This invention is useful for determining the permeability of a geological formation using .sup.1H NMR diffusion measurements acquired in the laboratory and using downhole .sup.1H NMR well logging. The current technology for obtaining formation permeability downhole using NMR is not adequate for low-permeability, unconventional source rock formations with high organic content. This new method uses laboratory .sup.1H NMR diffusion measurements for creating continuous downhole well logs of the mobile-hydrocarbon permeability of the hydrocarbon-filled pore space of downhole geological formations.

The following invention is used for determining the relative permeability of a fluid in a rock for three different phases: water, oil, and gas, in both conventional and unconventional formations. The permeability of a phase describes how much it can flow in porous media given a pressure gradient and is useful in evaluating reservoir quality and productivity. The following invention is a method to determine the three-phase relative permeabilities in both conventional and unconventional formations using NMR restricted diffusion measurements on core with NMR-active nuclei, combined with centrifugation of the core. In addition, the tortuosity, pore size (surface-to-volume ratio), fluid-filled porosity, and permeability is determined for each of the three phases in a rock.

A gas oil separation plant (GOSP) and method for receiving crude oil from a wellhead and removing gas, water, and salt from the crude oil, and discharging export crude oil. The GOSP includes online analyzer instruments for performing online analysis of salt concentration in multiple streams in the GOSP. Based in part on the online analysis, the salt content in the export crude oil may be determined and the flowrate for wash water supplied to the desalter vessel may be specified.

A method for using water proton transverse relaxation rate R.sub.2(T) to monitor, in real time, the sedimentation rates of multiphase mixtures such as drug products and drug substances. The method provides a practical application of wNMR as an analytical tool to study and provide higher quality and more efficient multiphase mixtures.

The invention relates to an NMR system, and more particularly to an NMR measurement unit including a flow channel for separating a sample from a fluid stream in a process channel, a magnet arranged relative to flow channel for creating a magnetic field in part of flow channel, a coil arranged relative to flow channel for exciting NMR active nuclei of the sample in flow channel and for receiving the frequency pulse that returns to coil from NMR active nuclei, a frame comprising a fastening flange for sealing NMR measurement unit to process channel and a chamber that is closed relative to fluid stream and connected to fastening flange, arranged to be installed mainly inside process channel, within which chamber magnet and coil are arranged and through which chamber the flow channel passes, the frame installable such that flow channel is positioned inside process channel.

The present disclosure provides a method of measuring a percent solids content (PSC) of solids by mass in a slurry catalyst composition, where the solids include a catalyst. The method includes obtaining a first time domain (TD) .sup.1H-nuclear magnetic resonance (NMR) spectrum using a time domain (TD)-NMR spectrometer and a test sample of the slurry catalyst composition from which a value of a voltage signal (a) that represents the slurry catalyst composition is determined. A second TD .sup.1H-NMR spectrum using the TD NMR spectrometer is obtained for a neat sample of the suspension liquid for the solids of the slurry catalyst composition, where a value of a voltage signal (b) from the second TD .sup.1H-NMR spectrum that represents the suspension liquid for the solids of the slurry catalyst composition is determined. The percent solids content (PSC) of solids in a slurry catalyst composition is then determined with Equation I: PSC=(1a/bd.sub.b/d.sub.a)100% Equation I where x represents mathematical multiplication, a and b are as described above, db is a density of the suspension liquid for the solids of the slurry catalyst composition and d.sub.a is a density of the slurry catalyst composition.

Nuclear magnetic resonance (NMR) gas isotherm techniques to evaluate wettability of porous media, such as hydrocarbon reservoir rock, can include constructing a NMR gas isotherm curve for a porous media sample gas adsorption under various pressures. A hydrophobic or hydrophilic nature of the porous media sample can be determined using the NMR gas isotherm curves. A wettability of the porous media sample can be determined based on the NMR gas isotherm curve. The wettability can be determined for porous media samples with different pore sizes. In the case of reservoir rock samples, the determined wettability can be used, among other things, to model the hydrocarbon reservoir that includes such rock samples, to simulate fluid flow through such reservoirs, or to model enhanced hydrocarbon recovery from such reservoirs.

The present invention provides a device and a method for measuring fluid saturation in nuclear magnetic resonance (NMR) on-line displacement, the method comprising: measuring a nuclear magnetic resonance (NMR) T2 spectrum under the dead volume filling of the on-line displacement system as displacing phase fluid and the core to be measured as saturated nuclear magnetic detection phase fluid to generate a calibrated T2 spectrum; measuring a nuclear magnetic resonance (NMR) T2 spectrum of a process in which the core to be measured is converted from a saturated displaced phase fluid into a displacing phase fluid to generate a displacement process T2 spectrum; generating the fluid saturation of the on-line displacement system in real time according to the generated calibrated T2 spectrum and the displacement process T2 spectrum. The present invention achieves the purpose of improving measurement precision of fluid saturation in the on-line displacement process.

A method for separating oil-water two-phase NMR signals by using dynamic nuclear polarization comprising: using a combination of a non-selective free radical and a selective relaxation reagent to selectively enhance an NMR signal of an oil phase or a water phase, the relaxation reagent being capable of selectively suppressing dynamic polarization enhancement of the water phase or oil phase, thus achieving the polarization enhancement of a single fluid phase in the mixed fluid phases and realizing separation of the two-phase signals; or using a selective free radical to selectively enhance the NMR signal of the oil phase or the water phase, thus achieving the polarization enhancement of a single fluid phase in the mixed fluid phases and realizing separation of the oil-water two-phase NMR signals. The method is simple and easy to operate, has a short test time, and can efficiently separate NMR signals of oil and water phases.

Herein methods and systems for determining matrix or grain density of a subsurface formation are described. This includes measuring in-air mass of a fluid-saturated sample of the subsurface formation, wherein the in-air mass comprises mass of matrix or grains of the sample, mass of a fluid surrounding the sample, and mass of the fluid inside the sample. The volume of the fluid inside the sample, V.sub., and volume of the fluid surrounding the sample, V.sub.sur, are determined using nuclear magnetic resonance (NMR). The fluid-saturated sample can then be submerged in a predetermined volume of a weighing fluid and mass of the fluid-saturated sample without the surrounding fluid in the weighing fluid, m.sub.f is measured. Using the measured and determined values one can determine the volume of the sample without the surrounding fluid, V.sub.c, the bulk density of the fluid-saturated sample without the surrounding fluid, .sub.b, the volume of the matrix, V.sub.m, and the matrix or grain density of the subsurface formation, .sub.m.