A method and system for locating subsurface ore bodies. Samples of near surface soil are collected over a predetermined geographical area. The samples are analysed to discover any chemical anomalies in the dust particles as a way of identifying possible subcropping mineralization. A tine (22) and collection tube (24) engage into subsurface soil and samples are drawn up the tube into a dust collection module (12). Sub 5 micron particles are captured on an electrostatically charged tape (40). Consecutive samples are indexed on the tape e.g. with a barcode. Collected dust samples are ablated by a laser ablation cell (72) and the ablated sample analysed by a mass spectrometer for presence of ions indicating presence of a resource body, such as a body of ore, minerals or hydrocarbons.

The invention relates to a method for detecting and locating hydrocarbon deposits under a body of water in several steps. First, images of a surface of the body of water taken at different times are acquired. Next, for each image, traces of hydrocarbon leaks are identified. Next, a detection map is generated. This map indicates probabilities of the presence of a hydrocarbon leak around the identified traces. The map is obtained by processing the image at least based on a criterion of distance to the identified traces. Finally, the detection maps are combined to produce a hydrocarbon leak location map.

Systems and methods for determining the thermal maturity of a rock formation from isotopic values in gases are provided. Isotope values may be obtained from mud gas isotope logging, vitrinite reflectance equivalence values may be determined from core samples using known techniques. A relationship between vitrinite reflectance equivalence and isotopic values, such as carbon-13 methane values, may be determined. The vitrinite reflectance equivalence may then be determined from isotopic values to determine the thermal maturity of rock formations accessed by drilling additional exploration wells.

Described herein are methods and techniques for determining one or more characteristics of a hydrocarbon source. The method comprises obtaining a hydrocarbon fluid sample, determining at least one measured clumped isotope signature or measured position specific isotope signature for at least one hydrocarbon species of interest in the hydrocarbon fluid sample, determining at least one expected clumped isotope signature or expected position specific isotope signature for the hydrocarbon species of interest, comparing the measured clumped isotope signature or measured position specific isotope signature with the expected clumped isotope signature or expected position specific isotope signature, and determining at least one characteristic of the source of the hydrocarbon sample based on the comparison.

Systems and methods for geochemical sampling grid locations on a seafloor. At least one of the methods includes generating, using received seismic data, an image representing an interpretation of a seafloor horizon surface; extracting, from the image and based on the seismic data, one or more discontinuity attributes of the seafloor horizon surface; extracting, from the image and based on the seismic data, one or more amplitude attributes of a window extending below the seafloor horizon surface; combining the one or more discontinuity attributes and the one or more amplitude attributes; and selecting, using the image and based at least partly on the combining, one or more locations of the seafloor horizon surface for sampling.

A method for determining a presence of reservoired hydrocarbons having a hydrocarbon seep involves locating a hydrocarbon seep at a seabed location where hydrocarbon is actively flowing out of the seabed. Temporally spaced isotopic compositions of the hydrocarbon seep are determined. When a temporal variance between the isotopic compositions falls within a predetermined temporal tolerance, the hydrocarbon seep is classified as being indicative of the presence of reservoired hydrocarbons. A unique identifier is assigned to the reservoired hydrocarbons.

A method for a physics-driven deep learning-based inversion coupled to fluid flow simulators may include obtaining measured data for a subsurface region, obtaining prior subsurface data for the subsurface region, and obtaining a physics-driven standard regularized joint inversion for at least two model parameters. The method may further include obtaining a case-based deep learning inversion characterized by a contracting path and an expansive path. The method may further include forming the physics-driven deep learning inversion with the physics-driven standard regularized joint inversion, the case-based deep learning inversion, and a coupling operator based on a penalty function. The method may further include forming a feedback loop between the physics-driven standard regularized joint inversion and the case-based deep learning inversion for re-training the case-based deep learning inversion. The method may further include generating an inversion solution for reservoir monitoring.

A method and apparatus detects an unknown deposit in soil of a known mineral or gemstone using characteristic scents of the mineral or gemstone. The method may disturb the soil, for example, by causing a chemical reaction in at least part of the soil such that a mineral or gemstone present in the soil emits a characteristic scent. The unknown deposit of the known mineral or gemstone can be detected in real-time or near real-time in the field.

The present disclosure relates to techniques for prediction of reservoir fluid properties of a hydrocarbon reservoir fluid, such as the density, the saturation pressure, the formation volume factor and the gas-oil ratio of the reservoir fluid. To predict the reservoir fluid properties, a model is generated by selecting a subset of available reservoir samples based on a degree of biodegradation of the samples, generating an input data set comprising input data and target data, the input data comprising measured or predicted mud-gas data; and generating a model using the input data. The application of this technique allows a continuous log of the selected property to be generated using mud-gas data collected during the well drilling process.

Systems and methods for geochemical sampling grid locations on a seafloor. At least one of the methods includes generating, using received seismic data, an image representing an interpretation of a seafloor horizon surface; extracting, from the image and based on the seismic data, one or more discontinuity attributes of the seafloor horizon surface; extracting, from the image and based on the seismic data, one or more amplitude attributes of a window extending below the seafloor horizon surface; combining the one or more discontinuity attributes and the one or more amplitude attributes; and selecting, using the image and based at least partly on the combining, one or more locations of the seafloor horizon surface for sampling.