A testing apparatus for testing a fluid and a loss control material (LCM) is provided. The testing apparatus includes a testing chamber having an upstream end, a downstream end, a device central axis, and a general flow direction. The testing chamber includes a chamber body having an upstream cap, a downstream cap, a first chamber wall, and a second chamber wall. The first chamber wall has a first diameter and in part defines a first chamber interior, the second chamber wall has a second diameter, the first diameter is less than the second diameter, and both the first chamber wall and the second chamber wall are positioned relative to one another such that an annulus is defined in part in between. The traversal of the fluid and the LCM along the fluid flow path is restricted by a flow restriction.

The present disclosure describes methods and systems, including computer-implemented methods, computer program products, and computer systems, for measuring a water cut for hydrocarbon fluid in a production pipe. One method includes transmitting a microwave through a first waveguide attached to a production pipe, wherein the microwave is directed to the hydrocarbon fluid in the production pipe; and obtaining, measurement results based on reflection or propagation of the microwave, wherein the measurement results are used to determine a water cut of the hydrocarbon fluid.

A drilling fluid flowback tracking system and method for determining quantities and qualities of drilling fluid returned from the wellhead in drilling operations, providing a frame, a receiving pipe, a riser pipe, and a surge suppressor for conveying returned drilling fluid, a tapered fluid bin having a calibrated drain slot, which retains fluid at a level corresponding to the inflow rate of the fluid, and flow rate marks for visual correlation of the highest level of outflow with the flow rate of the inflow. Collection and retention of data is further provided through sensors in an inline sensor housing communicating through a data cable with a data collection unit. Remote access to the data collection unit is further provided through a data transceiver and remote data unit.

A system and a method for applying .sup.13C or .sup.1H NMR spectroscopy to a sample of oil in order to calculate and assign an indicative property such as cetane number, pour point, cloud point, aniline point and/or octane number of a gas oil or naphtha fraction of the crude oil.

A process is provided for the determination of oil dispersant effectiveness. A submersible dispersant sensing platform is passed across a body of water. The platform has a plurality of sensors including a multichannel fluorometer and a particle size analyser, and each sensor produces an output data stream. The body of water is continuously analysed at a predetermined depth profile below the surface of the body of water. Hydrodynamic and environmental condition data is collected proximate in time and location to the output data from the dispersant sensing platform. The environmental condition data includes one or more of ambient temperature, body or water temperature, salinity of the body of water, wind speed, location, mixing energy of the body of water and derivatives thereof. Oil and dispersant data is provided which includes characteristics of the dispersant and of oil samples prior to the application of the dispersant. The output data stream, the hydrodynamic and environmental condition data, and the oil and dispersant data is processed to generate an indicator of the state of dispersion of the oil and of the oil dispersant efficiency under the hydrodynamic and environmental conditions the oil is exposed to. A system for the determination of oil dispersant efficacy is also provided.

A process is provided for the determination of oil dispersant effectiveness. A submersible dispersant sensing platform is passed across a body of water. The platform has a plurality of sensors including a multichannel fluorometer and a particle size analyser, and each sensor produces an output data stream. The body of water is continuously analysed at a predetermined depth profile below the surface of the body of water. Hydrodynamic and environmental condition data is collected proximate in time and location to the output data from the dispersant sensing platform. The environmental condition data includes one or more of ambient temperature, body or water temperature, salinity of the body of water, wind speed, location, mixing energy of the body of water and derivatives thereof. Oil and dispersant data is provided which includes characteristics of the dispersant and of oil samples prior to the application of the dispersant. The output data stream, the hydrodynamic and environmental condition data, and the oil and dispersant data is processed to generate an indicator of the state of dispersion of the oil and of the oil dispersant efficiency under the hydrodynamic and environmental conditions the oil is exposed to. A system for the determination of oil dispersant efficacy is also provided.

A method for simulating a microemulsion system in a chemical enhanced oil recovery process is disclosed. The method includes receiving a geological model of a subsurface reservoir that defines a grid having a plurality of cells, determining a surfactant concentration for each cell based on a volume of surfactant and a volume of water within the cell and independently from a volume of oil in the cell, and simulating fluids flowing in the subsurface reservoir. Results from simulation can be used to optimize a chemical enhanced oil recovery process in a subsurface reservoir.

The profiler system and method measure multiphase fluid with or without a container. The profiler includes at least one sensor module. Each sensor module extends a set distance from an upper end to a lower end of the module. This set distance determines proximal and distal measurement zones corresponding to different portions of multiphase fluid. The zones can be aligned within the container to define a sample volume with a relative position from top to bottom within the container. The profiler measures fluid characteristics with location data based on the sample volume or zones so that a profile of the multiphase fluid includes position of the portions of multiphase fluid measured. The safety and accuracy of storage in a container or active flow in a flow connector or open water can be maintained, even as the multiphase fluid dynamically changes while in storage and while in active flow.

A pressure cell for sum frequency generation spectroscopy includes: a metal pressure chamber; a heating stage that heats a liquid sample; an ultrasonic stage that emulsifies the liquid sample; a chamber pump that pressurizes an interior of the metal pressure chamber; and a controller that controls the chamber pump, the ultrasonic stage, and the heating stage to control a pressure of the interior of the metal pressure chamber, an emulsification of the liquid sample, and a temperature of the liquid sample, respectively. The metal pressure chamber includes: a liquid sample holder that retains the liquid sample; a removable lid that seals against a base; a window in the removable lid; a sample inlet that flows the liquid sample from an exterior of the metal pressure chamber to the liquid sample holder at a predetermined flow rate; and a sample outlet.

An NIR analyzer with the optical probes across a pipe, or in a bypass configuration, after a stabilizer in an oil or condensate production plant. Prior to use, liquid samples from the plant are analyzed in a chemical lab to obtain reference vapor pressure or compositional values. A chemometric model using known techniques is then built with the captured absorption spectra and the reference lab results. Preprocessing methodologies can be used to help mitigate interferences of the fluid, instrument drift, and contaminate build up on the lenses in contact with the fluid. The chemometric model is implemented through the NIR analyzer as the calibration curve to predict the vapor pressure or other values of the flowing fluid in real time.