To separate porosity from surface roughness, length scales for pore size and surface roughness are identified. These length scales are determined from surface roughness measurements and confirmed via NMR pore body calculations and pore size capillary pressure measurements. A filter removes pore contribution to surface roughness measurements and delivers intrinsic surface roughness. Additional filters and methods determine the minimum magnification on which to base surface roughness calculation, based on size of the field of view and where measured surface roughness approaches intrinsic surface roughness as magnification increases but larger magnification increase sampling time and difficulty. Sample irregularities, such as saw marks, are also filtered out or determined to be too large to remove via filter and another area of measurement is located. With the pore corrected quantification of surface roughness, surface relaxivity and pore distribution can be calculated with greater accuracy.

An experimental device and method for supercritical CO.sub.2/H.sub.2O mixed fluid huff and puff for shale oil development includes a CO.sub.2 storage tank, a water vapor generator, a mixing vessel, and a core holder; the CO.sub.2 storage tank and the water vapor generator are in communication with the mixing vessel; a first pressure gauge and a hygronom are connected to an upper end of the mixing vessel, and a displacement pump is connected to a lower end of the mixing vessel; the mixing vessel is connected to an inlet end of the core holder; the core holder is connected to an inlet end of a drying pipe, and the measuring cylinder is disposed upside down in a liquid containing dish, where the liquid containing dish and the measuring cylinder are filled with a saturated sodium carbonate solution.

A method for NMR measurements on borehole materials, e.g., sidewall cores, is based on performing a standard measurement in substantially homogeneous magnetic fields with a sensitivity volume covering an entire sample and a measurement on a fragment of the sample (local measurement), the fragment having a predetermined volume independent of the irregularities of the sample shape (e.g., irregular shaped edges). The fragment of the sample is selected using a switchable static magnetic field gradient or a localized radio-frequency magnetic field. The homogeneous and the local measurement data are processed jointly to obtain volume normalized NMR relaxation data (in porosity units), the processing also using a calibration sample data. A measurement apparatus with an automated sample transfer can be used to implement the method in order to perform high-throughput NMR relaxation measurements that do not require independent measurement of the sample volume.

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.

Tools and methods are used to determine the oil, water, and solids volume fractions in a drilling fluid at the rig site. The volume fractions can be determined in-line with returned drilling fluid by using an NMR magnet and a flow line or sample chamber that receives a fluid sample and loads it into the NMR magnet. Using an RF probe, spectrometer, and computing device, data processing and interpretation of NMR data from the spectrometer is performed, while also raising a flag when iron contamination exceeds a predefined threshold.

A method, system and device for comprehensively characterizing a lower limit of oil accumulation of a deep marine carbonate reservoir is provided, aiming to solve the problem that the prior art cannot: accurately determine the lower limit of oil accumulation of the deep marine carbonate reservoir, which leads to the difficulty in predicting and identifying deep effective reservoirs. The method includes: determining lower limit porosity and permeability for oil accumulation based on a boundary line; determining lower limit porosity and permeability for oil accumulation based on a movable oil ratio of a core sample; determining a lower limit pore throat radius for oil accumulation based on a mercury injection experiment; and comprehensively characterizing the lower limit of oil accumulation of a deep marine carbonate reservoir to be predicted. The method, system and device can predict and identify deep effective reservoirs.

Described herein are methods for removing the vibration induced additional signal obtained during downhole NMR operations. The additional signal is removed by analyzing a number of instances of data sets neighbors, at either the raw echo, reconstructed echoes, or the spectrum which results from inversion. A number of neighboring data instances are analyzed together to find the minimal (lowest) common values in each. Thereafter, the minimal value replaces the previous value across the data instances, thereby removing the extra signal.

The present disclosure relates to a method and system for predicting a disturbance response to an injection of carbon dioxide into a multi-scale rock mass. The method includes: predicting a disturbance response to an injection of supercritical carbon dioxide into a multi-scale rock matrix; predicting a disturbance response to an injection of supercritical carbon dioxide into a multi-scale rock mass structure; and predicting a disturbance response to an injection of supercritical carbon dioxide into a multi-scale rock matrix-rock mass structure system. The method in the present disclosure can accurately analyze a cross-scale spatio-temporal evolution process of the multi-scale rock mass and seepage mechanics under disturbance of the injection of supercritical carbon dioxide.

A method for assessing and/or removing one or more motion effects from logging while drilling (LWD) measurement data may include disposing a borehole logging tool into a borehole, wherein the borehole logging tool is disposed on a bottom hole assembly (BHA), taking one or more measurements at one or more depth in the borehole with the borehole logging tool to form a measurement data set, and identifying one or more pipe breaks and one or more stations in the measurement data set. The method extracts measurement data at one or more pipe breaks and one or more stations to form a non-motion measurement data set, providing answer products from the non-motion measurement data set. The method may further include removing the one or more pipe breaks and one or more stations from the measurement data set to form a corrected measurement data set and providing one or more answer products.

Embodiments described herein generally relate to systems, tools, and methods for flow assurance monitoring within pipe structures. In an embodiment is provided a method of determining at least one property of a mixture flowing through a system that includes introducing an inhibitor to a fluid flowing through the system to form the mixture; exposing the mixture to electromagnetic energy to induce at least one paramagnetic response from at least one diamagnetic species present in the mixture flowing through the system; performing electron paramagnetic resonance (EPR) spectroscopy on the at least one paramagnetic response to generate an EPR spectrum; and determining the at least one property of the mixture based on the EPR spectrum. Apparatus for determining fluid properties and systems for extracting hydrocarbons from a subterranean reservoir are also provided.