The present invention relates to a method for providing a numerical model of a sample of rock that, when used for flow simulations, it reproduces the porosity and the permeability according to the measurements taken in said sample of the rock. The method is characterized in that the structure and the properties of the numerical model are populated randomly ensuring that the global behavior reproduces the measurements.

A method and apparatus for simulating spectral representation of a region of interest is disclosed. In one embodiment, the method comprises determining a physical characteristic of a geospatial portion of the region of interest, associating the determined physical characteristic with a material of a spectral library, the spectral library having at least one spectral definition material, associating the spectral definition of the material with the geospatial portion of the region of interest, wherein the material is at least partially representative of the geospatial section of the region of interest, and generating the simulated spectral representation of the region of interest at least in part from at least the associated spectral definition of the at least one material.

A cross sectional representation of a geological surface is displayed on a display screen. A segment of the cross-sectional representation is edited, and a pseudo log of formation properties based on the edited segment is displayed on the display screen. A determination is made whether formation properties associated with the pseudo log match actual formation properties measured during drilling of a well and a signal is output indicative of the match. A drill operator may use a structural model determined based on the edited geological surface to drill for hydrocarbons in the formation.

It discloses an experimental apparatus and experimental method for physical modeling of a fluid migration and accumulation process with contemporaneous structural deformation. The experimental apparatus comprises a structural deformation experiment box, a structural deformation control device, a fluid control device and an experimental control device; the structural deformation experiment box is installed in a basket experiment module on a cantilever of a drum centrifuge, the structural deformation control device can extend and compress an experimental model in horizontal and vertical directions; and fluid cylinders of the fluid control device can be filled with fluids or plastic materials.

The present invention discloses an experimental apparatus and experimental method for physical modeling of lithospheric structural deformation. The experimental apparatus comprises a drum centrifuge capsule, a drum centrifuge driving power compartment, a structural deformation device control system and a motion control system; a basket is hung at each end of a cantilever of the centrifuge, a structural deformation experiment box is placed in the basket, and the structural deformation control system accurately controls the deformation of experimental materials in the experiment box and can model structural deformation processes at various lithospheric scales. The experimental apparatus further comprises real-time monitoring cameras and a high-speed image acquisition device.

A method for field development includes receiving input data representing a subterranean volume, generating a multi-domain model of the subterranean volume, statistically sampling one or more of the realizations of the multi-domain model based at least in part on an uncertainty associated therewith, simulating the sampled one or more of the realizations using a field development planning engine, and generating a field development plan based at least in part on the simulated one or more of the realizations.

The present invention relates to a method of estimating the region of damage due to collapse in the wall of a well during the drilling operation, normally using drilling fluid, where said well can, for example, be intended either for the injection or else for the production of a gas or oil reservoir. Other uses can be found in mining and in civil engineering work. This method is characterized by a set of analytical steps that allow establishing, for example, optimal drilling parameters so as to allow the fastest possible drilling speed that is also safe enough to allow is charging the collapse material without jamming the drilling tool. This method likewise allows assessing both the width and depth of damage in the wall of the well.

Described herein are various embodiments of computer-implemented methods, computing systems, and program products for analyzing a flood operation on a hydrocarbon reservoir. For example, an embodiment of a computer implemented method of using producer centered polygons to identify at least one infill drilling location in a hydrocarbon reservoir having a plurality of producers and at least one injector is provided.

Methods for simulating hydrocarbon (HC) migration and accumulation in a subsurface formation are provided. The methods include determining a plurality of HC mass associated with a plurality of grid cells representing the subsurface formation. The methods also include determining a plurality of HC mass outflow magnitudes for one or more grid cells in the plurality of grid cells, the HC mass outflow magnitude for each of the one or more grid cells having an upper bound value based on the HC mass in that grid cell. The methods update the HC mass of the plurality of grid cells based on the plurality of HC mass outflow magnitudes. The methods also determine that a set of grid cells in the plurality of grid cells contain an excess mass of HC, and perform an accumulation process to model filling of a trap associated with the set of grid cells.

A calibration system for an electromagnetic (EM) tool includes a processor. The processor employs the EM tool to measure responses at each of a plurality of channels. The processor records the measured responses at each of the channels in an EM data log for the channel. The processor determines a nominal value of each of the channels, as being equal to a histogram peak of the EM data log. The processor selects one or more calibration points from the EM data log for a particular channel, based on a difference between the nominal value of the particular channel and the measured response at the calibration point being greater than a particular threshold. The processor determines a plurality of parameters by reducing a misfit between synthetic data and both the nominal values of the channels and the measured responses of the channels at the selected one or more calibration points.