A method and system for determining fluid contamination. The method may comprise monitoring a fluid sample, wherein the fluid sample comprises a reservoir fluid contaminated with a well fluid, and obtaining input parameters, wherein the input parameters comprise fluid properties obtained from measurement of the fluid sample and mud filtrate composition. The method may further comprise representing a mud composition as a Gaussian distribution, selecting a plurality of input data during a pumpout, determining calculated fluid properties of the reservoir fluid using an equation of state filtrate analysis, and further obtaining updated values of iterative parameters for use in a mole fraction distribution function. The system may comprise a downhole fluid sampling tool operable to obtain fluid samples of a reservoir fluid contaminated with a well fluid while the downhole fluid sampling tool is disposed in a wellbore, and a processor

Methods (and related apparatus) include obtaining data regarding a measured property. The measured property includes an amount of each of predetermined hydrocarbons in a gas sample extracted from drilling fluid exiting a wellbore having a hydrocarbon resource. An unknown characteristic of an investigated fluid property of the hydrocarbon resource is predicted utilizing the obtained input data and one or more predetermined models each built via statistical classification and regression analysis of a preexisting database containing records. Each record includes known characteristics of fluid properties of a different one of known reservoir fluids. The fluid properties include the investigated fluid property and the measured property. The investigated fluid property includes a fluid type of the hydrocarbon resource, an amount of at least one additional hydrocarbon, gas-oil ratio, or stock tank oil density.

A method may comprise sampling a wellbore fluid; analyzing the wellbore fluid and determining a presence of a graphene-like substrate, a concentration of the graphene-like substrate, or both, in the wellbore fluid; and correlating the presence and the concentration of the graphene-like substrate to at least one subterranean formation characteristic.

An adjustable filtration assembly performs water filtration tests from a sample point. A container contains a water solution. An inlet valve enables a flow of the water solution into the container. An adjustable pressure regulator valve regulates the flow. A relief valve releases a portion of the water solution when a pressure of the water solution exceeds a threshold pressure. A differential pressure gauge displays a current pressure reading of the water solution in the container, receives adjustments specifying a specific pressure to be maintained, maintains the specific pressure of the water solution, and triggers the relief valve when the pressure exceeds the specific pressure. An outlet valve, when opened, outputs a measured volume of the water solution. A filter membrane mounted in the outlet valve filters solids from the measured volume. A relative plugging index (RPI) of the water solution is determined based on a weight of the solids.

A method includes analyzing a carbonaceous deposit for an asphaltene content from a hydrocarbon-containing fluid located in a well, a wellhead or a production line proximate the wellhead, and applying one or more preventative measures to the hydrocarbon-containing fluid located in the well, the wellhead or the production line proximate the wellhead based on the asphaltene content.

The present application discloses a gas logging system, including a degasser configured to degas a sample to separate a gas to be tested; and a detector connected to the degasser and configured to receive the gas to be tested separated by the degasser and perform detection, where the degasser comprises a degassing cover, the degassing cover includes a spherical crown disk surface and a plurality of semipermeable membrane degassing units on the spherical crown disk surface, wherein the plurality of semipermeable membrane degassing units are arranged on the spherical crown disk surface according to the Fibonacci Spiral Rule. The gas logging system provided by the present application may improve the distribution uniformity of a drilling fluid on the degassing cover while increasing arrangement number, and reduce the impact on semipermeable membrane degassing units.

The disclosure presents a technique for predicting the composition of a borehole mud using a thermal conductivity parameter of the mud and a dilution liquid. The mud can be altered by conditions within the borehole, such as material, fluid, and temperature affecting the original mud composition pumped into the borehole location. The mud can be an oil-based, water-based, or another type of mud of a well system. The technique can extract a measured quantity of mud and place it into a mud container. A first thermal conductivity parameter can be calculated for the extracted mud. A dilution liquid can be mixed into the extracted mud in the mud container and a second thermal conductivity parameter calculation can be performed. From the calculated first and second thermal conductivity parameters, the composition of the mud, as well as the fractional proportions of the major components of the mud, can be predicted and computed.

A valve apparatus (400) for a flow system in a subsea oil and gas production installation and a method of use. The valve apparatus comprises an inlet for production flow from the subsea oil and gas production installation, an outlet for production flow, and a flow control valve (420) disposed between the inlet and the outlet. A first flow line (361) in communication with a sampling circuit is disposed between the inlet and the flow control valve, and a second flow line (362) in communication with a sampling circuit is disposed between the outlet and the flow control valve. The flow control valve is operable to be partially closed to create a pressure differential between the first and second flow lines, and thereby drive a production fluid into the sampling circuit.

A method for monitoring pitting corrosion of a production tubing in a hydrocarbon well under downhole conditions during a production process using a coupon segment, the method comprising the steps of placing the coupon segment in the hydrocarbon well at a placement depth, the coupon segment is exposed to produced fluids and comprises an outer layer, an inner layer, and a hollow middle layer comprises a tracer fluid operable to leak into the produced fluids when pitting corrosion penetrates the outer layer, operating the production process in the hydrocarbon well such that produced fluids flow through the production tubing to a surface of the hydrocarbon well and wherein the produced fluids contact the coupon segment such that pitting corrosion occurs on the coupon segment; obtaining a sample of the produced fluids at the surface of the hydrocarbon well; and measuring an amount of the tracer fluid in the sample.

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.