It discloses a hypergravity experimental apparatus and experimental method for interaction between brittle deformation and ductile deformation. The experimental apparatus comprises an experiment module, a control device and a drive device; the drive device comprises a centrifuge for generating a hypergravity environment and a hydraulic press for generating extensional/compressional force in an experiment box; the control device comprises a control terminal, a control cabinet and a hydraulic control station for controlling the operation of the drive device; the experiment module is provided with an experiment box and a transmission device therein, and the transmission device converts a vertical lifting force generated by a hydraulic cylinder controlled by the hydraulic press in the drive device into a horizontal pushing-pulling force.

A multivariate analysis may be used to correlate seismic attributes for a subterranean formation with petrophysical properties of the subterranean formation and/or microseismic data associated with treating, creating, and/or extending a fracture network of the subterranean formation. For example, a method may involve modeling petrophysical properties of a subterranean formation, microseismic data associated with treating a complex fracture network in the subterranean formation, or a combination thereof with a mathematical model based on measured data, microseismic data, completion and treatment data, or a combination thereof to produce a petrophysical property map, a microseismic data map, or a combination thereof; and correlating a seismic attribute map with the petrophysical property map, the microseismic data map, or the combination thereof using the mathematical model to produce at least one quantified correlation, wherein the seismic attribute map is a seismic attributed modeled for the complex fracture network.

It discloses a hypergravity experimental apparatus and experimental method for interaction between brittle deformation and ductile deformation. The experimental apparatus comprises an experiment module, a control device and a drive device; the drive device comprises a centrifuge for generating a hypergravity environment and a hydraulic press for generating extensional/compressional force in an experiment box; the control device comprises a control terminal, a control cabinet and a hydraulic control station for controlling the operation of the drive device; the experiment module is provided with an experiment box and a transmission device therein, and the transmission device converts a vertical lifting force generated by a hydraulic cylinder controlled by the hydraulic press in the drive device into a horizontal pushing-pulling force.

A downhole tool, surface equipment, and/or remote equipment are utilized to obtain data associated with a subterranean hydrocarbon reservoir, fluid contained therein, and/or fluid obtained therefrom. At least one condition indicating that a density inversion exists in the fluid contained in the reservoir is identified from the data. Molecular sizes of fluid components contained within the reservoir are estimated from the data. A model of the density inversion is generated based on the data and molecular sizes. The density inversion model is utilized to estimate the density inversion amount and depth and time elapsed since the density inversion began to form within the reservoir. A model of a gravity-induced current of the density inversion is generated based on the data and the density inversion amount, depth, and elapsed time.

A multivariate analysis may be used to correlate seismic attributes for a subterranean formation with petrophysical properties of the subterranean formation and/or microseismic data associated with treating, creating, and/or extending a fracture network of the subterranean formation. For example, a method may involve modeling petrophysical properties of a subterranean formation, microseismic data associated with treating a complex fracture network in the subterranean formation, or a combination thereof with a mathematical model based on measured data, microseismic data, completion and treatment data, or a combination thereof to produce a petrophysical property map, a microseismic data map, or a combination thereof; and correlating a seismic attribute map with the petrophysical property map, the microseismic data map, or the combination thereof using the mathematical model to produce at least one quantified correlation, wherein the seismic attribute map is a seismic attributed modeled for the complex fracture network.

A method may include obtaining seismic data for a geological region of interest. The method may further include obtaining geophysical data for the geological region of interest. The method may further includes determining various pressure wavefields using a slowness model and a reflectivity model. The method may further include determining various slowness gradients for the slowness model based on the geophysical data, the pressure wavefields, the seismic data, and a geophysical constraint. The geophysical constraint may correspond to an objective function that determines a misfit between the geophysical data and the slowness model. The method may further includes updating the slowness model using the slowness gradients to produce an updated slowness model. The method may further include generating, based on the updated slowness model and the reflectivity model, a subsurface image of the geological region of interest.

A density inversion method comprises acquiring local gravity anomalies of a target body to be measured at many measurement points within a target measurement area; acquiring information of distance between a center position of an area the target body being located and a specified boundary of the target measurement area; determining a target inversion depth to be used in density inversion for the target body based on the information of distance and the specified depth; and substituting the local gravity anomaly of the target body at each measurement point and the target inversion depth into a preset layer density inversion formula which is a transform formula of a density inversion formula in the case of a constant density in a longitudinal cross-section, to obtain a density distribution of the target body in a transverse cross-section. The accuracy of the density distribution obtained through the density inversion can be improved.

A computer-implemented method for determining rock and fluid parameters of a subsurface region from measured seismic reflection data, said method including: generating, with a computer, a geophysical data volume by combining a plurality of angle stacks obtained from the measured seismic reflection data and geophysical property data obtained from a full wavefield inversion of the measured seismic reflection data; for each point of the geophysical data volume, determining, with a computer, a petrophysical model that is a probability of a rock state based on initial values of the rock and fluid parameters and the geophysical data volume; iteratively determining, using a computer, updated values for the rock and fluid parameters, wherein the iteratively determining includes determining a petrophysical parameter estimate for the rock and fluid parameters from the petrophysical model as constrained by the geophysical data volume and the initial values of the rock and fluid parameters, minimizing a misfit between the geophysical data volume and synthetic data generated from a forward modeling of the initial values of the rock and fluid parameters using a cost function that includes the petrophysical parameter estimate of the rock and fluid parameters, and repeating the iteratively determining until a predetermined stopping criteria is satisfied and final values for the rock and fluid parameters are generated, and each subsequent iteration of the iteratively determining replaces the initial values for the rock and fluid parameters with the updated values for the rock and fluid parameters from a previous iteration; determining, with a computer, uncertainty in the final values for the rock and fluid parameters; and exploring for or producing hydrocarbons using the final values for the rock and fluid parameters and there uncertainty.

A downhole tool, surface equipment, and/or remote equipment are utilized to obtain data associated with a subterranean hydrocarbon reservoir, fluid contained therein, and/or fluid obtained therefrom. At least one condition indicating that a density inversion exists in the fluid contained in the reservoir is identified from the data. Molecular sizes of fluid components contained within the reservoir are estimated from the data. A model of the density inversion is generated based on the data and molecular sizes. The density inversion model is utilized to estimate the density inversion amount and depth and time elapsed since the density inversion began to form within the reservoir. A model of a gravity-induced current of the density inversion is generated based on the data and the density inversion amount, depth, and elapsed time.

Determination of an in-situ stress perturbation model for a subsurface geological structure by using potential fields data. Potential fields data, such as gravity data, may be obtained and attributes may be determined from the gravity data. Lineaments that define the structural framework of the basement may be derived from an interpretation of the attributes. The lineaments may be combined with an in-situ stress direction and used as constraints in a finite element geomechanical simulation to generate the in-situ stress perturbation model.