16 results about "Geochemistry" patented technology

The invention discloses a method for intensively developing a kerogen-rich shale oil reservoir by using a kerogen residual carbon resource, and relates to the technical field of unconventional oil and gas development. According to the method, water and oxygen-containing gas are injected into the shale oil reservoir rich in kerogen after electric heating in-situ exploitation, hydrogen and heat are generated by utilizing residual carbon enriched in the shale oil reservoir rich in kerogen, and kerogen at a large well spacing is further developed by utilizing the generated hydrogen and heat. According to the method, residual heat and residual carbon in the reservoir after in-situ development are electrically heated, the kerogen-rich shale oil reservoir after in-situ exploitation can be further developed without additional energy, the oil yield is increased, meanwhile, energy is saved, and the method is a novel green, low-carbon, safe and efficient unconventional oil reservoir development technology.

The invention discloses a method for predicting the radon exhalation rate of an ore body under a multi-factor coupling condition. The method comprises the following steps: collecting a rock sample in a mining area and processing the rock sample into a standard sample; measuring the porosity and the radium content of the sample; judging whether the porosity and the radium content are the same or not; and calculating the radon exhalation rate by utilizing a plurality of equation prediction models based on parameters such as temperature, water content, porosity and radium content. The radon exhalation rate prediction method comprehensively considers the coupling effect of multiple factors such as temperature, moisture content, porosity and radium content, overcomes the defects of a single-factor model, realizes more accurate prediction and effective prevention and control of radon exhalation behaviors of a mine, has good practicability, economical efficiency and popularization value, and is suitable for popularization and application. And powerful technical support is provided for mine radiation protection and safety production.

The application discloses a natural gas hydrate reservoir formation age analysis method, device and system, relates to the technical field of marine natural gas hydrate exploration, and comprises the following steps: collecting marine sediment samples in a natural gas hydrate drilling core column; performing a photoelectric age test on the marine sediment samples; establishing an age-depth model of the natural gas hydrate samples according to the obtained photoelectric age and sediment depth of the marine sediment samples; calculating the sedimentation time of the natural gas hydrate reservoir according to the age-depth model of the natural gas hydrate drilling, and further determining the formation age of the natural gas hydrate. The method can accurately determine the formation age of the natural gas hydrate, avoids the interference caused by the uncertainty of the natural gas hydrate reservoir forming time, and lays a geological exploration foundation for further revealing the natural gas hydrate reservoir forming mechanism.

The present application relates to the technical field of standard sample, in particular to a lithium ore component analysis series standard sample and a preparation method thereof, the chemical component composition and content range of the standard sample are as follows: Li2O: 0.80~6.2%; Na2O: 0.2~4.0%; K2O: 0.4~4.4%; Rb2O: 0.05~0.7%; Cs2O: 0.02~0.3%; SiO2: 49~69%; Al2O3: 14~19%; TiO2: 0.004~0.05%; Fe2O3: 0.3~1.3%; P2O5: 0.1~1.1%; BeO: 0.01~0.05%; CaO: 0.5~7%; MgO: 0.1~0.6%; MnO: 0.04~0.2%; S: 0.005~3%; Ta2O5: 0.01~0.07%; Nb2O5: 0.003~0.02%; F: 0.04~2.2%; ignition loss: 2.0~14%. The lithium ore standard sample prepared by the present application has many fixed values, and the linear relationship of main components is good, and the problem of poor uniformity caused by the segregation of characteristic elements is avoided, the needs of different users, different instruments, different analysis methods can be met, and the lithium ore standard sample can be widely applied to the analysis and quality monitoring of lithium ore.

The invention discloses a hot dry rock geothermal resource mining method, device and equipment and a storage medium. The method comprises the steps that parameter monitoring is conducted on multiple sets of geothermal exploitation and irrigation wells which are arranged in a target exploitation area in advance, a first exploitation and irrigation well which is in geothermal resource exploitation currently in the multiple sets of geothermal exploitation and irrigation wells is determined, and first exploitation and irrigation parameters corresponding to the first exploitation and irrigation well are determined; according to the first mining and irrigation parameters, the mining and irrigation well switching score used for switching mining and irrigation wells is determined; according to a preset switching threshold value range and the mining and recharging well switching score, determining a mining and recharging well switching scheme for switching the first mining and recharging well, and according to the mining and recharging well switching scheme, switching the first mining and recharging well which is currently exploiting geothermal resources to other mining and recharging wells in multiple groups of geothermal mining and recharging wells, intelligent switching and heat storage balanced development of well groups are achieved, continuity of geothermal energy production is guaranteed, the service life of geothermal resources is prolonged, and an economical and feasible technical path is provided for large-scale development of hot dry rock resources.

A quench oil may be excellent in thermal stability and may be capable of retaining the brightness for a prolonged period of time. Such a quench oil may contain a base oil containing a mineral oil (A), the mineral oil (A) having a 40° C. kinematic viscosity of 100 to 600 mm2 / s and a sulfur content of 0.10 to 0.20% by mass, the base oil having a content of the mineral oil (A) of more than 0.5% by mass, based on the total amount of the base oil.

This invention provides a method for predicting vertical sweet spots in high-silica shale, comprising the following steps: S1, collecting shale core samples and obtaining measured experimental data and well logging data of the shale; wherein the measured experimental data of the shale includes measured TOC, NMR porosity, and relative content of silica minerals; S2, establishing the relationship between measured TOC, NMR porosity, and relative content of silica minerals, and determining the lower limits of relative content of silica minerals, TOC, and NMR porosity in the gas-producing section; S3, establishing a calculation model for the relative content of silica minerals in well logging; S4, determining the sweet spot section of the shale; S5, verifying the accuracy of the sweet spot section of the shale. This invention uses the relative content of silica minerals as the key parameter, which is simple and clear; the relative content of silica minerals is also the most important brittle mineral in shale. The higher the relative content of silica minerals, the better the brittleness of the shale, and the more conducive it is to fracturing. Therefore, the high silica content section is also the engineering sweet spot section. This method takes into account the prediction of both geological and engineering sweet spots.

The invention provides a coal rock component calculation method and device. The method comprises the following steps: acquiring a coal rock sample to be analyzed; measuring the sample through an X-ray fluorescence spectrophotometer, and determining the elemental composition and content of the coal rock; performing element and mineral correlation analysis according to the coal rock sedimentary environment, and determining the occurrence characteristics of each element in the inorganic mineral components of the coal rock; and based on the occurrence characteristics of the elements in the inorganic mineral components of the coal rock, performing mineral inversion calculation to obtain the coal rock components. By utilizing the scheme of the invention, the requirements of field production on real-time analysis and evaluation of coal rock can be met.

This application discloses a coal facies logging classification method, system, equipment, storage medium, and program product, belonging to the field of coalfield geological exploration technology. First, by selecting reference wells and collecting multi-source data, a reliable data foundation is provided for coal facies classification, avoiding the limitations of subjective assignment. Second, by evaluating the correlation between coal facies parameters and logging data, logging data categories that conform to geological laws are selected, effectively eliminating noisy data irrelevant to coal facies types and improving the effectiveness of the training dataset used for model training. By determining the significance between logging data and coal facies types, a reliable statistical correlation between the logging data used for model training and coal facies types is ensured, improving the quality of model training and the accuracy of prediction. Finally, by training a coal facies evaluation model and applying it to prediction wells, the objectivity and accuracy of coal facies classification are guaranteed. This solves the technical problems of strong subjectivity and low classification efficiency in existing technologies.

The invention provides a mapping method and system for basin clastic rock sedimentary facies, and the method comprises the steps: determining all sedimentary facies types possibly existing in a current basin through considering the terrain environment, stratum distribution and structural elements of a to-be-researched basin; aiming at different sedimentary facies types, respectively taking structures, material sources, landforms and sedimentary facies as research elements, and combining a set sedimentary facies control principle to analyze control association between each research element and the corresponding sedimentary facies; and respectively compiling sedimentary facies planar graphs of stratums in different periods of the current basin by adopting a point-line-plane mode based on the control correlation between each research element and the corresponding sedimentary facies. By adopting the scheme, the defects of complicated operation and insufficient map information accuracy in the prior art can be overcome, the control effect of factors such as the structure, the material source, the landform and the deposition on the sedimentary facies is comprehensively considered, and support is provided for the sedimentary facies evolution law and guidance of oil-gas exploration engineering.

This invention discloses a method and system for determining and quantitatively analyzing the main development zones for shale oil. The method includes: revealing the production capacity characteristics of pure shale oil based on its dynamic production curve; extracting standards and parameters for analyzing the development effect of shale oil based on different production capacity characteristics; determining the main geological development zones for shale oil based on these standards and parameters; and determining the main drilling targets for shale oil by combining the development effect with the main geological development zones. This invention, by combining the development effect with the main geological development zones, ultimately determines the main development targets for continental shale oil, achieving profitable development of pure shale oil; and providing a basis for the rational optimization of shale oil well networks and well spacing, and for profitable development.

The invention relates to the technical field of petroleum and natural gas exploration, in particular to an oil layer judgment method and device based on a mineral logging cosine similarity method.The method comprises the steps that content data of mineral components of a target stratum and a known stratum in a target area are obtained, and the content data of the mineral components are subjected to standardization processing; feature vectors representing mineral components and contents of the target stratum and the known stratum are obtained; calculating the cosine similarity between the target stratum and the known stratum in the target area according to the feature vector; and judging the stratum type of the target stratum according to the cosine similarity. According to the method, the accurate position of the current drilling layer can be rapidly and accurately judged in real time by using the cosine similarity, the accuracy and efficiency of horizontal well guiding are improved, more powerful support is provided for engineering adjustment, a guarantee is provided for the subsequent oil and gas recovery ratio, and the method has wide application prospects and important practical significance and is worthy of popularization and application. The method plays an important role in promoting oil field exploration and development.

The present application relates to a kind of compact sandstone fine naming method and rock mineral content determination method, belong to rock mineral identification technical field.The fine naming method of the present application includes the following steps: obtaining the Fe element content, Al element content and Si element content in the skeleton of the rock to be named in target area, utilize skeleton X element content-dirt content model, skeleton aluminum element content-feldspar content model, skeleton silicon element content-quartz content model calculate dirt, feldspar and quartz content, then calculate dirt relative content, feldspar relative content and quartz relative content, and utilize sandstone triangular graph to fine name the rock in target area.The method can be in real time on the rock fine naming in oil drilling site, overcome the defect that rock mineral content is obtained after laboratory analysis is not continuous in fine naming rock, carry out compact oil and gas completion fine evaluation and test layer in drilling site, realize in improving interpretation precision, simultaneously, speed up oil and gas development process.

The invention relates to the technical field of deep coal rock gas exploration, and particularly discloses a method for predicting the free gas volume of deep coal rock, which comprises the following steps: acquiring the formation pressure and temperature of a coal rock layer in a production well, a coring coal rock sample and natural gas; the formation temperature and pressure are simulated according to the obtained formation pressure and temperature value, the obtained natural gas is injected into the coal rock sample under the simulated formation temperature and pressure, and the natural gas gathered in the formation environment of the coal rock layer is simulated; depressurizing the coal rock sample filled with the natural gas to separate out the natural gas from the coal rock sample in the simulated stratum environment; measuring the accumulated gas production rate corresponding to the delta 13CH4 value of the natural gas isotope separated out from the coal rock sample in the depressurization process; according to the isotope delta 13CH4 value, the free gas amount and the adsorption gas amount in the accumulated gas production amount are distinguished. The method can be used for rapidly predicting the free gas content, the adsorbed gas content and the final natural gas recoverable quantity in the deep coal rock.

The present application relates to a kind of offshore sea-land transition phase little well area hydrocarbon source rock type identification method and its device, the identification method includes: S1, obtaining required data;S2, according to sporopollen facies analysis data, determine the hydrocarbon source rock division limit value based on sporopollen facies component content;S3, according to the hydrocarbon source rock division limit value based on sporopollen facies component content, determine the limit value of the biosignature compound of hydrocarbon source rock and condensate oil corresponding biosignature compound's source indicating parameter;S4, according to the limit value of the biosignature compound of condensate oil corresponding biosignature compound's source indicating parameter, determine the limit value of natural gas light hydrocarbon parameter;S5, according to natural gas light hydrocarbon parameter plot intersection figure, according to the limit value of natural gas light hydrocarbon parameter, the range corresponding to different types of hydrocarbon source rock is divided.The identification method and its device provided by the present application significantly improve the identification accuracy of offshore sea-land transition phase sedimentary environment little well area hydrocarbon source rock type, solve the problem of little well area sample limitation.