The invention discloses method for determining hydraulic parameters and water inflow in the erosion stage of gravel soil, comprising: calculate the soil particle content P and the soil porosity n of each grade of particle size a, and draw the PSD curve of each grade of particle size and the soil particle content P of each grade of particle size and the PSD curve cluster of each grade of particle size and the soil particle content P of each grade of particle size in each erosion stage; calculate the equivalent diameter D.sub.h of the soil particle, and calculate the minimum equivalent pore diameter d.sub.0 of the soil particle; calculate the critical hydraulic gradient i.sub.cr of particle erosion at each stage; calculate the permeability coefficient k.sub.h; calculate the seepage flow velocity ν and the total seepage flow Q.

A system for detecting material accumulation relative to basket assemblies of an agricultural implement includes a frame assembly, and a basket assembly configured to be supported by the frame assembly relative to a surface of a field. The system also includes a load sensor configured to detect a load indicative of a draft load associated with the basket assembly, and a computing system communicatively coupled to the load sensor. The computing system is configured to monitor the load based on data provided by the load sensor, compare the monitored load to a load threshold, and determine that field materials have accumulated relative to the basket assembly when the monitored load differs from the load threshold.

A system for detecting material accumulation relative to basket assemblies of an agricultural implement includes a frame assembly, and a basket assembly configured to be supported by the frame assembly relative to a surface of a field. The system also includes a load sensor configured to detect a load indicative of a draft load associated with the basket assembly, and a computing system communicatively coupled to the load sensor. The computing system is configured to monitor the load based on data provided by the load sensor, compare the monitored load to a load threshold, and determine that field materials have accumulated relative to the basket assembly when the monitored load differs from the load threshold.

A method includes performing a downhole operation in a borehole in a formation. Downhole particles and drilling mud are captured at a surface from the borehole into a screen of a shaker during the downhole operation. Input power that comprises at least one of voltage, current, and leakage current being supplied to the shaker is monitored during operation of the shaker, it is determined whether the input power exceeds a threshold as a result of change in a load on the shaker. In response to determining that the input power exceeds the threshold as the result of change in the load on the shaker, it is determined that there is a kick condition in the borehole, where the kick condition comprises a condition in which a pressure of the formation exceeds a pressure in the borehole.

A method includes performing a downhole operation in a borehole in a formation. Downhole particles and drilling mud are captured at a surface from the borehole into a screen of a shaker during the downhole operation. Input power that comprises at least one of voltage, current, and leakage current being supplied to the shaker is monitored during operation of the shaker, it is determined whether the input power exceeds a threshold as a result of change in a load on the shaker. In response to determining that the input power exceeds the threshold as the result of change in the load on the shaker, it is determined that there is a kick condition in the borehole, where the kick condition comprises a condition in which a pressure of the formation exceeds a pressure in the borehole.

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 of imaging electrical conductivity distribution of a subsurface containing metallic structures with known locations and dimensions is disclosed. Current is injected into the subsurface to measure electrical potentials using multiple sets of electrodes, thus generating electrical resistivity tomography measurements. A numeric code is applied to simulate the measured potentials in the presence of the metallic structures. An inversion code is applied that utilizes the electrical resistivity tomography measurements and the simulated measured potentials to image the subsurface electrical conductivity distribution and remove effects of the subsurface metallic structures with known locations and dimensions.

There are provided methods, systems and processes for the utilization of microbial and related genetic information for use in the exploration, determination, production and recovery of natural resources, including energy sources, and the monitoring, control and analysis of processes and activities.

There are provided methods, systems and processes for the utilization of microbial and related genetic information for use in the exploration, determination, production and recovery of natural resources, including energy sources, and the monitoring, control and analysis of processes and activities.

The present invention includes a method for distinguishing between a natural source of deep gas and gas leaking from a CO.sub.2 storage reservoir at a near surface formation comprising: obtaining one or more surface or near surface geological samples; measuring a CO.sub.2, an O.sub.2, a CH.sub.4, and an N.sub.2 level from the surface or near surface geological sample; determining the water vapor content at or above the surface or near surface geological samples; normalizing the gas mixture of the CO.sub.2, the O.sub.2, the CH.sub.4, the N.sub.2 and the water vapor content to 100% by volume or 1 atmospheric total pressure; determining: a ratio of CO.sub.2 versus N.sub.2; and a ratio of CO.sub.2 to N.sub.2, wherein if the ratio is greater than that produced by a natural source of deep gas CO.sub.2 or deep gas methane oxidizing to CO.sub.2, the ratio is indicative of gas leaking from a CO.sub.2 storage reservoir.