Systems, methods, and software for predicting total organic carbon (TOC) values are described. A representative method includes obtaining nuclear magnetic resonance (NMR) data and training a radial basis function (RBF) model based on the NMR data and measured total organic carbon (TOC) values. The method also includes obtaining subsequent NMR data and employing the trained RBF model to predict TOC values based at least in part on the subsequent NMR data. The method also includes storing or displaying the predicted TOC values.

Systems and methods for extracting minerals from an underground mineralization zone located below the surface at an oil and gas drilling site. The system includes a vertical drilling means for drilling a vertical bore extending from the surface at the oil and gas drilling site into the mineralization zone, a second horizontal drilling means for drilling at least one horizontal production bore into the mineralization zone. The first horizontal drilling means and the second horizontal drilling means are configured to return material from the mineralization zone to the surface where the mineral content of the material is analyzed and a separator separates minerals, waste and drilling mud from the material. The method includes steps of drilling a horizontal assessment bore, analyzing assessment material for a desired mineral, drilling a horizontal production bore, producing production material containing the desired mineral, and separating the desired material from waste and drilling mud.

A system for increasing the detecting degradation of a wellbore. The system comprises a computer memory configured for storing computing instructions and a processor operably coupled to the computer memory. The system comprises a sensor operably coupled to the computer memory and is configured to determine the presence of at least one chemical species indicative of degradation of the wellbore in a fluid exiting the wellbore. Methods of monitoring a wellbore for corrosion or other degradation of one or more components of wellbore equipment are disclosed as are methods of increasing the lifetime of a wellbore.

Anisotropic elastic properties and subsequently in situ stress properties for a rock formation surrounding a wellbore are computed from rock physics and geomechanical models. Mineralogy data measured from DRIFTS on cuttings from the wellbore and rock physics and geomechanical models that have been log-calibrated in another wellbore are used in the computation. The method includes: (1) Defining and calibrating rock physics and geomechanical models using data from the first wellbore; (2) using DRIFTS analysis to measure mineralogy data on rock cuttings obtained through drilling operation in the second wellbore; and (3) using previously calibrated models to estimate in situ stress properties, including a stress index and the minimum principal stress magnitude.

Anisotropic elastic properties and subsequently in situ stress properties for a rock formation surrounding a wellbore are computed from rock physics and geomechanical models. Mineralogy data measured from DRIFTS on cuttings from the wellbore and rock physics and geomechanical models that have been log-calibrated in another wellbore are used in the computation. The method includes: (1) Defining and calibrating rock physics and geomechanical models using data from the first wellbore; (2) using DRIFTS analysis to measure mineralogy data on rock cuttings obtained through drilling operation in the second wellbore; and (3) using previously calibrated models to estimate in situ stress properties, including a stress index and the minimum principal stress magnitude.

A method of sampling ingredients of an oil-bearing inclusion includes a) providing a first container and a second container, an external diameter of the first container being smaller than an internal diameter of the second container, and the first and second containers both being transparent; b) adding a solvent into the first container and sealing said first container; c) adding an oil-bearing inclusion sample into the second container, and putting the first container that contains the solvent and is sealed in step b) into the second container; and d) using a laser to ablate the oil-bearing inclusion sample contained in the second container that is sealed in step c), and using the laser to break an end portion of the first container close to the sample on condition that the second container is maintained complete, so as to allow the solvent in the first container to enter the second container.

A method of sampling ingredients of an oil-bearing inclusion includes a) providing a first container and a second container, an external diameter of the first container being smaller than an internal diameter of the second container, and the first and second containers both being transparent; b) adding a solvent into the first container and sealing said first container; c) adding an oil-bearing inclusion sample into the second container, and putting the first container that contains the solvent and is sealed in step b) into the second container; and d) using a laser to ablate the oil-bearing inclusion sample contained in the second container that is sealed in step c), and using the laser to break an end portion of the first container close to the sample on condition that the second container is maintained complete, so as to allow the solvent in the first container to enter the second container.

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.

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.

A method of performing a stimulation operation for a subterranean formation penetrated by a wellbore is provided. The method involves collecting pressure measurements of an isolated interval of the wellbore during injection of an injection fluid therein, generating a fracture closure from the pressure measurements, generating transmissibility based on the fracture closure and a mini fall off test of the isolated interval during the injection, obtaining fracture geometry from images of the subterranean formation about the isolated interval, and generating system permeability from the transmissibility and the fracture geometry. The method may also involve deploying a wireline stimulation tool into the wellbore, isolating an interval of the wellbore and injecting fluid into the interval with the wireline stimulation tool. The fracture geometry may be obtained by imaging the formation, and fracture geometry may be obtained from core sampling.