85 results about "Vitrinite reflectance" patented technology

The present invention is coking blend method with gas coal, and different kinds of coking coal with required vitrinite reflectance distribution are blended. The blended coals include gas-fat coal 5-10 wt%, fat coal 5-20 wt%, 1 / 3 coking coal 30-45 wt%, coking coal 30-45 wt% and lean coal 10-18 wt%. The method of the present invention has reasonable utilization of the coking coal resource, accurate coal blending and high coke quality.

The present invention is one kind of coke coal blending ratio and coking process. The coke coal consists of fat coal 20-23 weight portions, coking coal 50-55 weight portions, 1 / 3 coking coal 15-20 weight portions, and lean coal 8-12 weight portions. The compounded coal has the quality including ash content 9-10 %, sulfur content 0.65-0.73 %, volatile component 24-26 %, G value 83-88, Ymm of 16-20, and Xmm of 20-30. The quality parameters, vitrinite reflectances and microscopic ingredients of the said four kinds of coal are specifically defined. During the coking process, the mixed coal material is sintered at 1200 deg.c for not less than 16 hr. The present invention can obtain coke with high strength.

A method is disclosed for evaluating and predicting a shale oil enrichment area of a fault lacustrine basin, comprising: obtaining materials and key data; determining a source-reservoir configuration relationship according to a longitudinal superposition relationship of different types of rock in a lithology profile and establishing a single-well lithofacies model; in the single-well lithofacies model, using a dolomite-to-formation ratio and a TOC average value to form a dolomite-to-formation ratio contour map and a TOC contour map, and superposing the dolomite-to-formation ratio contour map, the TOC contour map and a source-reservoir configuration relationship plane distribution map to form a lithofacies plane distribution map; on the basis of the lithofacies plane distribution map, superposing a vitrinite reflectance contour map and a dolomite thickness contour map to obtain a corresponding evaluation and prediction map of the shale oil enrichment area of the fault lacustrine basin.

The invention relates to a method for predicting the mechanical strength and thermal properties of coke. In the method, vitrinite reflectance distribution of coal is used as a main input parameter to predict the mechanical strength and thermal property indexes of the coke. The prediction of the mechanism strength index of the coke is realized by a BP neural network, and the prediction of the thermal property index is realized by the BP neural network or a calculation method. The method can ensure the effective use of coke coal resources, scientifically and accurately predict the cold strengthand thermal property of the coke, guarantee the quality of the coke, reduce coal blending cost, realize scientific coal blending and implement a coal blending expert system.

The invention discloses a comprehensive evaluation and prediction method for the enrichment favorable area of dense oil in a lacustrine basin. The method comprises steps of performing data collection and processing and acquisition of key data; according to the longitudinal superposition relation of different rocks in the logging lithology profile, making the configuration relationship of source and reservoir clear and establishing the single well lithofacies mode; using the single-well cloud ratio, TOC data to form the cloud-to-field ratio contour map and the TOC contour map, overlapping the cloud-to-field ratio contour map, the TOC contour map and the source and reservoir relation plane configuration map, and determining the lithofacies plane distribution map; and overlapping vitrinite reflectance contour map on the basis of the lithofacies plane distribution map, and referring to the dolomite thickness contour map to perform the comprehensive evaluation and prediction of the enrichment favorable area of the dense oil. The beneficial effect is that the method is simple in operation and high in accuracy, and can clearly and comprehensively reflect the plane distribution rule of high quality reservoir, high quality source rock and its mutual configuration relationship; and the economic cost is low and the operability is strong.

The invention relates to a method for identifying the source of a gas reservoir, and belongs to the technical field of exploration and development of oil and gas. The method makes full use of the gas geochemical data of a target space to screen gas reservoir clustering validity parameters; the genetic type of the natural gas is determined according to the screened parameters; and based on maturity of gases in different matrix natural gas types and the changes of different types of hydrocarbon source rock vitrinite reflectance with the depth, the buried depth of hydrocarbon source rock generating gases in different types of gas reservoirs is finally established; and sources of gas reservoir of different matrix types are discriminated under high thermal evolution degree. The method can effectively guide the oil and gas exploration in sag belt.

The invention discloses a quantitative calculation method for coal and rock adsorbed gas content. First, logging information is preprocessed; then, fixed carbon content and formation pressure are calculated, a quantitative relation drawing board between the coal and rock adsorbed gas content and a coal rank, a burial depth, temperature and pressure is established, and a vitrinite reflectance function and a regression coefficient between impact factors and Langmuir pressure are obtained; lastly, a dynamic adsorption calculation model of the coal and rock adsorbed gas content is established based on a Langmuir equation, and logging data and parameters are introduced into the dynamic adsorption calculation model for calculation to obtain the coal and rock adsorbed gas content; coal and rock gas characteristics are evaluated according to the coal and rock adsorbed gas content obtained through calculation. According to the quantitative calculation method, quantitative influence on the coal and rock adsorbed gas content by multiple factors under the formation condition is studied sufficiently, experimental data are utilized for scaling to the logging information under the shaft, the dynamic adsorption calculation model of the coal and rock adsorbed gas content based on the logging information is established, and the calculation accuracy of the adsorbed gas content is improved.

The invention relates to a continuous lossless whole rock natural gas generation simulation method. The method comprises the following steps of: crushing a hydrocarbon source rock sample into particles and loading into a sample tube of a thermal cracking device; connecting the sample tube and a pyrolyzing furnace of the thermal cracking device to a sample inlet of a chromatograph; regulating the pressure of carrier gas in the thermal cracking device; introducing gas into the thermal cracking device, fully adding liquid nitrogen into a liquid nitrogen cold trap, setting the heating temperature of the pyrolyzing furnace at the preset temperature, increasing the temperature of the thermal cracking device, and keeping the temperature for 50min after the temperature reaches the preset temperature to produce a gas product from the hydrocarbon source rock sample by thermal cracking; removing the liquid nitrogen cold trap and starting the gas chromatograph to analyze the gas product after the temperature of the thermal cracking device is reduced, and obtaining a chromatogram and a gas yield; changing the preset temperature and repeating the steps; and utilizing the gas yields at all the preset temperatures and the corresponding preset temperatures or the vitrinite reflectance of a coal rock sample to make a diagram within a same rectangular coordinate system, and forming a natural gas generation schematic diagram of the hydrocarbon source rock sample in different thermal evolution stages.

The invention relates to the field of coking, and particularly relates to a method for predicting the vitrinite reflectance distribution of coal blend according to coal blend ratio, vitrinite content and reflectance distribution, and a method for guiding coal blend by combining a mobility change function and a G value. The method comprises the following steps: by adopting a coal petrography analysis system, detecting the vitrinite reflectance distribution and vitrinite content of coal blend, and calculating the vitrinite reflectance distribution and content of the coal blend according to the vitrinite content, the reflectance distribution and coal blend ratio of the coal blend; and through calculation, controlling the vitrinite reflectance distribution range, the mobility and the G value of the coal blend, thus further controlling the mass of coke. According to the method disclosed by the invention, the errors of simply adding and calculating the vitrinite reflectance distribution of the coal blend according to the coal blend ratio without the consideration of different contents of different single vitrinite in a traditional method are corrected, the vitrinite reflectance distribution of the coal blend can be accurately predicted, high-strength coke under relatively low caking index conditions can be blended by combining the mobility function and G value.

The invention belongs to the field of sandstone-type uranium ore exploration, and specifically discloses an outlining method for an in-situ leaching sandstone-type uranium-bearing basin favorable mineralization section. The method comprises the steps: determining a research area, and selecting a target layer; collecting a land surface sample of a bottom plate of a basin edge target layer, a drilled coal stone sample or a carbon mudstone sample; collecting sandstone samples of the above samples at the same layer; carrying out the vitrinite reflectance measurement of the collected coal stone sample or the collected carbon mudstone sample, and calculating the maximum burial depth of an ore-containing target layer; selecting apatite minerals from the collected mudstone sample, carrying out the fission-track dating of apatite, and carrying out the inversion of the relation between temperature and time in construction evolution; verifying whether the above inversion result is matched with the actual condition or not: extracting the measurement result if the above inversion result is matched with the actual condition, or else checking whether the sampling is standard or not; drawing an erosion thickness contour map in the research area according to an erosion thickness calculation result, carrying out the research of restriction of construction uplift erosion on uranium mineralization, and outlining a favorable mineralization section. The method is clear in sampling object, is clear in analysis flow, and is simple in operation.

The invention provides a petroleum spatial distribution quantitative evaluation chart generation method under reservoir configuration constraint. The method comprises the steps: collecting different types of hydrocarbon source rock samples sequentially according to thermal evolution degree, abundance of organic matter, lithology and organic matter type; carrying out the thermal simulation experiment of the collected samples, quantifying discharged oil and retention oil at each temperature point, employing the organic carbon analysis of residue, Rock-Eval detection, and vitrinite reflectance analysis; drawing an oil discharge rate chart of different types of hydrocarbon source rocks; selecting geological sections of different basins as actual geological samples; densely collecting the hydrocarbon source rocks and storage layer rock core samples and carrying out organic carbon analysis, Rock-Eval detection, vitrinite reflectance analysis and chloroform bitumen quantitative analysis on actual geological sections; drawing an oil discharge rate parameter curve of an actual geological sample; and obtaining the petroleum spatial distribution quantitative evaluation chart generation method under reservoir configuration constraint according to the oil discharge rate charts of different types of hydrocarbon source rocks and the oil discharge rate parameter curve of the actual geological sample.

The invention provides a method for determining a gas production rate of an organic matrix in a biochemical gas production stage, and belongs to the technical field of oil and gas resource evaluation. The method comprises the following specific steps: collecting four characterization parameters of a source rock in the biochemical gas production stage of one area, namely residual hydrocarbon amount of chloroform bitumen "A", vitrinite reflectance Ro reflecting the thermal evolution degree of the source rock, organic carbon content TOC and burial depth h; establishing a graph of relation of "A" / TOC and Ro or h according to the characterization parameters of the source rock; determining the exhaust threshold of a biogenic gas according to the graph, wherein the value at the threshold is "A"<0> / TOC<0>; calculating the restoration index of the hydrocarbon generation rate of the source rock according to "A" / TOC and "A"<0> / TOC<0> under different Ro or h conditions, and calculating the total hydrocarbon generation rate of the source rock under a variety of maturity conditions through the index and the "A"<0> / TOC<0>; calculating the gas production rate of the biogenic gas of the source rock according to the difference value of the total hydrocarbon generation rate and the residual hydrocarbon rate. By adopting the method, the problems of the original methods of calculating gas production rate, such as simulation experiment and the like are solved, and important technical support is provided for biogenic gas resource evaluation.

The invention relates to a coking coal blending method with the participation of lean coal, which comprises the step of blending various single coking coals. The singe coal coals include lean coal, wherein the special interval proportion of the lean coal with a vitrinite reflectance Rmax less than 1.35% is larger than 45%, and the lean coal is 16 to 20% the total weight of the coking coals; or the special interval proportion of the lean coal with a vitrinite reflectance Rmax within 1.35 to 1.70% is larger than 65%, and the lean coal is 13 to 15% the total weight of the coking coals; or the special interval proportion of the lean coal with a vitrinite reflectance Rmax larger than 1.70% is larger than 70%, and the lean coal is 8 to 12% the total weight of the coking coals. The method can achieve quantitatively and maximally reasonable usage of lean coal in national standard classification on the premise of coke quality stabilization, thus reducing the coal blending cost.

The invention discloses a method for determining gas contents of coal beds, and belongs to the field of coal bed gas exploration and development. The method includes forming theoretical values of Langmuir volumes corresponding to different coal rank conditions on the basis of Langmuir isothermal adsorption theoretical model derivation; applying corresponding conventional well logging data on the basis of the theoretical values, combining the well logging data with coal and rock test analysis and isothermal adsorption experiment data and quantitatively computing and determining the gas contents of the coal beds. The method has the advantages that Langmuir isothermal adsorption models are improved, relations between the maximum vitrinite reflectance and the Langmuir volumes are analyzed, a process for solving the maximum vitrinite reflectance by the aid of conventional well logging curves is created, and accordingly the gas contents of the coal beds can be determined; the method is continuous in evaluation and cognition, good verification effects can be realized, shortcomings of difficulty in experimental sampling and excessively high cost due to the fact that gas contents are measured by the aid of existing experimental technologies at present can be effectively overcome, and reliable reservoir parameters can be provided for developing coal bed gas in various basins in China.

The invention provides a method for calculating original organic matter abundance recovery coefficient, which comprises the following steps: establishing a mathematical relationship between an organic matter-type hydrocarbon-generation rate G and a vitrinite reflectance Ro; calculating the relation of residual degradation rate Dc and the hydrocarbon-generation rate; when the original hydrocarbon-generation rate Gy is hypothesized as the hydrocarbon-generation rate when the vitrinite reflectance Ro equals 4, according to the relation between the hydrocarbon-generation rate G and the vitrinite reflectance Ro as well as the residual degradation rate Dc and the hydrocarbon-generation rate G, obtaining the relation of high-evolution hydrocarbon source rock original organic matter abundance recovery coefficient Rc and the vitrinite reflectance Ro; using the vitrinite reflectance Ro and conversion coefficient a of conversion from effective organic carbon to hydrocarbons to calculate the high-evolution hydrocarbon source rock original organic matter abundance recovery coefficient Rc, and recovering the high-evolution hydrocarbon source rock original organic matter abundance. The method has the obvious characteristics of less parameter and simple operation.

The invention discloses a chemical method for weakening of top coal. The method successively comprises the following steps: selecting a coal seam with vitrinite reflectance of R<o, max> and hard, complete and difficult-to-cave top coal; perforating drilling holes in the coal seam and sealing the holes; preparing an alkali solution, injecting the prepared alkali solution into the drilling holes and carrying out soaking for a period of time; organizing subsequent production according to conventional top coal caving procedures; and comparing the chemical method with traditional physical measures like waterflooding cracking and loosening blasting so as to examine caving improvement effects of the chemical method on the coal seam. According to the invention, the injected alkali solution does not lead to cracks of the coal seam and chemically reacts with the coal seam to rapidly reduce mechanical strength of the coal seam, so caving and drawing characteristics of the coal seam are obviously improved. The method has the advantages of simple operation, good controllability, low cost and a good top coal weakening effect and effectively overcomes problems like difficult top coal caving and a low mining rate of low-rank coal.

The invention discloses a coal blending expert system fit for a top-loading coke oven. The coal blending expert system comprises a coal data and coal blending data acquisition module, a coke performance autoregression module, an optimization coal blending module and a coal blending result acquisition and inspection module. The system adopts a combined method of multi-parameter nonlinear regression, a coal vitrinite reflectance distribution diagram and a coal fluidity distribution diagram, so that the coke strength prediction deviation is controlled to be within 2%. Meanwhile, nonlinear optimization coal blending is carried out with the goal of the lowest coke net cost, the influence of the coking byproduct yield, the market price and the coal quality and price on the net cost is considered, and coking and coal blending with the lowest cost are really carried out.

The invention relates to a method for discriminating affinity of a high-maturity crude oil, and belongs to the technical field of oil and gas exploration and development. The method for discriminatingaffinity of the high-maturity crude oil provided by the invention comprises the following steps: 1) calculating the relationship between the methylphenanthrene index MPI and the vitrinite reflectanceRo of the phenanthrene series compound in the source rock extract to obtain the values of A, B, C, and D; 2) calculating the relationship between the methylphenanthrene index MPI of the phenanthreneseries compound in the crude oil and the maturity Rc of the crude oil to obtain Rc; 3) establishing a change relationship between the vitrinite reflectance and the geological history of the source rocks of different horizons; and 4) assuming the source horizon and accumulation time of crude oil by using the Rc in the step 2) and the change relationship between the vitrinite reflectance and the geological history determined in the step 3). The method for discriminating affinity of the high-maturity crude oil provided by the invention can finely determine the source of deep oil and gas, therebyguiding the efficient exploration of deep oil and gas.

The invention discloses a method for preventing and controlling coalbed rockburst through chemical reaction, which sequentially comprises the following steps: selecting a coalbed with rockburst disasters and a vitrinite reflectance of less than 0.6%; selecting a certain area in the coalbed to carry out hole drilling; blocking orifices of drilled holes; preparing an alkali solution; pumping the prepared alkali solution into the drilled holes to soak for a period of time; and monitoring in a slight shock, electromagnetic radiation or cuttings drilling mode so as to ensure that the outburst-proneness is eliminated, repeatedly carrying out soaking many times until the outburst-proneness is completely eliminated. Compared with the traditional physical rockburst prevention and control measures, and the traditional rockburst prevention and control measures, the method disclosed by the invention is not only good in rockburst prevention and control effect, but also convenient to construct, high in safety and low in cost, eliminates the outburst-proneness rapidly and thoroughly, avoids the defect that the traditional water injection and absorption speeds are slow, provides a new prevention and control method for low-rank coalbed rockburst, and has a broad application prospect in low-rank coalbeds.

The invention provides a prediction method and exploration method of geological sweet spots of a reservoir of inter-salt shale series of strata and relates to the field of petroleum survey. The prediction method comprises the following steps: sampling different shale series of strata in the inter-salt shale series of strata to determine the rocky lithofacies of the shale series of strata; samplingthe shale series of strata with the rocky lithofacies of dolomite to determine the content of organic carbon, vitrinite reflectance, porosity, permeability, flowable pore throat radius, density, structure, soundwave, flowable oil mass heat releasing hydrocarbon and oil saturability index, wherein the rocky lithofacies, hydrocarbon source condition, storage and gathering condition and oil containing characteristic are met; and obtaining the sweet spots of the reservoir of inter-salt shale series of strata and the positions thereof and comparing the prediction result with the exploration result, wherein the relative error is smaller than 20%. The method has relatively high prediction precision and high field practicality. The method applied to exploring the geological sweet spots of the reservoir of inter-salt shale series of strata has relatively excellent field practicality.

The invention discloses a paleo-thermal lithosphere thickness determination method and device. The method comprises the following steps: obtaining rock heat conductivity and rock heat production rate of each structure layer in a research area; establishing a paleostructure layer model of the research area in a preset geological time by utilizing a stratum backstripping technology, and determining the thickness of each structure layer according to the paleostructure layer model; obtaining paleo-surface heat flow value of each structure layer in a simulated manner according to vitrinite reflectance actually-measured value; calculating top boundary heat flow values of each structure layer according to the paleo-surface heat flow values, rock heat production rate and the thickness of each structure layer; determining shallow earth one-dimensional heat conduction geotherm according to the top boundary heat flow values, the thickness of each structure layer, the rock heat conductivity and rock heat production rate; and determining the depth of the shallow earth one-dimensional heat conduction geotherm intersecting with a mantle adiabatic line as the thickness of the paleo-thermal lithosphere. According to the method and device, the paleo-surface heat flow and paleo-surface thickness can be obtained, and furthermore, the thickness of the paleo-thermal lithosphere is calculated; and the problem that the paleo-thermal lithosphere thickness and evolution cannot be determined in the prior art is solved.

The invention relates to a coal petrographic analysis test and graph processing method. The method adopts a digital coal petrographic analyzer to determine the vitrinite reflectance of coal, and according to the final graphics, deletes the scattered part that has a percentage content close to 0, smooth image and rising peak and is affected by interfering components, thus ensuring that the determined graph reflects the true components of coal. Compared with the prior art, the method provided by the invention can truly reflect the quality of coal provided by a supplier, more objectively reflect the real situation of coal so as to better serve coking and iron-making production, meets the fined large-scale production needs of companies, and provides more real and accurate data.

The invention provides an experimental method for simulating a shale organic pore evolution process. The experimental method comprises the step one of, collecting an immature-low maturation shale sample, cutting the immature-low mature shale sample into a plurality of shale blocks, and polishing the shale blocks; the step two of determining simulation temperature, pressure and time; the step threeof filling quartz sand in a sample chamber, and sequentially filling the shale blocks; the step four of carrying out a thermal simulation experiment on hydrocarbon generation and evolution of shale in a low evolution stage; the step five of taking out the shale blocks, mechanically grinding parts of the shale blocks, etching the surface of the sample, and measuring the vitrinite reflectance according to an SY / T5124-2012 sedimentary rock vitrinite reflectance measurement method; the step six of repeating the step three and the step five; and the step seven of repeating the step six until the set evolution phase is all completed. According to the experimental method, after thermal simulation in different evolution stages, the requirement of argon ion polishing sample preparation on scanningelectron microscope observation can be met, and the influence of shale heterogeneity and the damage effect of a pressing device on the shale sample are reduced.

The invention discloses an evaluation method of the maturity of lower paleozoic marine shale organic matter. The evaluation method comprises the steps that (1) samples are collected and screened, wherein a marine shale sample is selected, and the sample is polished or made into a polished section through mechanical polishing equipment or an argon ion polishing machine and other equipment; (2) microscopic components are observed; (3) a conversion formula (EqVRo=1.055*R<gr>-0.053) of graptolite dermatosome random reflectance (R<gr>) and equivalent vitrinite reflectance (EqVRo) and a conversion formula (EqVRo=0.9096*R+0.1643) of raw asphalt random reflectance (R) and the equivalent vitrinite reflectance (EqVRo) are established, wherein R<2>=0.98 in the first conversion formula, and R<2>=0.96 in the second conversion formula; and (4) the maturity of the lower paleozoic marine shale organic matter is evaluated. According to the evaluation method, through microscopic component observation on lower paleozoic marine shale, correct classification and interference elimination, an equivalent relation between the graptolite dermatosome reflectance and the vitrinite reflectance and an equivalent relation between the raw asphalt reflectance and the vitrinite reflectance in the lower paleozoic marine shale are established, and correct evaluation of the maturity of the lower paleozoicmarine shale organic matter is realized.

The invention belongs to the field of coal blending, and particularly relates to a method for diagnosing a fluctuation reason of quality of coke. The coke is measured, if any one or two of the particle size of the coke and the ash content of the coke is / are not in the defined range, vitrinite reflectance detection is carried out on the mixing coal of the coke, the result is recorded on a vitrinite reflectance distribution diagram with the abscissa as the reflectance range and the ordinate as the mass percent of a single coal in the overall mixing coal, so that the actual coal types of the mixing coal and the actual proportion of each coal type can be determined, and the actual proportion of each coal type is compared with the set proportion of the coal blending process so as to regulate the set proportion of the coal blending process. According to the method, the mixing coal generating coke of specified indicator can be allocated, so that the energy resource waste is reduced, and the cost of mixing coal is saved.

The invention discloses a method for preventing and controlling coalbed rockburst through chemical reaction, which sequentially comprises the following steps: selecting a coalbed with rockburst disasters and a vitrinite reflectance of less than 0.6%; selecting a certain area in the coalbed to carry out hole drilling; blocking orifices of drilled holes; preparing an alkali solution; pumping the prepared alkali solution into the drilled holes to soak for a period of time; and monitoring in a slight shock, electromagnetic radiation or cuttings drilling mode so as to ensure that the outburst-proneness is eliminated, repeatedly carrying out soaking many times until the outburst-proneness is completely eliminated. Compared with the traditional physical rockburst prevention and control measures, and the traditional rockburst prevention and control measures, the method disclosed by the invention is not only good in rockburst prevention and control effect, but also convenient to construct, high in safety and low in cost, eliminates the outburst-proneness rapidly and thoroughly, avoids the defect that the traditional water injection and absorption speeds are slow, provides a new prevention and control method for low-rank coalbed rockburst, and has a broad application prospect in low-rank coalbeds.

The invention relates to a reconstruction method for a three-dimensional heat flow space-time field in a petroliferous basin. The reconstruction method includes following steps: 1), collecting and tidying basic data in the basin; 2), establishing a geologic history model in the basin; 3), establishing a vitrinite hydrocarbon dynamics calibration model; 4), constructing an objective function of ancient geothermal gradient and ancient ground surface temperature during various layer deposition periods; 5), solving the objective function; 6), evaluating a vitrinite reflectance space-time field in a basin inner well; 7), judging whether or not, analogue values and measured values of a single well vitrinite reflectance space-time field and a temperature field meet accuracy requirement; 8), establishing a rock thermal conductivity model; 9), reconstruct the three-dimensional heat flow space-time field of a single well; and 10), reconstructing the three-dimensional heat flow space-time field in the basin. The reconstruction method can be widely used for reconstruction of three-dimensional heat flow space-time fields in the petroliferous basin, and provides technical support for exploration and development of oil gas in the basin.

The invention provides a coking coal blending method with the participation of lean coking coal. Components of coking coal of the lean coking coal comprises, in percentage by weight, 8%-18% of 1 / 3 coking coal, 10%-18% of fat coal with a dry ash-free basis volatile component (Vdaf) larger than or equal to 32% and smaller than or equal to 34%, 8%-14% of fat coal with a dry ash-free basis Vdaf larger than or equal to 28% and smaller than 32%, 30%-50% of coking coal with the caking index G larger than or equal to 78, 0%-25% of coking coal with the caking index G larger than or equal to 75 and smaller than 78 and 10%-30% of lean coking coal. The ash content of the coking coal is 8%-9.5%, the sulfur content is 0.6%-0.9%, the volatile content is 25%-27%, and the vitrinite reflectance is distributed continuously and normally. The blended proportion of the lean coking coal with the method reaches 30%, and the vitrinite reflectance of the coking coal is distributed continuously and normally, so that while high-quality coking coal is protected, low-cost coal blending is achieved for enterprises; the produced coking coal ash content is below 12.5%, and the sulfur content is below 1.0%, therefore, the requirement for coking coal consumption of large blast furnaces can be completely met.

The invention provides a paleo-heat flow change recovering method and device. The method comprises the following steps: stratum information of different strata in a survey region is obtained, wherein the stratum information comprises sample depths of all sample points in all the strata, geologic history times, vitrinite reflectance, a current earth surface temperature, a current geothermal gradient, paleogeotemperature of initial sediment, the maximal burial depth of a sediment base, thermal conductivity of all the strata and geologic history times which the sediment goes through; a time-temperature index of all the sample points in each stratum is obtained; a theoretical time-temperature index model of all the sample points in each stratum is established; a paleo-heat flow back-stripping calculation model is established; a palaeogeothermal gradient of each stratum at the time of sedimentation is obtained; according to the obtained palaeogeothermal gradient of each stratum at the time of sedimentation, the paleo-heat flow value of the corresponding stratum is calculated; according to the change trend of the paleo-heat flow value of each stratum over time, different mathematic models are selected for fitting, and a change rule of paleo-heat flow over time is determined. The paleo-heat flow change recovering method can be applied to complicated geological conditions, thereby being better in adaptability and effectiveness.

The invention provides a method and a device for predicting oil-gas quantity produced by in-situ development of shale oil, and the method comprises the following steps: obtaining an original total organic carbon content TOC value, a vitrinite reflectance Ro value and an original hydrogen index HI value of shale to be measured; obtaining the in-situ development output oil gas quantity of the to-be-measured shale according to the original TOC value, the Ro value and the original HI value of the to-be-measured shale, and a pre-established shale oil in-situ development output oil quantity prediction model and a shale oil in-situ development output gas quantity prediction model. The shale oil in-situ development output oil quantity prediction model and the shale oil in-situ development output gas quantity prediction model are pre-established according to output oil gas quantity data obtained by performing thermal simulation experiments on a plurality of different shale samples and originalTOC values, Ro values and original HI values of the shale samples. According to the technical scheme, quantitative prediction of the oil-gas quantity produced by in-situ development of the shale oil is realized, and the prediction precision and efficiency of the oil-gas quantity produced by in-situ development of the shale oil are improved.