26results about "Detection using electron/nuclear magnetic resonance" patented technology

The present application provides a kind of shale oil oil saturation measurement method, device, storage medium and electronic equipment, belong to petroleum exploration technical field.The shale oil oil saturation measurement method includes: obtaining two-dimensional nuclear magnetic T1-T2 spectrum, the two-dimensional nuclear magnetic T1-T2 spectrum is using the first pulse sequence of multiple waiting time, fluid distribution in the field core object is identified based on the two-dimensional nuclear magnetic T1-T2 spectrum, and the distribution characteristics of multiple core fluids are obtained.Based on the distribution characteristics of various core fluids, the oil saturation of various core fluids is calculated according to the preset saturation calculation model to obtain the oil saturation of shale oil.The oiliness can be qualitatively and quantitatively evaluated, the oil saturation can be accurately calculated, the oiliness can be quantitatively evaluated, and the well site rapid interpretation and evaluation can be realized.

Methods and systems herein may perform nuclear magnetic resonance measurements, and nuclear magnetic resonance tools, the method and systems comprising: acquiring, using an NMR sensor a first NMR signal from a volume in a subterranean region, wherein the first NMR signal is acquired using a first acquisition window. Further, acquiring, using the NMR sensor a second NMR signal from a volume in the subterranean region, wherein the second NMR signal is acquired using a second acquisition window different from the first acquisition window, wherein the first NMR signal and the second NMR signal form an NMR relaxation data; determining, using the first NMR signal and the second NMR signal, a correction term. Finally, the correction term may be used to acquire a corrected relaxation data set.

A method for automatically determining an NMR pulse sequence for use in downhole NMR measurements, such as NMR logging while drilling measurements, includes receiving a set of expected NMR measurements and evaluating the received set of expected NMR measurements using a bilevel optimization to determine a pulse sequence for the downhole NMR measurement.

This application relates to the field of geophysical exploration technology and provides a high-precision nuclear magnetic resonance (NMR) detection method for organic pollution. The method includes: transmitting a DC pulse P1; applying an amplitude-sweeping AC pulse AFP1 after turning off the DC pulse P1; turning off the amplitude-sweeping AC pulse AFP1 and transmitting a DC pulse P2; after turning off the DC pulse P2, applying an adiabatic half-wave pulse AHP1 and acquiring a first induced voltage signal; applying an adiabatic half-wave pulse AHP2 at the moment after turning off the adiabatic half-wave pulse AHP1 and acquiring a second induced voltage signal; applying an amplitude-sweeping AC pulse AFP2 after turning off the adiabatic half-wave pulse AHP2, and repeatedly applying the amplitude-sweeping AC pulse AFP2 after each time it is turned off, acquiring a third induced voltage signal. This application can selectively suppress groundwater signals and enhance the sensitivity of organic pollution signals.

A method of estimating a wettability characteristic of a rock material includes acquiring a plurality of T2 distributions based on nuclear magnetic resonance (NMR) measurements of a rock material unde

A method may include determining various adaptive weights using a machine-learning model, first simulation data, and second simulation data. The method may further include determining predicted simulation data for a time step of the reservoir simulation using the adaptive weights, the first simulation data, the second simulation data, grid model data, and various reservoir simulation parameters. The method may further include determining whether the predicted simulation data satisfies a predetermined criterion. The method may further include determining, in response to determining that the predicted simulation data fails to satisfy the predetermined criterion, updated simulation data for the time step of the reservoir simulation based on the predicted simulation data, the grid model data, the reservoir simulation parameters, a search method, and the reservoir equations.

Systems, methods, and apparatus, including computer programs encoded on computer-readable media, for obtaining nuclear magnetic resonance (NMR) measurements of a subsurface formation in a well system. One or more NMR pulses are generated downhole using an NMR tool of the well system. It is determining whether an amplitude of an NMR echo signal is less than or equal to a threshold level or the NMR echo signal is not present. Ringing noise associated with the one or more NMR pulses is measured when the amplitude of the NMR echo signal is less than or equal to the threshold level or the NMR echo signal is not present. The ringing noise is cancelled from the NMR measurements, and properties of the subsurface formation are determined from the NMR measurements after cancelling the ringing noise.

A method may include acquiring NMR data and sonic data for a borehole in a subsurface geologic region; inverting the NMR data and the sonic data to determine volume fractions for a number of classes of pore types, where the classes include shape and size-based classes; and characterizing the subsurface geologic region based on the volume fractions for the number of classes.

This invention relates to a method for detecting and locating buried targets based on a pod optimization algorithm, comprising the following steps: acquiring data synchronously collected by two optically pumped magnetometers and performing differential processing to obtain a magnetic anomaly fingerprint curve; extracting key time-frequency domain features from the magnetic anomaly fingerprint curve and obtaining a gradient field based on the magnetic anomaly fingerprint curve; and detecting and locating the buried target based on the key time-frequency domain features and the gradient field using a parameter inversion model based on the pod optimization algorithm. By performing high-precision, high-resolution detection and analysis of the weak magnetic field anomalies caused by buried targets, the target can be effectively detected and quickly identified. This invention utilizes the anomalous signals caused by the magnetic differences between the target and its surrounding environment, combined with advanced signal processing and parameter inversion algorithms, to achieve accurate judgment of the target's location and properties. This technology is not only efficient and fast but also has non-contact, long-distance detection capabilities, which can significantly reduce the dangers faced by workers.

The present disclosure describes methods and systems for determining source rock potential in a subterranean region of a hydrocarbon reservoir. One method includes receiving, an electron spin resonance (ESR) image from an in-situ ESR scanner that is attached to a wellbore at a first subterranean location, wherein the wellbore extends into the subterranean region of the hydrocarbon reservoir; determining, a spin concentration level of a source rock in the first subterranean location based on the ESR image; and determining, the source rock potential at the first subterranean location based on the determined spin concentration level.

A method of measuring petrophysical information from a crushed porous media including performing one or more NMR measurements on the porous media fully submerged in an NMR visible fluid, performing one or more NMR measurements on the porous media alone following centrifugation, performing one or more NMR measurements on the porous media after rinsing with a NMR invisible fluid, and analyzing the NMR measurements to extract a petrophysical property.

A method for automatically determining an NMR pulse sequence for use in downhole NMR measurements, such as NMR logging while drilling measurements, includes receiving a set of expected NMR measurements and evaluating the received set of expected NMR measurements using a bilevel optimization to determine a pulse sequence for the downhole NMR measurement.

Methods and or systems herein may be utilized for evaluating least one reactive component within a subsurface formation, comprising: disposing a downhole tool into the subsurface formation; introducing into the subsurface formation at a targeted depth a contrast agent composition. Further, methods and systems may be configured for performing one or more formation logging measurements capable of detecting one or more reaction products or byproducts or changes in the at least one reactive component within the subsurface formation fluid with the downhole tool. Additionally, methods and systems may be configured for analyzing the one or more formation logging measurements to at least one of confirm, characterize, presence, spatial distribution, and concentration of the reactive component within the subsurface formation fluid.

A method of estimating the primary and secondary acoustic velocities, Vp and Vs, of formation surrounding a first wellbore includes obtaining well logging data for a multiplicity of other wellbores to collect, for each other wellbore a plurality of input data sets including at least a Nuclear Magnetic Resonance logging data set, and an element composition scanning data set. The operation further collects, for each other wellbore, at least one output data set including a primary and secondary velocity data set. The method incudes training or establishing at least one regression model using said input and output data sets, obtaining well logging data for said first wellbore to obtain a corresponding plurality of input data sets, and applying the obtained corresponding plurality of input data sets to the trained or established regression model to generate as an output of the regression model, an output data set for the first wellbore including a primary and secondary velocity data set.

The present application relates to a kind of natural gas hydrate three-phase saturation acquisition method and device, equipment, medium, it is related to formation evaluation technical field, comprising: based on neutron logging data establishes the neutron porosity logging interpretation model of target well mixed section, and establishes the neutron porosity interpretation model of pure hydrate section similar to the lithology of target well mixed section and adjacent;Based on nuclear magnetic resonance logging data establishes the nuclear magnetic porosity logging interpretation model of target well mixed section;Establish the nuclear magnetic porosity interpretation model of pure hydrate section similar to the lithology of target well mixed section and adjacent;Based on each model, average formation porosity, average neutron porosity and average nuclear magnetic porosity, three-phase saturation is obtained by solving.This application provides the acquisition method, is based on nuclear magnetic resonance logging and neutron logging to establish nuclear magnetic-neutron interpretation model, accurately obtains the hydrate, free gas, water three-phase saturation of mixed section, provides accurate reservoir parameter for hydrate resource quantity evaluation.

A method may include determining various adaptive weights using a machine-learning model, first simulation data, and second simulation data. The method may further include determining predicted simulation data for a time step of the reservoir simulation using the adaptive weights, the first simulation data, the second simulation data, grid model data, and various reservoir simulation parameters. The method may further include determining whether the predicted simulation data satisfies a predetermined criterion. The method may further include determining, in response to determining that the predicted simulation data fails to satisfy the predetermined criterion, updated simulation data for the time step of the reservoir simulation based on the predicted simulation data, the grid model data, the reservoir simulation parameters, a search method, and the reservoir equations.

The present invention falls within the area of well logging to evaluate formations in oil and gas producing fields. Particularly, the present invention describes a method for generating synthetic T1-T2 maps from marginal distributions of nuclear magnetic resonance logging tools, wherein the method comprises: decomposing marginal distributions of T1 and T2 relaxation times into an initial sum of log-normal functions with the same amplitudes and different means and standard deviations; setting the initial amplitudes, means and standard deviations so that the sum of log-normal functions corresponds to the marginal distributions of T1 and T2; and using the amplitudes, means and standard deviations set in a sum of two-dimensional log-normal functions to generate a synthetic T1-T2 map.

A method is provided for automatically classifying grains, pores, or both of a formation sample. The method includes receiving a digital image representation of the formation sample, and identifying a plurality of pores, grains, or both in the digital image representation. The method also includes computing a plurality of geometric features associated with the pores, grains, or both in the digital image representation, and inputting the geometric features into an unsupervised machine learning model. The unsupervised machine learning model determines a label for each identified pore and grain, the label being a pore-type or a grain-type, and the plurality of geometric features and the labels determined for each pore, grain, or both, are input into a supervised machine learning model. The supervised machine learning model determines a final classification of a pore-type for each pore and a grain-type for each grain in the digital image representation of the formation sample.

The application discloses a method and device for identifying coexistence of natural gas hydrate and free gas and electronic equipment. The method comprises the following steps: obtaining the measured value of formation resistivity and the measured value of nuclear magnetic porosity of the reservoir to be interpreted of the target well; calculating the water saturation of the reservoir to be interpreted according to the measured value of formation resistivity and the pre-calculated formation water resistivity, formation porosity, lithology coefficient and preset saturation index; based on the nuclear magnetic resonance logging porosity calculation model, taking the reservoir to be interpreted as a pure gas layer as a hypothetical condition, substituting the water saturation, and forward calculating the nuclear magnetic porosity calculation value of the reservoir to be interpreted under the condition of the pure gas layer; and according to the nuclear magnetic porosity calculation value and the measured value of nuclear magnetic porosity, constructing an identification chart of the reservoir to be interpreted to identify whether the reservoir to be interpreted contains natural gas hydrate. The application can accurately identify the coexistence of hydrate and free gas under the condition of lacking expensive core data and lacking shear wave data based on the measured data on site.

Systems and methods for performing local optimization of rock property estimation in geological formations are provided. A method includes: drilling into a rock formation using first drilling parameters, acquiring local data from a first sample from the drilling, acquiring test data from a second sample, selecting a local model input and output, receiving a pre-trained global model including a global model input and output, accessing the global model to extract global weights for global neuron layers, passing the global weights to a local model, training the local model with the local data using the passed global weights to generate local weight(s) corresponding to local neuron layer(s), feeding the test data into the trained local model to generate a prediction output, and based on the prediction: generating second drilling parameters to optimize drilling of the rock formation, and drilling into the rock formation using the second drilling parameters.

The application relates to the field of aerial surveying, in particular to an aerial magnetic surveying device and a UAV applying the same. The aerial magnetic surveying device comprises a probe rod for mounting a detection device, a suspension assembly for connecting with a UAV body and a limiting locking assembly. The suspension assembly comprises a hanger and a connecting head. The hanger is connected with the UAV body and has a sliding slot. The sliding plate of the connecting head is matched with the sliding slot. The sliding plate is relatively fixed with the hanger through a first locking bolt. One end of the limiting locking assembly is connected with the side wall of the UAV body, and the other end is fixed with the probe rod. The probe rod is a hollow carbon fiber rod for wiring. The suspension assembly of the UAV is arranged on the belly of the UAV. The probe rod extends to the back side of the UAV body to mount the detection device. The limiting locking assembly is arranged on the back side of the UAV body to connect the UAV body and the probe rod. During flight, the probe rod is horizontal, and the cesium light pump is vertical. The application achieves the technical effects of high stability of the aerial magnetic surveying device, guaranteeing stable operation of the aerial magnetic surveying device and accurate measurement.

Systems, methods, and apparatus, including computer programs encoded on computer-readable media, for obtaining nuclear magnetic resonance (NMR) measurements of a subsurface formation in a well system. One or more NMR pulses are generated downhole using an NMR tool of the well system. It is determining whether an amplitude of an NMR echo signal is less than or equal to a threshold level or the NMR echo signal is not present. Ringing noise associated with the one or more NMR pulses is measured when the amplitude of the NMR echo signal is less than or equal to the threshold level or the NMR echo signal is not present. The ringing noise is cancelled from the NMR measurements, and properties of the subsurface formation are determined from the NMR measurements after cancelling the ringing noise.

The present disclosure relates to a method for identifying the distance of sediment source in a fault basin based on well logging data, which analyzes the paleocurrent by using the imaging logging data, determines the direction of the paleocurrent, and then scales the imaging logging, conventional logging and nuclear magnetic logging by using the core, determines the conventional logging response characteristics, nuclear magnetic T2 distribution spectrum characteristics of the far source, medium source and near source, establishes the source distance identification chart, realizes the longitudinal continuous, efficient, accurate and low-cost sediment source distance discrimination, and provides an important basis for the analysis of the sediment basin; the present disclosure analyzes the distance of the sediment source based on the well logging data, fully excavates the geological information of the existing well logging data, reduces the cost to the minimum, and solves the problems of the discontinuity of the source distance determined by using the core data, and the low accuracy of the source analysis result when the core data is insufficient.

Provided are a well-seismic analysis system and method based on a tight sandstone geological-mechanical coupled lithofacies system, and a device. The system includes a classification mode construction module configured to construct a geological-mechanical coupled lithofacies classification mode for a tight sandstone reservoir based on the information data through a four-element composite triangle chart method. An integration module classifies geological-mechanical coupled lithofacies at a single-well level based on element difference data and integrate multi-type lithofacies prediction results. An analysis and determination module performs, by a well-seismic collaborative three-dimensional model of the geological-mechanical coupled lithofacies in the tight sandstone reservoir, characteristic extraction of the geological-mechanical coupled lithofacies, lithofacies classification feedback adjustment, and seismic attribute mapping, and determines geological-mechanical coupled lithofacies distribution information data of the tight sandstone reservoir.