fracturing construction parameters are subjected to optimization design, the fracturing effect is improved effectively, and the single-well capacity is increased.