The present disclosure provides a method for numerical simulation of reactive transport during CO.sub.2+O.sub.2 in-situ leaching of uranium at a sandstone-type uranium deposit. Unlike the traditional method for numerical simulation of solute transport during in-situ leaching of uranium with consideration of only convection and diffusion, the method permits establishment of a multi-field coupled reactive solute transport model to simulate the dynamic leaching process of a sandstone-type uranium deposit in Northern China. The method provided in the present disclosure includes: creating a thermodynamic database suitable for CO.sub.2+O.sub.2 leaching of a sandstone-type uranium deposit in Northern China, and with consideration of the dynamic reaction process of uranium dissolution under combined action of oxygen O.sub.2 (aq) and bicarbonate HCO.sub.3.sup.−, performing numerical simulation of reactive transport during CO.sub.2+O.sub.2 in-situ leaching of uranium using a TOUGHREACT simulation technology framework.

A method for determining a distribution of a uranium deposit is provided, including: acquiring a remote detection result of a target area; acquiring a chemical detection result of soil in the target area; delineating a plurality of exploration regions in the target area according to the remote detection result and the chemical detection result; and providing boreholes in the plurality of exploration regions for gamma detection to determine a distribution and a trend of a uranium deposit according to a result of the gamma detection.

A system for identifying migration direction of natural gases is provided and may include a network of .sup.4He gas sensors and a migration monitoring hub. The network of .sup.4He gas sensors may be operable to identify a .sup.4He concentration in gas samples. The migration monitoring hub may be in communication with the network of .sup.4He gas sensors and may comprise a user interface and a processor. The processor may be operable to determine a direction of increasing .sup.4He concentration and map increasing .sup.4He concentration. The user interface may be operable to display migration information. A method for identifying migration direction of natural gases is also provided and may include isolating a target portion of a petroleum exploration environment, detecting gas samples from a network of .sup.4He gas sensors, identifying a .sup.4He concentration in the gas samples, and determining a direction of increasing .sup.4He concentration in the gas samples.

A core sample with carbonate veins is obtained from a well formed in the hydrocarbon reservoir. Formation water samples are obtained from the well. Mineralogy of carbonate in the carbonate veins is analyzed. An oxygen isotope ratio between oxygen isotopes in the formation water and an oxygen isotope ratio between oxygen isotopes in the carbonates are determined. A formation paleo-temperature value is determined based on the determined oxygen isotope ratio using a model that relates the formation paleo-temperature value and the oxygen isotope ratio.

The present invention relates to a method for determination of real subsoil composition or structure characterized in that the method comprises: —reception of unmeshed model representing the real subsoil; —determination of a sediment trajectory in said model; —based on the sediment trajectory, determination of at least one parametric surface describing a sediment formation in said model; —based on the least one parametric surface, meshing the sediment formation in said model.

In accordance with one embodiment, a method of locating mineral deposits suitable for production comprises obtaining via a computer an image of an area of land, determining from the image at least one fluid-expulsion structure present on the land, designating an area proximate the fluid-expulsion structure as a mineral exploration location; while in accordance with another embodiment a method of locating a hydrocarbon reservoir suitable for production is described which comprises obtaining via a computer an image of an area of land, determining from the image at least one fluid-expulsion structure present on the land, and designating an area proximate the fluid-expulsion structure as a hydrocarbon exploration location.

Methods, systems, and apparatus, including computer programs encoded on a computer storage medium, for detecting seepage of hydrocarbons in subterranean zones. In one aspect, a method includes detecting hydrocarbon seepage at multiple different sampling depths from a surface in a surveyed geographic region, comparing each of the hydrocarbon seepage at the multiple different sampling depths, wherein hydrocarbon seepage at a reference depth is known, and determining hydrocarbon seepage through the surveyed geographic region based on a result of the comparison.

Carbonate samples are received from a wellbore formed in a geologic formation. An oxygen isotope ratio and carbon isotope ratio present within each of the carbonate samples are determined. A mineral composition of each of the carbonate samples is determined. A plot showing the determined oxygen isotope ratios versus a depth from where within the wellbore each of the carbonate samples was obtained is created. One or more negative oxygen isotope shifts are identified based on the plot. Natural carbonate cement levels within one or more of the plurality of carbonate samples that correspond to the one or more negative oxygen isotope shifts identified in the plot are determined. One or more production sweet spots are determined based on the identified negative oxygen isotope shifts and the determined natural carbonate cement levels.

A system for determining a fingerprint of a structure is provided. The system includes a plurality of granules inserted in a structure having a plurality of fissures, fractures, and cracks (collectively apertures), each granule comprising a membrane, and at least one bubble of compressed gas formed in the membrane, the membrane selectively dissolving in presence of a predetermined fluid and thereby selectively bursting the at least one bubble, thereby generating a concussing vibration, at least at least i) three detection devices for two-dimensional mapping or ii) four detection devices for three-dimensional mapping placed proximate to the structure according to a predetermined placement schedule, and a computing device comprising a processor configured to receive data from the at least three or four detection devices and to determine location of the at least one bubble of each of the plurality of the granules at the time of bursting by triangulating the concussive vibration in order to determine location of the at least one bubble.

A computerized method and system for of operating an oil/gas facility for processing oil and gas from a reservoir. The method includes steps of receiving input data concerning condensate phase and gas phase components in the reservoir, the input data characterizing both phase components, determining a pore capillary pressure of the reservoir based on the received input data which characterizes the phase components, determining PVT parameters of the reservoir phase components based on the determined pore capillary pressure, and controlling a setting of the oil/gas facility based on the determined PVT parameters of the reservoir phase components.