109 results about "Source rock" patented technology

A method for evaluating geological hydrogen source rock in a region is provided. The method includes: collecting magnetic susceptibility data from a plurality of subsurface locations in the region; receiving geophysical survey data of the region, wherein the geophysical survey data comprises geophysical data collected from above ground; tying the magnetic susceptibility data of the plurality of subsurface locations to the geophysical survey data; generating a geologic map of igneous rock, metamorphic rock, or mafic mineral- or iron-rich sedimentary rock within the region based on the magnetic susceptibility data using a model; and determining, based on the geologic map, a target zone of the geological hydrogen source rock with a potential for hydrogen production or with the potential for hydrogen accumulation.

The invention relates to the technical field of petroleum geophysical exploration, and provides a reservoir forming period hydrocarbon source rock paleo-pressure quantitative prediction method and system, and the method comprises the steps: solving the stratum denudation thickness based on a mudstone compaction curve extrapolation method; obtaining the thickness of a terrain skeleton, constructing a binary function based on the stratum denudation thickness and the thickness of the terrain skeleton to analyze an approximate solution, and inverting the stratum paleo-burial depth for the logging paleo-burial depth; obtaining the total porosity of the hydrocarbon source rock according to the stratum paleo-burial depth; quantitatively predicting the single well paleo pressure of the hydrocarbon source rock according to the total porosity; the multi-well paleo pressure is obtained based on the single well paleo pressure, interpolation is performed according to the multi-well paleo pressure to obtain the plane paleo pressure, in this way, the accurate well logging compaction trend line is established, the accuracy and reliability of the prediction result are improved by considering the influence of the shear wave speed, and therefore the accuracy of predicting the paleo pressure of the hydrocarbon source rock in the reservoir forming period is improved.

The invention relates to a device and method for evaluating the oil saturation of rock based on a step-by-step centrifugal volumetric method, and the device comprises a centrifugal unit which comprises a rotating support and a centrifugal tray sleeving the rotating support; the measuring unit comprises a plurality of closed detachable centrifugal tubes, the plurality of centrifugal tubes are uniformly arranged in the circumferential direction of the centrifugal tray, a pressurizing chamber, a sample chamber and a collecting chamber are sequentially arranged in each centrifugal tube from top to bottom, and the pressurizing chamber and the sample chamber are separated through a sealing partition plate and are controlled to be opened and closed through a valve; and the sample chamber and the collection chamber are separated by a filter screen. Compared with an organic solvent, the supercritical CO2 adopted by the method has obvious advantages in the quantification of the crude oil of the source rock. The oil content measuring agent has both gas diffusivity and liquid solubility, is small in molecular size, can penetrate through tiny pores of source rocks, is higher in dissolving capacity for heavy components in crude oil, and can fully extract the crude oil in various pores and reduce residues, so that the oil content of the rocks is more accurately quantified.

The embodiment of the invention discloses a stratum denudation data determination method and device, equipment and a medium. The method comprises the following steps: determining a target layer, a Shanghai generic surface and a Shanghai generic surface of which stratum denudation data needs to be calculated; wherein the upper marine flooding surface is located above the top surface of the target layer and closest to the top surface of the target layer, and the lower marine flooding surface is located below the bottom surface of the target layer and closest to the bottom surface of the target layer; determining denudation points according to the target layer and the underlying stratum; wherein the underlying stratum is a stratum located between the bottom surface of a target stratum and a lower sea flooding surface; and determining the stratum denudation amount according to the thickness between an upper line extending upwards in the stratum direction from the denudation point and the bottom surface of the target stratum. According to the scheme, the stratum denudation amount can be determined more accurately and quickly according to the stratum characteristics and the seismic data which are easy to obtain, higher practicability is achieved, and basic data are provided for later-stage structural analysis, hydrocarbon source rock evolution, oil and gas accumulation condition analysis and the like.

The application discloses a sparse well area hydrocarbon source rock TOC prediction method and system, an electronic device and a medium, relates to the technical field of hydrocarbon source rock carbon content prediction, and comprises the following steps: establishing a virtual well in a well-free area; determining the seismic attribute of the virtual well based on a seismic attribute extraction method; determining the lithology of the virtual well based on the seismic attribute of the virtual well and a sandstone and mudstone lithology prediction model, and extracting the mudstone section of the virtual well; determining the longitudinal continuous TOC prediction value of the hydrocarbon source rock in the mudstone section of the virtual well based on a single-well longitudinal continuous TOC prediction model; and combining the longitudinal continuous TOC prediction value and the measured TOC value of the hydrocarbon source rock in the mudstone section of the virtual well to construct a three-dimensional TOC attribute body of the target sparse well area based on a preset geological condition constraint, so as to predict the TOC of the hydrocarbon source rock in the target sparse well area. The application realizes higher-precision quantitative evaluation and prediction of the TOC of the hydrocarbon source rock in the sparse well area.

A method of deploying a pulsed neutron logging tool. The method may comprise detecting natural gamma rays from the subterranean formation via one or more detectors of the pulsed neutron logging tool, broadcasting neutrons into the subterranean formation, and detecting neutron-induced gamma rays and natural gamma rays from the subterranean formation. The method may further comprise creating an inelastic spectrum, a capture spectrum, or a capture time decay from the natural gamma rays or the neutron-induced gamma rays, forming an inelastic yields, a capture elemental yields, or a formation sigma form the inelastic spectrum, the capture spectrum, or the capture time decay, creating a closure model from the inelastic yields and / or capture elemental yields and / or a formation sigma, and identifying a porosity, a mineral weight fraction, or a quality figure of merit from the closure model that quantifies geologic hydrogen reservoir quality.

The invention relates to a generation method, device, equipment and medium of a natural gas cause identification chart, in particular to the technical field of natural gas exploration, and the generation method comprises the following steps: performing a hydrocarbon generation simulation test on a hydrocarbon source rock sample to obtain gaseous analysis gas; performing natural gas composition analysis, natural gas C6-C8 light hydrocarbon composition analysis and natural gas C1-C5 carbon isotope and hydrogen isotope analysis on gaseous analysis gas, and drawing a gas component-gas component relational graph, a light hydrocarbon component-light hydrocarbon component relational graph and a hydrocarbon gas carbon isotope-carbon isotope relational graph of different closed systems; and screening parameters with differences to establish a natural gas cause identification chart of the high-over mature multi-closed system. According to the generation method provided by the invention, a hydrocarbon generation simulation experiment and oil-gas product chemical analysis are carried out, a multi-closed system natural gas cause identification chart is established, and theoretical support is provided for cover layer closure evaluation in regional oil-gas exploration, regional oil-gas resource evaluation and oil-gas-containing distant view and exploration field evaluation.

The invention belongs to the technical field of geological research, and provides a helium source rock prediction method and device, a storage medium and equipment, and the method comprises the steps: taking a bed rock top surface seismic horizon explained and tracked by a target area as a bed rock top surface, and taking a preset time window below the bed rock top surface as a target object; making a bedrock seismic waveform classification attribute graph of a preset time window; according to the bedrock seismic waveform classification attribute graph and the seismic reflection characteristics of the various different types of rocks of the bedrock, determining the corresponding relation between the different types of rocks of the bedrock and different seismic waveform distribution areas displayed by the bedrock seismic waveform classification attribute graph; and predicting helium source rocks of different types based on the corresponding relationship and different seismic waveform distribution areas displayed by the bedrock seismic waveform classification attribute graph to obtain a prediction result. Through the prediction method, on the premise of not depending on gravity and magnetic data, the prediction accuracy of the helium source rock can be greatly improved.

The invention discloses an oil gas hydrocarbon generation pressurization charging wave and range characterization method based on energy conservation, and relates to the technical field of oil exploration and development. In order to solve the problem that a traditional method focuses on macroscopic reservoir formation qualitative description and lacks a filling degree accurate quantification method, energy of different sources is superposed to calculate total hydrocarbon expulsion kinetic energy of hydrocarbon expulsion of hydrocarbon source rocks; the energy from different sources comprises under-compaction kinetic energy, hydrocarbon generation volume expansion kinetic energy and fluid elasticity energy; quantizing the energy attenuation of the oil gas in the migration process from the hydrocarbon source rock to the reservoir; a charge distance limit is determined based on the total hydrocarbon expulsion kinetic energy and the energy attenuation of the migration process.

Methods for identifying, evaluating, and high-grading rocks associated with past or future potential generation of hydrogen from geologic materials are provided. For example, a method for evaluating a hydrogen system within a geological source rock includes obtaining a geological sample of the geological source rock; extracting 'mobile' gases of the geological sample under a pressure gradient; evaluating the 'mobile' gases extracted from the geological sample; and quantifying a volume of hydrogen previously generated based on the 'mobile' gases.

The invention discloses a method and equipment for determining the initial reservoir forming depth of shale oil, and the method comprises the steps: obtaining curves of oil-generating pressurization values of mudstone and carbonate rock along with time through an oil-generating pressurization experiment, then carrying out curve conversion, and calculating the initial reservoir forming depth of shale oil by calculating the capillary resistance of the carbonate rock. According to the method, the reservoir forming initial depth of the shale oil is determined according to the superposition curve and the capillary resistance, and due to the fact that the reservoir forming initial depth is determined through the superposition curve and the capillary resistance, the scheme does not need to emphasize on utilization of geological factors and is not affected by other factors, and the finally obtained result is more accurate. Moreover, the method provided by the invention considers the influence of mudstone and carbonate rock on the reservoir forming initial depth of shale oil at the same time, avoids the problem that only conventional oil and gas of single hydrocarbon source rock lithology are aimed in related technologies, and is suitable for determining the reservoir forming initial depth of unconventional oil and gas such as shale oil and the like.

The invention relates to the technical field of hydrocarbon source rock testing devices, in particular to a device and method for testing the oil discharge efficiency of hydrocarbon source rocks of different qualities, and the device comprises a support, a central pipe is fixed at the center of the support, and a drilling cylinder capable of moving up and down relative to the central pipe and rotating simultaneously sleeves the central pipe. A driving device capable of driving the drilling barrel to slide up and down and rotate simultaneously is mounted on the bracket; and an oil discharge hole communicated internally and externally is formed in the upper end of the central pipe. The device is reasonable and compact in structure and convenient to use, can be used for testing in an actual geological environment of the hydrocarbon source rock without collecting and treating a sample, can be used for directly testing the hydrocarbon source rock, does not need to bring the sample back to a laboratory for further analysis, reduces destructive operation of the sample, and improves the test efficiency. And the property of the underground hydrocarbon source rock can be known more accurately.

The present application relates to a kind of based on the evaluation method of in-situ enrichment capacity of oil and gas in fracture source rock control, belong to the field of oil and gas exploration geology, including: selecting key fracture parameter as evaluation factor, key fracture parameter includes four types such as fracture structural style, fracture density, vertical fault throw and drilling-fracture nearest distance;Quantitative scoring model of each key fracture parameter is constructed, and fracture structural style score, fracture density score, vertical fault throw score and drilling-fracture nearest distance score are obtained;Fracture reservoir-controlling index is calculated;Based on fracture reservoir-controlling index, reservoir-controlling capacity is classified.The present application builds complete fracture structural parameter system, establishes the quantitative scoring model of each parameter, and builds fracture reservoir-controlling index using weight assignment method, realizes the quantitative evaluation of fracture reservoir-controlling capacity, standardization and comparability.

The invention discloses an oil source comparison method and system based on biomarker compound big data analysis. The oil source comparison method comprises the following steps: acquiring biomarker compound big data in hydrocarbon source rock and crude oil; according to big data of biomarker compounds in hydrocarbon source rocks and crude oil, main factor analysis is carried out, and main factors are screened out; performing rotated factor load matrix analysis on the main factors, and further performing type division on hydrocarbon source rocks and crude oil; based on big data of the biomarker compounds in the main factors, factor score coefficient matrix analysis is carried out, and key biomarker compound parameters are screened out for oil source comparison. According to the method, oil source comparison is carried out by adopting biomarker compound big data, factor score coefficient matrix analysis is carried out on the biomarker compound big data, and biomarker compound parameters capable of representing crude oil sources are screened out for oil source comparison; the problems of high multiplicity of solutions, poor effect and the like when oil source comparison is carried out by utilizing biomarker compound maps or parameter charts are solved.

The mineralogical, chemical, magnetic, and physical properties of a rock can be used to determine the amount of hydrogen that was generated during rock alteration and the remaining amount of hydrogen generation potential. The methodologies evaluate the hydrogen generation potential of geological samples and identify natural hydrogen source rocks. The mineralogy, elemental composition, iron content and oxidation state, and other properties of a geological sample may be determined. From the determined mineralogy and other properties of the geological sample, the amount of hydrogen which the geological sample may have generated may be quantified. This method can determine the maturity of hydrogen source rocks, the potential volume of hydrogen that can be generated in other parts of a given geologic province with higher degrees of hydrogen source rock maturity, and quantify the potential remaining volume of hydrogen that can be still be generated via secondary enhanced hydrogen stimulation processes.

Methods for identifying, evaluating, and high-grading rocks associated with past or future potential generation of hydrogen from geologic materials are provided. For example, a method for evaluating a hydrogen system within a geological source rock includes obtaining a geological sample of the geological source rock; extracting ‘mobile’ gases of the geological sample under a pressure gradient; evaluating the ‘mobile’ gases extracted from the geological sample; and quantifying a volume of hydrogen previously generated based on the ‘mobile’ gases.

The invention relates to the technical field of oil and gas exploration, in particular to a gas logging-based test layer selection method and device.The gas logging-based test layer selection method comprises the following steps that S1, gas logging parameters and logging parameters are collected, and the C1 / C2 ratio is calculated according to the gas logging parameters; drawing a C1 / C2 change curve, an acoustic curve and a total hydrocarbon curve; s2, selecting a hydrocarbon source rock baseline according to a total hydrocarbon curve change trend, lithology and an acoustic curve; s3, comparing the C1 / C2 ratio of the gas reservoir section with the hydrocarbon source rock baseline value of the underlying mudstone section, and dividing the gas reservoir section into a good gas reservoir, a medium gas reservoir and a differential gas reservoir; preferentially selecting a good gas layer, secondly selecting a medium gas layer, and finally selecting a differential gas layer for testing. The method can significantly improve the success rate of test layer selection.

A method for evaluating geological hydrogen source rock in a region is provided. The method includes: collecting magnetic susceptibility data from a plurality of subsurface locations in the region; receiving geophysical survey data of the region, wherein the geophysical survey data comprises geophysical data collected from above ground; tying the magnetic susceptibility data of the plurality of subsurface locations to the geophysical survey data; generating a geologic map of igneous rock, metamorphic rock, or mafic mineral-or iron-rich sedimentary rock within the region based on the magnetic susceptibility data using a model; and determining, based on the geologic map, a target zone of the geological hydrogen source rock with a potential for hydrogen production or with the potential for hydrogen accumulation.

The invention relates to the technical field of liquid hydrocarbon measuring devices, in particular to a device for measuring the gas forming amount of liquid hydrocarbon without being discharged out of hydrocarbon source rocks, which comprises a machine compartment, a measuring tank, a gap making driving mechanism, a plurality of high-pressure injection components, an exhaust measuring component and a gap maker, the measuring tank is arranged in the machine compartment, and a hydrocarbon source rock sample block is stored in the measuring tank; a plurality of forming holes are uniformly distributed in the hydrocarbon source rock sample block, the gap making driving mechanism can drive the gap making device to extend into the forming holes and perform wall breaking and gap making on the inner walls of the forming holes, and the high-pressure injection assembly can convey liquid hydrocarbon into pores from the forming holes at high pressure. The device is reasonable and compact in structure and convenient to use, different fractures are constructed through the gap maker, and liquid hydrocarbon is injected into the fractures through the high-pressure injection assembly, so that the migration path of the liquid hydrocarbon in an underground fracture network is simulated, the gas forming amount of the liquid hydrocarbon which is not discharged out of hydrocarbon source rocks in multiple environment conditions is simulated and measured, and the reduction simulation degree is high.

The invention relates to the technical field of hydrocarbon source rock thermal evolution history reconstruction, in particular to a hydrocarbon source rock thermal evolution history reconstruction method, device, equipment, medium and product, and the method comprises the steps: obtaining thermal evolution parameters of a hydrocarbon source rock sample of a target layer, and constructing a thermal history model of the target layer; obtaining geological data of a target stratum, and establishing a burial history model of the target stratum; based on the thermal history model of the target stratum and the burial history model, carrying out constraint, and reconstructing a hydrocarbon source rock thermal evolution history; the accuracy and the reliability of the field outcrop reconstruction hydrocarbon source rock organic matter thermal evolution history can be improved.

This invention relates to a method for identifying and predicting the thickness of highly-to-overmature marine source rocks, determining the lower limit of total organic carbon (TOC) content; using this lower limit as a boundary, clarifying the electrical distribution characteristics of carbonate mudstones with TOC content greater than the lower limit, mudstones with TOC content greater than the lower limit, and mudstones with TOC content less than the lower limit; and then constructing a well logging quantitative identification scale. This allows for the determination of the thickness of carbonate mudstones with TOC content greater than the lower limit. This invention effectively solves the key problem of often missing the distribution intervals of some high TOC samples in the evaluation of the hydrocarbon generation potential of highly-to-overmature marine source rocks.

The present application relates to a kind of method and system for predicting shear wave based on source rock petrophysical model, comprising the following steps: based on lithology parameter initial value and the well logging data curve of target well, longitudinal and transverse wave velocity is estimated using source rock petrophysical model;Based on actual longitudinal wave velocity estimated value, construct inversion objective function, and lithology parameter is inverted using simulated annealing algorithm, until the error of longitudinal wave velocity estimated value and actual longitudinal wave velocity reaches the allowable condition, obtains the lithology parameter after inversion correction;Based on the lithology parameter after inversion correction, build source rock petrophysical prediction model, and estimated to obtain transverse wave velocity.The present application improves the calculation efficiency of shear wave prediction result, improves the stability and reliability of shear wave prediction method in more in line with the actual background of stratum.The present application can be widely applied to oil and gas exploration and development field.

The invention relates to the technical field of oil and gas exploration, in particular to a method for quantitatively evaluating the vertical oil and gas transmission capacity of fractured basin fractures, and aims to calculate channel source fracture transmission capacity quantitative evaluation parameters by identifying the distribution condition of effective channel source fractures in a fractured basin containing oil and gas. And performing quantitative evaluation on the vertical conduction capability of the trench source fracture by combining the fracture activity rate, the inclination angle, the fracture zone area, the effective fracture-hydrocarbon contact area, the section positive pressure, the effective hydrocarbon supply amount of the hydrocarbon source rock and the oil gas discovery condition. According to the method, multi-factor comprehensive geological evaluation is considered, data acquisition is convenient, the applicability is wide, the reliability is high, and reliable theoretical support can be provided for favorable zone optimization in fractured basin oil-gas exploration.

The application discloses a method, device and equipment for identifying sweet spots of shale oil in a salinized lake basin. The method comprises the following steps: firstly, determining a rock structure factor of a stratum based on a natural gamma curve, volume density logging data and skeleton density logging data of the stratum, so as to determine the lithology of the stratum and identify reservoir rock layers in the stratum based on the rock structure factor; then, determining a lamination index of the rock in the stratum based on electrical imaging logging data, so as to identify source rock layers in the stratum based on the lamination index; and finally, identifying a sweet spot development section of the shale oil in the salinized lake basin based on the reservoir rock layers in the stratum and the source rock layers in the stratum. The method can quickly identify the sweet spot development section of the shale oil in the target area, and provides a basis for later oil and gas development.

The application discloses a method for predicting the oil and gas transportation capacity of a composite transportation system and the trap accumulation probability, belongs to the technical field of oil exploration, fully considers the whole process from the generation to the migration and accumulation of oil and gas, comprehensively evaluates the hydrocarbon supply capacity of source rocks, the vertical transportation capacity of fractures and the lateral migration capacity of sandstone transportation layers, can accurately and quantitatively evaluate the oil and gas transportation capacity of the fracture-sand body composite transportation system, and the accurate prediction of the oil and gas transportation capacity can effectively predict the trap accumulation probability and the oil and gas field scale, thereby improving the exploration success rate, especially in the low exploration degree area, the application does not need a large amount of drilled well data or the accumulation law of discovered oil and gas fields as prior information, only starts from the geological law to quantitatively study the oil and gas transportation capacity, and then predicts the oil and gas accumulation zone, and improves the success rate of exploration wells.

The invention discloses a method for quantitatively determining contribution proportions of crude oil from different sources and periods. The method comprises the following steps: collecting a crude oil sample, a potential hydrocarbon source rock sample and a reservoir sample of a target oil and gas reservoir; comparing hydrocarbon isotopes and biomarker compounds of the crude oil sample and the potential hydrocarbon source rock samples, and determining a main hydrocarbon source rock; manufacturing an inclusion sheet; establishing a diagenesis mineral sequence of the target oil and gas reservoir; determining the capture periods of various hydrocarbon inclusions in the inclusion sheet; measuring the U-Pb age of the diagenetic minerals in each stage; determining each main reservoir forming period and the source of oil and gas in each main reservoir forming period; respectively measuring the fluorescence spectrum of the hydrocarbon inclusion corresponding to each main reservoir forming period; determining the fluorescence spectrum of the crude oil sample; according to the fluorescence spectrum of the crude oil sample and the fluorescence spectrum of the hydrocarbon inclusion, the contribution ratios of crude oil of different sources and periods are determined, so that quantitative analysis of the contribution ratios of different hydrocarbon source rocks in different reservoir forming periods is realized, and effective exploration deployment guidance can be provided.

The mineralogical, chemical, magnetic, and physical properties of a rock can be used to determine the amount of hydrogen that was generated during rock alteration and the remaining amount of hydrogen generation potential. The methodologies evaluate the hydrogen generation potential of geological samples and identify natural hydrogen source rocks. The mineralogy, elemental composition, iron content and oxidation state, and other properties of a geological sample may be determined. From the determined mineralogy and other properties of the geological sample, the amount of hydrogen which the geological sample may have generated may be quantified. This method can determine the maturity of hydrogen source rocks, the potential volume of hydrogen that can be generated in other parts of a given geologic province with higher degrees of hydrogen source rock maturity, and quantify the potential remaining volume of hydrogen that can be still be generated via secondary enhanced hydrogen stimulation processes.

The application discloses a fault dominant migration channel identification method and device. The method comprises the following steps: screening an oil-source fault from a fault system of a research area; determining a relative contact amount of the oil-source fault according to a section area of the oil-source fault and a contact area between the section and a hydrocarbon source rock, and screening a favorable oil-source fault from the oil-source fault according to the relative contact amount; and identifying a fault dominant migration channel according to activity rate distribution data of a main hydrocarbon generation and expulsion period of the favorable oil-source fault and / or a fluid potential energy convergence area. The fault dominant migration channel for oil and gas migration along the fault can be quickly and reasonably screened from the fault system.

The application provides a method for oil and gas geochemical research by using gas logging data, and relates to the technical field of oil and gas exploration, which comprises the following steps: counting gas logging data of abnormal layers and layers available as oil and gas layers of all exploratory wells in a research area, counting gas logging values of known main hydrocarbon source rocks in the research area, determining oil and gas sources by superimposing the gas logging data of the oil and gas layers in the research area and the data of the hydrocarbon source rocks; counting gas logging total hydrocarbon component big data of the hydrocarbon source rocks in the research area, obtaining the starting depth of effective hydrocarbon source rocks according to the condition that high carbon components are detected; and counting the total hydrocarbon content of the hydrocarbon source rocks in the research area, and obtaining the burial depth of the effective hydrocarbon source rocks in the research area according to the characteristics that all the detected components are effective hydrocarbon source rocks. The method for geochemical research can improve the identification efficiency of the hydrocarbon source rocks so as to provide a reference for exploration decision-making.

The application discloses a kind of quantitative evaluation method and device of oil and gas along fault to river channel sand body filling capacity, first, according to fluid inclusion analysis, oil and gas reservoir forming period is identified, and oil and gas reservoir forming period and time are determined;Then, according to the result of seismic data interpretation, the configuration relationship of fault and hydrocarbon source rock is analyzed, and gas source fault is determined;Then, in combination with the configuration relationship of fault and sand body, its evolution and the recovery result of porosity evolution, and the historical data of porosity-permeability relationship, the filling capacity evaluation parameter of key reservoir forming period is obtained;Then, in combination with the relationship between filling capacity evaluation parameter and sand body gas content, the weight coefficient of different parameters on the influence of natural gas filling is determined, and then the filling capacity coefficient of each river channel sand body is calculated, so that the selective filling strength of oil and gas along fault to each river channel sand body is obtained.The application realizes the quantitative evaluation of oil and gas along fault to river channel sand body filling capacity, and based on the evaluation result, favorable gas-bearing river channel sand body can be further predicted.