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.

Contamination estimation of a mud filtrate or reservoir sample requires a robust handle on the properties of mud filtrate at downhole conditions. Coupling acquired data with downhole measured data provides a robust estimation of contamination by encompassing the entire available data. Downhole density of the mud filtrate sample may be estimated based on a characteristic of the mud filtrate sample. A density of a formation fluid of the reservoir may be determined using a formation tester tool. The contamination of the formation fluid may be estimated based on the clean fluid density and the estimated mud filtrate density by, for example, using a material balance equation or ratio. An estimated pump-out time for the formation fluid may be determined based on the estimated contamination and a trend of the estimated contamination of the formation fluid.

A degasser system may comprise a mass flow controller device and a sample pump coupled to a sample degasser for controlling the dilution of gases extracted from drilling fluid in the sample degasser by a dilution fluid, such as nitrogen gas. The mass flow controller may inject the dilution fluid into the tank of the sample degasser to dilute the gases extracted from the drilling fluid. The dilution fluid may be aspirated or sparged into the sample degasser. The sample pump may extract a sample of the gases separated from the drilling fluid by the sample degasser. The rate of injection of the dilution fluid into the sample degasser and the rate of extraction of the gas sample from the drilling fluid may be adjustable to control the dilution of the gas sample for analysis.

A device and method for collecting sample fluids from an underground source which includes sample wells terminating in a corrugated conduit and sieve. The sampling regions for each sample well is separated by a grout or expanding seal barrier. Negative pressure is optionally applied to extract fluids from the underground matrix for sampling. The device can also be used for remediating an environmental contaminant from soil or aquifers. Upon identification of at least one environmental contaminant, a remediation composition is injected into the soil or aquifer using the sampling wells of the device. The remediation fluids can be directed to specific locations by selectively utilizing one or more sampling wells to inject the remediation fluid.

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.

A method of monitoring a fluid is described comprising introducing a luminescent nanoparticle into the fluid; removing a fluid sample from the fluid; adding a reagent to the fluid sample to vary the luminescence behaviour of the luminescent nanoparticles and/or of other luminescent species present in the fluid; analysing the luminescence of the modified fluid sample to determine an amount of the nanoparticle present therein. A use of a tracer based on these principles is also described.

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.

A method for processing a fluid that includes receiving the fluid into a testing skid as an inlet flow, the fluid comprising a multi-phase fluid produced from a well. The method includes controlling the inlet flow in a manner whereby an at least a portion of the inlet flow is transferred as a diverted stream to a separation component associated with the testing skid, and using the separation component to restructure an at least a portion of the diverted stream into stratified flow regimes. The stratified flow regimes entail a gas phase and a liquid phase. The method includes using the water cut meter to determine a water:oil ratio present in the liquid phase; and discharging the liquid phase from the testing skid.

Provided is a water retort apparatus, methods of using the water retort apparatus, and systems including the water retort apparatus. An example of the water retort apparatus comprises a sample test cell, a heating element configured to heat the sample test cell to a temperature between about 212° F. and about 400° F., a condenser in fluidic communication with the sample test cell, a sight glass in fluidic communication with the condenser, a camera configured to capture images of the sight glass, and a controller configured to analyze the images captured by the camera and estimate a volume of water in the sight glass.

Systems, methods and devices for analyzing a sample of fluid extracted from a hydrocarbon-producing geological formation to detect a quantitative amount of hydrogen sulfide or disclosed. The systems methods and devices involve including a scavenger within a sample compartment to react with the hydrogen sulfide therein. The concentration of hydrogen sulfide in the sample may be derived as a function of the amount of scavenger remaining in the sample after reaction with hydrogen sulfide, an amount of byproduct of a reaction between the scavenger and the hydrogen sulfide, or an amount of hydrogen sulfide as measured following a secondary reaction that releases the hydrogen sulfide from the scavenger.