A method is disclosed for evaluating and predicting a shale oil enrichment area of a fault lacustrine basin, comprising: obtaining materials and key data; determining a source-reservoir configuration relationship according to a longitudinal superposition relationship of different types of rock in a lithology profile and establishing a single-well lithofacies model; in the single-well lithofacies model, using a dolomite-to-formation ratio and a TOC average value to form a dolomite-to-formation ratio contour map and a TOC contour map, and superposing the dolomite-to-formation ratio contour map, the TOC contour map and a source-reservoir configuration relationship plane distribution map to form a lithofacies plane distribution map; on the basis of the lithofacies plane distribution map, superposing a vitrinite reflectance contour map and a dolomite thickness contour map to obtain a corresponding evaluation and prediction map of the shale oil enrichment area of the fault lacustrine basin.

Forecasting the likelihood of an earthquake comprises: determining a gas migration rate using measurements collected from measurement device(s). The measurement devices may be measuring changes in radon gas intensity. If the gas migration rate increases at greater than a first rate, determining a latent heat energy release rate; if the latent heat energy release rate increases at greater than a second rate, look for at least one transient outgoing long wave radiation (OLR) anomaly using measurements collected from remote sensing atmospheric thermodynamic measurement(s); if the transient outgoing long wave radiation (OLR) anomaly has been observed, look for at least one ionospheric anomaly using measurements collected from ionosphere measurement device(s); and if the at least one ionospheric anomaly has been observed, forecasting that an earthquake is likely to occur within one to four days from the observation of the at least one ionospheric anomaly.

Proposed is a geological hydrogen productivity evaluation system. The system may include a gas injection device configured to inject a reactive gas, a water vapor collecting device configured to collect water vapor generated in the gas injection device when the gas is injected. The system may also include a main reacting device in which a reaction between a solvent and a rock sample, which are loaded into the inside thereof, is performed using the gas supplied from the gas injection device. The system may further include a discharging device through which reactants generated by the reaction in the main reacting device are discharged, and a collecting device configured to collect gas from reactants produced by the reaction by being connected to the discharging device. The system may capture hydrogen from a reactant produced by the reaction of the rock sample in the main reacting device, in the collecting device.

Embodiments of the disclosure are drawn to apparatus and methods for determining gas flux measurements. A gas plume may be emitted from a source and may be blown by wind in an environment. A measurement system, such as a light detection and ranging (lidar) system may collect a plurality of gas concentration measurements associated with the gas plume at a plurality of locations in the environment. A gas flux may be determined based on one or more of the gas concentration measurements along with a wind speed at a location associated with the gas plume. In some embodiments, a height of the gas plume may be determined, and the wind speed at the height of the gas plume may be determined and used to determine the gas flux.

A portable monitor used to measure landfill gas and landfill well parameters. The portable monitor includes a control unit and a measuring unit that can communicate wirelessly with one another. The control unit and/or measuring unit can include a heating arrangement to increase the temperature of one or more components in the control unit and/or measuring unit in cold environments.

Methods and systems for locating a chemical source include measuring chemical concentration with sensors at a plurality of different positions. Measurements from pairs of positions are cross-correlated to determine an average velocity vector for a group of positions. A convergence region is determined based on a plurality of average velocity vectors to determine a chemical source location.

Described herein are methods and techniques that utilize molecular geochemistry and isotopic signatures to monitor microbial enhanced gas and oil recovery operations. The methods and techniques utilize multiply substituted isotopologue signatures, clumped isotope signatures, and/or position-specific isotope signatures of one or more byproducts of the microbial stimulation techniques to determine the effectiveness of a microbial stimulation technique.

Methods and apparatus suitable for quickly and accurately measuring .sup.13C levels and supporting data in an aqueous fluid reservoir. Interpreting the resulting data to indicate key factors regarding a reservoir and completion methods, including reservoir constraint, gas producibility, and completion success. A sensor and to a sensing method that evaluates the level of hydrologic constraint in aquifers occurring in unconventional reservoirs, such as shales and coals is disclosed. Specifically, Raman spectroscopy is disclosed as a sensor and a sensing method that measures the level of naturally-occurring .sup.13C in an aqueous reservoir and compares the level of .sup.13C to the levels typical for highly constrained and highly unconstrained reservoirs. The disclosed sensor and sensing method also monitors the level of naturally-occurring .sup.13C in a reservoir. Also disclosed is a method of using .sup.13C.sub.Dic to evaluate geographic areas of coal bed reservoir water having biologic methanogenic activity.

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.

A method and system are described that may be used for exploration, production and development of hydrocarbons. The method and system may include analyzing a sample for a geochemical signature, wherein the geochemical signature includes a multiply substituted isotopolog signature and/or a position specific isotope signature. Then, the historical temperature, type of alteration and/or extent of alteration may be determined from the signature(s) and used to develop or refine an exploration, development or production strategy.