Methods and systems are provided that combine NMR and IR spectroscopy measurements on a rock sample to determine data representing at least one property of the rock sample. In one embodiment, cuttings can be split into first and second lots. Results of an NMR measurement performed on the first lot of cuttings without cleaning can be analyzed to determine pore volume of the cuttings. Results of an IR spectroscopy measurement performed on the second lot of cuttings after solvent cleaning can be analyzed to determine matrix density of the cuttings. Porosity can be determined from the pore volume and matrix density of the cuttings. In another embodiment, combined NMR and IR spectroscopy measurements can be performed on an unprepared rock sample (without solvent cleaning) to characterize properties of kerogen in the rock sample and porosity. In another aspect, a method is provided that employs multi-nucleic NMR measurements to determine porosity.

The embodiments of the present application disclose a method and an apparatus for determining flow rates of components of multiphase fluid. The method comprises: performing a first magnetization treatment and a second magnetization treatment on multiphase fluid in a pipeline in a target oil and gas well, respectively, to obtain first magnetized multiphase fluid and second magnetized multiphase fluid; determining a first echo train signal set and a second echo train signal set corresponding to the first magnetized multiphase fluid and the second magnetized multiphase fluid, respectively; determining contents of an oil phase component, a water phase component, and a gas phase component of the multiphase fluid at a specified horizon position, and determining a flow velocity of the multiphase fluid at the specified horizon position; and determining flow rates of the oil phase component, the water phase component and the gas phase component in the multiphase fluid. The technical solutions provided by the embodiments of the present application can improve the accuracy of the determined flow rate of each component of the multiphase fluid.

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.

A non-invasive NMR based apparatus for measuring a food attribute (moisture, sugar content) in food products comprises a magnetic chamber, an RF pulsing device attached to the magnetic chamber, a sensor receiver, and a data processing unit in communication with the sensor receiver. The pulsing device exposes the food ingredients/snacks to an RF field and produces an NMR response signal that is detected by the sensor receiver. The data processing unit quantitatively measures a food attribute of the food product based on the NMR response signal.

In a first step, a sample liquid is fabricated by mixing a sample formed of a polyester or decomposition products of a polyester into a solvent. The solvent used here contains chloroform and 2,2,2-trifluoroethanol and has an organic base added thereto. The organic base is at least one of a primary amine, a secondary amine, a tertiary amine and a heterocyclic amine. In a second step, the amount of terephthalic acid in the sample liquid is measured through a nuclear magnetic resonance spectroscopy aiming at hydrogen atoms

A non-invasive NMR based apparatus for measuring a food attribute (moisture, sugar content) in food products comprises a magnetic chamber, an RF pulsing device attached to the magnetic chamber, a sensor receiver, and a data processing unit in communication with the sensor receiver. The pulsing device exposes the food ingredients/snacks to an RF field and produces an NMR response signal that is detected by the sensor receiver. The data processing unit quantitatively measures a food attribute of the food product based on the NMR response signal.

There is described a method for determining the relative quantities of the expected components in a multi-component mixture of solids. The proposed quantification method makes use of a time domain nuclear magnetic resonance (TD-NMR) spectrometer and requires that, for each of the expected components in the mixture, a T1 saturation recovery curve (SRCi) is measured and recorded. The saturation recovery curve for the mixture sample (SRCmix) is determined from a measurement of the sample with the spectrometer. The relative amounts of the expected components present in the mixture sample are determined by fitting a linear combination of the component SRCs (SRCi) to the SRCmix. The resulting value of each weighting coefficient in the fit provides the relative proportion of the corresponding component in the overall sample.

A method for generating a log of a value of a property of a fluid in an earth formation versus depth includes: obtaining a plurality of samples of drilling fluid that are entrained with a formation gas and correlating each sample to a depth in a borehole from which the formation gas was entrained in the drilling fluid; extracting the formation gas from each sample to provide a plurality of gas samples; analyzing each formation gas sample to provide a chemical composition of each formation gas sample in the plurality of formation gas samples; and determining a property value of the fluid in the earth formation versus depth using the chemical composition of each formation gas sample in the plurality of formation gas samples to provide the log.

An evaluation method for hydrogen-bearing components, porosity and pore size distribution of organic-rich shale is provided, relating to a technical field of oil and gas development. The evaluation method includes steps of: according to differences among NMR (nuclear magnetic resonance) T.sub.1-T.sub.2 maps of kerogen, oil-adsorbed kerogen, clay minerals of different water-containing conditions, shale, dry shale sample, oil-saturated shale sample and water-saturated shale sample, establishing a classification scheme for each hydrogen-bearing component and a quantitative characterization method for fluid components of the organic-rich shale; with a T.sub.2 distribution of the organic-rich shale after being saturated with oil as a target and a T.sub.2 distribution of the dry shale sample as a basement, subtracting the basement, and obtaining a T.sub.2 distribution of oil in pores; and based on the T.sub.2 distribution of oil in the pores, evaluating the porosity and the pore size distribution of the organic-rich shale. Compared with a conventional method, the present invention shows relatively high innovativeness and credibility, which is beneficial to perfecting analysis of NMR in shale petrophysical measurement.

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.