39 results about "Geochemistry" patented technology

Low CAPEX / OPEX, effective, and environmentally friendly process of rapidly extracting lithium from geothermal brines and producing lithium carbonate. The method includes adjusting a unique parameter determined based on the modified alkalinity in a quantity of the geothermal brine to a preset value without needing to purposefully modify the pH. Interactions of the anionic reactant species with components within the geothermal brine cause a solid form of the lithium to precipitate out of the geothermal brine. After the solid separation, the spent brine is environmentally safe and returned underground or transported to a reservoir.

The invention discloses a quantitative evaluation method for microbial residual coal mining and settlement reduction effects, and relates to the technical field of mining area resource mining and ecological control. The quantitative evaluation method for the microbial residual coal mining and subsidence reduction effects comprises the following steps: acquiring gas extraction data and ground surface subsidence data of a target goaf region within a set time period after microbial treatment; respectively inputting into a pre-trained time sequence analysis model, and extracting gas extraction time sequence characteristics and ground surface settlement time sequence characteristics of the target goaf region; analyzing a residual coal heat release conversion index and a ground surface settlement control index, and analyzing a collaborative evaluation index of the target goaf region; based on the collaborative evaluation index, the microbial residual coal mining and settlement reduction treatment effect grade of the target goaf region in the set time period is judged, an automatic and objective microbial residual coal mining and settlement reduction effect judgment system is formed by constructing the time sequence characteristics and the evaluation index, and the evaluation accuracy and the application reliability are improved.

The invention relates to the technical field of drilling, in particular to a preparation method of composite lubricating particles for drilling fluid and the drilling fluid, the drilling fluid is formed by compounding a multi-defect-state g-C3N4-MoS2 heterostructure and nano bentonite, g-C3N4 is prepared through a urea-ammonium thiocyanate eutectic supramolecular self-assembly and gradient calcination technology, and the composite lubricating particles are prepared through a composite lubricating agent. Introducing an N vacancy by adopting plasma treatment; moS2 is subjected to oriented epitaxial growth on the surface of g-C3N4-MoS2 through a microwave-assisted hydrothermal method; the nano bentonite is obtained by high-pressure homogenization and supercritical CO2 stripping. After the drilling fluid is subjected to multi-stage dispersion, experiments find that the friction coefficient is as low as 0.43 and is reduced by 52% compared with that of conventional drilling fluid, the abrasion loss is reduced by 97% or above, the friction resistance in the drilling process can be remarkably reduced, the service life of a drill bit can be prolonged, and the drilling fluid is particularly suitable for ultra-deep well drilling operation of shale gas, deep sea oil gas and the like.

The invention discloses a method and device for drawing a carbonatite sedimentary facies diagram based on ternary coupling. The method comprises the following steps: determining a water depth environment based on a regional structure effect, a basin position, a substrate characteristic and a climate condition, and establishing a research region concept deposition mode; selecting a typical well, dividing a three-level sequence in the typical well according to earthquake, logging and core data, and further dividing a mapping unit; for each sequence, establishing a relationship between the ternary coupling of the water depth background, the sea level cycle and the paleo-geographic position and the sedimentary hydrodynamic condition and the stratum thickness, analyzing the thickness change of the single well stratum in the sequence, and reversely deducing the sedimentary hydrodynamic condition based on the relationship in combination with the water depth background, the sea level cycle and the paleo-geographic position; and determining a single-well facies under the guidance of the concept sedimentary mode, fitting, matching and correcting the single-well facies and hydrodynamic conditions, and drawing a sedimentary facies diagram of the drawing unit in combination with the regional structure trend. The method can draw a reasonable and accurate regional sedimentary facies diagram for a complex oil field group.

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 an ore dressing device and method based on ultraviolet irradiation. The ore dressing device comprises a processor and an ore conveying device, and the ore conveying device is used for conveying ore; ultraviolet light emitted by the ultraviolet light source irradiates the ore on the ore conveying device; the image acquisition device is arranged above the ore conveying device and is used for acquiring ore pictures under ultraviolet irradiation and transmitting picture information to the processor; the ore separation device is located at the tail end of the ore conveying device, the ore deviates from an original free parabolic path under the action of the ore separation device, and the ore separation device is connected with the processor and is controlled by the processor to be opened or closed; and the at least two material receiving devices are positioned below the tail end of the ore conveying device and are used for receiving the separated ore materials and tailings.

The invention relates to the technical field of exploration and development of petroleum and natural gas geological resources, and provides a method for quantitatively evaluating oil and gas accumulation in a deep concave area. The method comprises the following steps: according to a deep concave area oil and gas accumulation source reservoir combination matching principle, dividing deep concave area oil and gas accumulation dimensions into spatial combination and quantitative evaluation; three evaluation parameters of a reservoir in the deep concave area and three evaluation parameters of hydrocarbon source rocks in the deep concave area are screened out; obtaining values of three sub-indexes in the comprehensive evaluation index of the reservoir in the deep concave area and values of three sub-indexes in the comprehensive evaluation index of the hydrocarbon source rock in the deep concave area; respectively setting three corresponding space combination influence indexes; and processing to obtain a deep concave area oil and gas reservoir formation quantitative evaluation index, and performing deep concave area oil and gas reservoir formation quantitative evaluation of source reservoir combination matching according to the deep concave area oil and gas reservoir formation quantitative evaluation index. According to the method, the oil and gas accumulation potential of the deep concave area can be rapidly and quantitatively evaluated, the working efficiency is greatly improved, and the research cost is saved.

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 invention relates to the technical field of mine ecological restoration and carbon reserve estimation, and in particular to a method and system for estimating carbon reserves in ecosystems in coal mining subsidence areas. The method comprises the following steps: S1, dividing the coal mining subsidence area according to land use type, and determining the scope and area of ​​each land use type; S2, dividing the coal mining subsidence area according to spatial state, and forming a land use grid table with a unique code for each land use type; S3, obtaining initial carbon density parameters corresponding to the land use type, calculating the effect of surface subsidence on the carbon density parameters of each sub-area of ​​the coal mining subsidence area, and performing differentiated corrections; S4, calculating the total carbon reserve at different subsidence stages, analyzing the carbon reserve, carbon sequestration, and spatial distribution of each land use type, and comprehensively analyzing the temporal variation characteristics of carbon reserves. The present invention combines land use and subsidence state to analyze carbon density changes, thereby achieving an assessment of the spatiotemporal evolution characteristics of carbon reserves in coal mining subsidence areas.

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 relates to the technical field of standard samples, in particular to a lithium ore component analysis series standard sample and a preparation method of the lithium ore component analysis series standard sample. 0.2% to 4.0% of Na2O; 0.4 to 4.4 percent of K2O; rb2O: 0.05 to 0.7% of the total weight of the raw materials; 0.02% to 0.3% of Cs2O; 49 to 69 percent of SiO2; 14 to 19 percent of Al2O3; 0.004 to 0.05 percent of TiO2 (titanium dioxide); 0.3% to 1.3% of Fe2O3; 0.1% to 1.1% of P2O5; 0.01 to 0.05 percent of BeO; 0.5 to 7 percent of CaO; 0.1% to 0.6% of MgO; the content of MnO is 0.04 to 0.2 percent; 0.005 to 3 percent of S; 0.01% to 0.07% of Ta2O5; 0.003% to 0.02% of Nb2O5: (2); 0.04 to 2.2 percent of F; and the ignition loss is 2.0-14%. The lithium ore standard sample prepared by the method has many fixed value components and good main component linear relationship, avoids the problem of poor uniformity caused by easy segregation of characteristic elements, can meet the requirements of different users, different instruments and equipment and different analysis methods, and can be widely applied to analysis test and quality monitoring of lithium ore.

The evaluation method for structural fractures in continental shale oil reservoirs based on lithofacies constraints belongs to the field of petroleum geology and includes the following steps: (1) classifying the lithofacies types of continental shale in the study area; (2) based on the lithofacies type classification in step (1), extracting characteristic parameters affecting the development of structural fractures: continental shale brittleness index I, rock structure index S, and rock mechanical layer thickness H; (3) analyzing the sensitivity of different characteristic parameters in step (2) to the intensity response of structural fracture development; (4) analyzing the combination patterns of brittleness index, rock structure index, and rock mechanical layer thickness index of different lithofacies; (5) establishing a quantitative evaluation index for structural fractures in continental shale oil reservoirs based on lithofacies, and calculating the fracture development index F of different lithofacies. j This invention can be applied to the evaluation of structural fractures in continental shale oil reservoirs, providing technical support for the rational development of continental shale oil reservoirs in my country.

The invention provides a coal bed gas enrichment main control factor evaluation method, which relates to the field of geology, and comprises the following steps: collecting and sorting eight coal reservoir parameters including burial depth, reservoir temperature, reservoir pressure, Ro, vitrinite volume fraction, ash content yield and coal bed thickness and gas content data; the influence of each coal reservoir parameter on the gas content enrichment degree is quantitatively evaluated by adopting three methods of correlation analysis, random forest importance sorting and grey correlation analysis, and the evaluation result is normalized. On the basis, reasonable weights are dynamically given to all the methods through an entropy weight method, the total score of all the coal reservoir parameters is calculated, comprehensive sorting is conducted, and therefore quantitative evaluation of the coal bed gas enrichment main control factors is achieved.

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.

The present application provides a method for judging the cause of organic pores in a shale gas sweet spot section and a golden target body. The method for judging the cause of organic pores in a shale gas sweet spot section comprises: obtaining a rock sample of a target shale gas sweet spot section; determining the type of organic matter of the rock sample of the target shale gas sweet spot section; determining the thermal evolution history of the organic matter based on the type of organic matter of the rock sample of the shale gas sweet spot section, thereby determining the cause of the organic pores developed in the organic matter. The method for judging the golden target body of a shale gas sweet spot section comprises: obtaining a rock sample of a target shale gas sweet spot section; determining the mesopore organic pore porosity of the rock sample of the target shale gas sweet spot section; determining the golden target body of the target shale gas sweet spot section based on the mesopore organic pore porosity. The technical scheme provided by the present application can realize the judgment of the cause of organic pores in a shale gas sweet spot section and the judgment of the golden target body of a shale gas sweet spot section, thereby helping the fine evaluation of a shale gas sweet spot section and the economic goal of cost reduction and efficiency improvement in the exploration and development of shale gas.

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 provides a sandstone uranium mine supercritical carbon dioxide leaching mining environment construction method and system, and relates to the technical field of uranium mine mining, and the method comprises the steps: obtaining geometric data and physical property data of a target sandstone uranium mine layer; establishing a three-dimensional geometric model of the ore bed according to the geometric data and the physical property data, and simulating temperature change and pressure distribution of the ore bed in a preprocessing stage to obtain a preprocessing simulation result; obtaining a heating simulation result according to the preprocessing simulation result; according to a heating simulation result, simulating thermal stability and leaching efficiency of the ore bed under different conditions to obtain operation parameters of the leaching and mining environment; and according to the operation parameters and the heating simulation result, selecting point positions of the leaching and mining system are screened, the layout of the leaching and mining system is designed, and a leaching and mining system design scheme is obtained. By accurately simulating the temperature change and pressure distribution of the ore bed in the stages of pretreatment, heating and leaching mining, the supercritical carbon dioxide leaching mining environment can be optimized, and the uniformity of heat transfer and pressure distribution is ensured, so that the leaching efficiency of uranium ore is improved.

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 invention relates to a comprehensive evaluation method and system for determining a coal rock gas sweet spot area and a drilling target position. The method comprises the following steps that coal rock source rock feature evaluation and coal rock reservoir feature evaluation are conducted on coal rock to be detected; comprehensively evaluating the coal rock quality on the basis of the coal rock source rock characteristic evaluation result and the coal rock reservoir characteristic evaluation result; performing coal rock geological condition evaluation based on a coal rock quality comprehensive evaluation result; performing coal rock dessert zone evaluation based on the coal rock geological condition evaluation result to determine a coal rock dessert zone; and selecting a coal rock drilling target position based on the evaluation result of the coal rock dessert zone. According to the invention, the blank of domestic coal rock gas exploration technology is filled, the reliability and accuracy of the result are improved, and the success rate of exploration is improved.

The application provides an innovative method for analyzing carbon isotope composition of trace gas inclusions in mantle mineral rocks. The cavity of the ball mill and the mineral rock sample in the cavity are cleaned by a protective gas to remove possible gas impurities; the mantle mineral rock sample is placed in the micro-cavity of a three-dimensional high-energy vibration ball mill for vibration ball milling treatment. The released gas inclusions are transferred to a gas chromatography-isotope ratio mass spectrometry analysis system through a sealed rotary three-way valve for accurate carbon isotope composition analysis. The risk of non-native gas pollution can be significantly reduced through normal temperature crushing technology. Combined with ultra-trace gas extraction technology and efficient pre-concentration technology, the effective recovery and enrichment of trace gas in the gas inclusions in the mantle mineral rock are realized. By using high-sensitivity and high-precision isotope ratio measurement technology, the detection limit is improved, the background interference is effectively reduced, and the reliability of the analysis result is ensured.

The application discloses a method for restoring original organic geochemical parameters of high-overmature hydrocarbon source rock based on a FR-IR model, S1: collecting a large amount of marine and terrestrial basin from immature to overmature I, II1 and II2 type hydrocarbon source rock organic geochemical data; S2: establishing a HI and Tamx trend chart; S3: establishing a TOC threshold value and hydrogen index assignment; S4: selecting a large number of I, II1 and II2 type hydrocarbon source rock samples; S5: performing thermal simulation experiment, TOC and pyrolysis experiment on the samples, and performing hydrocarbon source rock evaluation; S6: establishing a FR restoration model; S7: establishing an IR restoration model; S8: collecting a large amount of world typical marine and terrestrial I, II1 and II2 type high-overmature hydrocarbon source rock organic geochemical data, and respectively performing restoration by applying the FR and IR models. The application proposes a high-precision FR-IR restoration model with universality, which can accurately restore original organic matter abundance and original hydrocarbon generation potential of high-overmature hydrocarbon source rock.

The invention provides a method, device and equipment for determining oil-gas saturation and a storage medium, and relates to the technical field of shale oil-gas exploration and development. The method comprises the following steps: determining target core analysis total organic carbon TOC of target low-resistance shale; obtaining the mixed density of kerogen and oil gas and the rock density of a target area corresponding to the target low-resistance shale; performing data processing on the mixed density of the kerogen and the oil gas, the rock density and the target rock core analysis TOC to obtain the residual hydrocarbon content of the target low-resistance shale; determining the target total porosity of the target low-resistivity shale; and determining the oil gas saturation of the target low-resistivity shale according to the residual hydrocarbon content and the target total porosity. According to the method, the accuracy of determining the oil-gas saturation of the low-resistivity shale is improved.

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 discloses a high-quality lacustrine facies hydrocarbon source rock evaluation and oil-gas source analysis method based on cyanobacteria and algae molecular geochemical indexes. The method comprises the following steps: S1, separating 2-methylhopane and hopane compounds in hydrocarbon source rock and crude oil saturated hydrocarbon by adopting a molecular geochemical analysis experiment method, and detecting 4-methylhopane compounds and organic matter carbon isotopes; s2, according to a detection result of the step S1, establishing a geochemical index system which comprises a 2-methylhopane index, a 4-methylstane index and an organic matter carbon isotope ratio; s3, evaluating the quality of the hydrocarbon source rock by adopting a geochemical index system, namely associating a 2-methylhopane index, a 4-methylstane index and a kerogen carbon isotope with a TOC value, and predicting the TOC value of the hydrocarbon source rock through a correlation chart; and S4, performing oil and gas source comparison by adopting a geochemical index system. The hydrocarbon source rock evaluation index system provided by the invention covers various biological sources in the lacustrine facies hydrocarbon source rocks, and the lacustrine facies hydrocarbon source rocks can be evaluated more accurately; a plurality of parameters are combined for use, and the applicability is wide.