178 results about "Source rock" patented technology

A grading evaluation method for high-maturity gas source rock based on hydrocarbon generation and expulsion simulation includes: establishing a change curve of hydrocarbon generation yield based on a hydrocarbon generation thermal simulation experiment; establishing a change curve of hydrocarbon expulsion of source rocks based on a principle of material balance; determining a classification boundary of source rocks based on the change curve of hydrocarbon generation yield and the change curve of hydrocarbon expulsion of source rocks; and obtaining a spatial distribution of different types of source rocks by combining logging interpretation according to the classification boundary of source rocks. In the method, the evaluation model and change curve of hydrocarbon generation yield, retained gas volume and hydrocarbon expulsion volume of source rock are established, and the classification standard of gas source rock at different maturity stages is determined by combining the change curve of hydrocarbon expulsion efficiency under different maturities.

Methods and systems are disclosed. The method may include obtaining a first plurality of hydrocarbon source rock samples from a first well and a second plurality of hydrocarbon source rock samples from a second well, each well penetrating a portion of a subterranean region. For each of the first and second plurality of samples obtaining a set of kinetic parameter values, including a discrete distribution of activation energy and a common frequency factor and determining a weighted average activation energy value from the distribution. The method may further include identifying a first chemostratigraphic segment of the first well and a second chemostratigraphic segment of the second well, each based on the weighted average activation values; determining a correlated stratigraphic unit and mapping organofacies based on the first the second chemostratigraphic segments; and predicting hydrocarbon generation, retention and expulsion and determining a drilling target within the correlated stratigraphic unit.

A system and method for determining a net source rock thickness is disclosed. The method includes obtaining at least one well log, a first and second plurality of core samples from a wellbore, and for each of the first plurality determining a relative abundance of inorganic materials, and for each of the second plurality a set of organic material data. The method further includes determining a validated total organic content and a measured source rock thickness based on the organic material data and relative abundance of inorganic materials and determining a data and a prediction portion of the wellbore, based on the second plurality sample locations. The method still further includes determining a cut-off value for each well log, predicting a source rock thickness from the cut-off values and the net source rock thickness from a sum of the predicted and the measured source rock thicknesses.

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 a method for identifying natural gas causes by using methane carbon and hydrogen isotopes, and belongs to the technical field of oil-gas exploration and development. The method comprises the following steps: (1) acquiring methane carbon and hydrogen isotope data of a natural gas sample in a target area; (2) respectively carrying out thermal simulation experiments on the oil-type gas hydrocarbon source rock sample and the coal-formed gas hydrocarbon source rock sample, determining methane carbon isotope characteristics of the oil-type gas and the coal-formed gas, and judging typical oil-type gas and coal-formed gas in the natural gas sample in the step (1) by combining geologic characteristics; and (3) performing methane carbon and hydrogen isotope clustering analysis on the typical oil-type gas and the coal-formed gas, establishing a methane carbon and hydrogen isotope identification chart of the oil-type gas and the coal-formed gas, and identifying the natural gas cause according to the identification chart. The judgment method is higher in accuracy, and a feasible way is provided for judgment of natural gas reservoir causes in a high heat evolution stage and in regions with complex causes.

The invention discloses a rapid comprehensive survey method and system for natural hydrogen resources, and the method comprises the steps: rapidly delineating a prospective area through remote sensing and geochemical measurement, fusing aviation gravity and magnetism, earthquake, time-frequency electromagnetism and ground geological survey multi-source data, finding out the characteristics of hydrogen source rock, a migration channel, a reservoir stratum and a cover stratum through the integrated evaluation of source-communication-storage-cover, and carrying out the comprehensive survey of the natural hydrogen resources. A target area is optimized through multi-information fusion, drilling verification is carried out, and efficient exploration of natural hydrogen resources is achieved. According to the method, the potential of the natural hydrogen resource can be rapidly and accurately evaluated.

Embodiments of the present disclosure provide systems and methods for hydrogen production. Systems and methods provided herein may include obtaining one or more hydrogen prospects, the one or more hydrogen prospects selected based on one or more parameters. Systems and methods provided herein may include constructing one or more fracture networks based on the one or more hydrogen prospects, the one or more fracture networks each having a source rock area value. Systems and methods provided herein may include, based on the source rock area value for each of the one or more hydrogen prospects, generating a source rock exposure value for each of the one or more prospects. Systems and methods provided herein may include outputting a production prediction based on the source rock exposure value for each of the one or more hydrogen prospects.

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.

The invention discloses a method and system for predicting the maximum height of an oil column of an upper-generation lower-storage type sandstone reservoir, and the method comprises the steps: building a dynamic critical equilibrium relational expression which takes hydrocarbon expulsion intensity and oil column formation height as unknown quantities and is used for representing an oil column formation condition and a force equilibrium relation according to the basic parameters of a hydrocarbon source rock stratum to be researched; according to pyrolysis experiment parameter data of multiple wells in the hydrocarbon source rock stratum to be researched, hydrocarbon expulsion intensity at different depths is calculated; and substituting the hydrocarbon expulsion intensities at different depths into the dynamic critical equilibrium relational expression so as to obtain the maximum oil column formation height at different depths. According to the method, the reliability and the accuracy of predicting the maximum height of the oil column of the upper-growing lower-storage type sandstone reservoir are improved.

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 belongs to the technical field of oil-gas exploration and development, and discloses a method for predicting the quantity of oil resources in a thin-well low-exploration basin, which comprises the following steps of: 1, determining a hydrocarbon generation threshold depth and a hydrocarbon generation period of a hydrocarbon source rock stratum section; and 2, recovering the paleostructure of the hydrocarbon generation period, and delineating the area of the mature hydrocarbon source rock on a plane distribution diagram of the paleostructure. And 3, determining a dark mudstone distribution range to obtain an effective hydrocarbon source rock area. And 4, calculating the percentage content of the mudstone. And 5, according to the mudstone percentage content, constructing a mudstone thickness model of the hydrocarbon source rock stratum section. And 6, dividing the mudstone thickness model of the hydrocarbon source rock stratum section in the effective hydrocarbon source rock area into a plurality of units, and calculating the average thickness of each unit. And 7, calculating the petroleum resource quantity of each unit, and accumulating to obtain the basin petroleum resource quantity. Accurate area data and thickness data are provided for predicting the petroleum resource quantity, and the efficiency and accuracy of predicting the petroleum resource quantity are improved through division unit calculation.

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 invention provides a twin-well circulation injection and production system for accelerating hydrogen generation of hydrogen source rocks and a working method. A fluid extraction module is connected with a ground processing system, the ground processing system is connected with a fluid injection module, the fluid injection module is connected with an injection well, and the fluid extraction module is connected with an extraction well; a first horizontal section of the injection well is arranged in the middle-lower area of the hydrogen source rock target area, a second horizontal section of the extraction well is arranged in the middle-upper area of the hydrogen source rock target area, an underground fracturing fracture net is formed between the first horizontal section and the second horizontal section, the Fe < 2 + > mineral content in the hydrogen source rock target area is larger than a preset content threshold value, and the hydrogen source rock target area comprises a pore fracture development zone; the ground treatment system comprises a control system, a gas-liquid separation module, a gas collection module and a fluid activation module, the gas collection module and the fluid activation module are connected with the gas-liquid separation module, the gas-liquid separation module is connected with the fluid extraction module, and the fluid activation module is connected with the fluid injection module. According to the invention, hydrogen can be actively, efficiently and continuously produced from the underground hydrogen source rock.

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.

This invention discloses a method and system for quantitative classification and ranking of exploration zones. The method includes: acquiring source rock data, reservoir data, and caprock data corresponding to each exploration zone; determining the oil source index corresponding to each exploration zone based on the source rock data; determining the reservoir index corresponding to each exploration zone based on the reservoir data; determining the caprock index corresponding to each exploration zone based on the caprock data; determining a preset classification corresponding to each exploration zone based on the oil source index, reservoir index, and caprock index; and ranking each exploration zone based on the ranking information corresponding to each preset classification and the oil source index, reservoir index, and caprock index corresponding to each exploration zone. This invention quantitatively classifies and ranks exploration zones based on source rock data, reservoir data, and caprock data, thereby improving the accuracy of exploration zone classification and ranking results and enhancing the effectiveness of exploration deployment.

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 belongs to the technical field of oil and gas well logging, and particularly relates to a method for evaluating the content of organic carbon in marine facies hydrocarbon source rock of a Yanan gas field based on a well logging curve. The invention discloses a method for evaluating the organic carbon content of Yanan gas field marine facies hydrocarbon source rock based on a logging curve. The method comprises the steps that a conventional logging curve and an actually-measured TOC value of a rock sample are obtained; constructing fusion parameters; and fitting the actually measured TOC values of the rock samples of the same well and the same depth with the fusion parameters to obtain a fitting relational expression, namely a TOC prediction model. According to the method, the fusion parameters are constructed instead of being directly fitted with a conventional logging curve, and the fusion parameters are reasonably selected and accord with the organic matter enrichment rule; the method has the advantages of being low in cost, high in efficiency and high in practicability, the hydrocarbon source rocks in the work area can be accurately and integrally depicted in a fine mode, and data support is provided for oil and gas exploration, development and evaluation.

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.