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.

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.

Various embodiments are generally directed to techniques for monitoring chromatographic fluid flows, such as the flow to and/or from one or more reservoirs used in chromatographic operations, for instance. In many embodiments, the chromatographic operations may include one or more of High Performance Liquid Chromatography (HPLC), Ultra Performance Liquid Chromatography (UPLC), Ultra Performance Convergence Chromatography (UPC2), and the like. Several embodiments are particularly directed to a chromatographic fluid flow device (CFFD) for monitoring a change in density of a chromatographic fluid in a tube, such as by detecting the presence or absence of gas in the tube with an ultrasonic bubble detector. In various embodiments, the chromatographic fluid may include a solvent, a sample, or waste associated with a chromatographic operation.

Various embodiments are generally directed to techniques for monitoring chromatographic fluid flows, such as the flow to and/or from one or more reservoirs used in chromatographic operations, for instance. In many embodiments, the chromatographic operations may include one or more of High Performance Liquid Chromatography (HPLC), Ultra Performance Liquid Chromatography (UPLC), Ultra Performance Convergence Chromatography (UPC2), and the like. Several embodiments are particularly directed to a chromatographic fluid flow device (CFFD) for monitoring a change in density of a chromatographic fluid in a tube, such as by detecting the presence or absence of gas in the tube with an ultrasonic bubble detector. In various embodiments, the chromatographic fluid may include a solvent, a sample, or waste associated with a chromatographic operation.

The invention provides a method, and apparatus, for determining the degree of separation (DOS) of a polymer solution into a polymer-rich stream and a solvent-rich stream, said method comprising the following: adding to a liquid-liquid separation vessel the polymer solution, which comprises a polymer, a solvent and an anti-solvent; separating the polymer solution into a polymer-rich stream and a solvent-rich stream; removing at least some the polymer-rich stream from at least one outlet P on the vessel, and measuring the actual solution density of this polymer-rich stream using at least one flow meter; removing at least some of the solvent-rich stream from at least one other outlet S on the vessel, and measuring the actual density of the solvent-rich stream using at least one flow meter; and wherein the degree of separation (DOS) is determined by the following equation (Eqn. 1):

DOS=[actual solution density (polymer-rich steam)actual solution density (solvent-rich stream)]/[theoretical solution density (polymer-rich stream)theoretical solution density (solvent-rich stream)](Eqn. 1).

The invention provides a method, and apparatus, for determining the degree of separation (DOS) of a polymer solution into a polymer-rich stream and a solvent-rich stream, said method comprising the following: adding to a liquid-liquid separation vessel the polymer solution, which comprises a polymer, a solvent and an anti-solvent; separating the polymer solution into a polymer-rich stream and a solvent-rich stream; removing at least some the polymer-rich stream from at least one outlet P on the vessel, and measuring the actual solution density of this polymer-rich stream using at least one flow meter; removing at least some of the solvent-rich stream from at least one other outlet S on the vessel, and measuring the actual density of the solvent-rich stream using at least one flow meter; and wherein the degree of separation (DOS) is determined by the following equation (Eqn. 1):

DOS=[actual solution density (polymer-rich steam)actual solution density (solvent-rich stream)]/[theoretical solution density (polymer-rich stream)theoretical solution density (solvent-rich stream)](Eqn. 1).

A method for determining properties of a hydrocarbon-containing gas mixture includes determining a thermal conductivity value, density measurement, viscosity measurement, and temperature and pressure. The method also includes determining a hydrogen content of the gas mixture on the basis of the thermal conductivity value and the temperature and pressure, determining a density measurement and associated temperature and pressure, and determining the mean molar mass or standard density on the basis of the density measurement and the temperature and pressure. The method further includes determining the mean molar mass or standard density of a hydrogen-free residual gas mixture based on the mean molar mass or standard density and the hydrogen fraction, determining the Wobbe index of the residual gas mixture based on the viscosity measurement and the temperature and pressure, and determining a calorific value based on the mean molar mass or standard density and the Wobbe index.

A method for determining properties of a hydrocarbon-containing gas mixture includes determining a thermal conductivity value, density measurement, viscosity measurement, and temperature and pressure. The method also includes determining a hydrogen content of the gas mixture on the basis of the thermal conductivity value and the temperature and pressure, determining a density measurement and associated temperature and pressure, and determining the mean molar mass or standard density on the basis of the density measurement and the temperature and pressure. The method further includes determining the mean molar mass or standard density of a hydrogen-free residual gas mixture based on the mean molar mass or standard density and the hydrogen fraction, determining the Wobbe index of the residual gas mixture based on the viscosity measurement and the temperature and pressure, and determining a calorific value based on the mean molar mass or standard density and the Wobbe index.

A multiphase flowmeter for detection of fluid flow by monitoring of vortex frequency or perturbation time of flight. The flowmeter includes a bluff body to facilitate formation of vortices during a consistent phase of a flowing fluid. Thus, monitoring frequency of the vortices may be employed to ascertain flowrate. Further, the bluff body may also facilitate formation of perturbations during transitioning phase of the fluid and include perturbation sensors at multiple known locations along the flow-path. Thus, analysis of perturbation detection times at the different locations may be used to ascertain flowrate even in the absence of vortices.

A multiphase flowmeter for detection of fluid flow by monitoring of vortex frequency or perturbation time of flight. The flowmeter includes a bluff body to facilitate formation of vortices during a consistent phase of a flowing fluid. Thus, monitoring frequency of the vortices may be employed to ascertain flowrate. Further, the bluff body may also facilitate formation of perturbations during transitioning phase of the fluid and include perturbation sensors at multiple known locations along the flow-path. Thus, analysis of perturbation detection times at the different locations may be used to ascertain flowrate even in the absence of vortices.