391 results about "Shale oil" patented technology

The invention discloses a shale oil reservoir geology-engineering double-dessert compressibility comprehensive evaluation method, and relates to the technical field of petroleum and natural gas yield increase transformation and geotechnical engineering, in particular to a shale oil reservoir geology-engineering double-dessert compressibility comprehensive evaluation method, which comprises the following steps of performing normalization processing on a logging basic parameter standard deviation; geological dessert parameters are established by calculating the weight of each factor; influence factors influencing the longitudinal expansion capacity of the hydraulic fracture of the target reservoir are obtained; constructing a geological-engineering double-dessert compressibility comprehensive evaluation model of three types of lithofacies'reservoir performance-transformation potential 'synergistic mechanisms; and establishing a geological-engineering double-dessert compressibility kernel density estimation map, and dividing the reservoir compressibility on the premise of adaptive bandwidth. According to the method, the operability and prediction precision of an evaluation result are remarkably improved, and an innovative decision support tool is provided for horizon optimization and scheme design of shale oil reservoir fracturing transformation.

The invention discloses a shale oil geological engineering dessert evaluation method and device based on geological modeling, and the method comprises the steps: determining a shale oil facies classification scheme and shale oil dessert evaluation key parameter values according to the shale oil geological engineering logging interpretation data, determining the corresponding scores of different shale rocks, and obtaining the shale oil dessert evaluation key parameter values of the shale oil facies classification scheme and the shale oil dessert evaluation key parameter values of the shale oil facies classification scheme; and determining a target sweet spot evaluation parameter weight based on sweet spot evaluation attributes of the lithofacies three-dimensional model and actual well drilling productivity data, establishing a shale oil geological engineering integrated comprehensive sweet spot factor, and determining a shale oil geological engineering comprehensive sweet spot evaluation result based on the sweet spot factor and the target sweet spot evaluation parameter value. Through the technical scheme of the embodiment of the invention, comprehensive evaluation of shale oil geological engineering desserts is realized, complexity of shale oil geological features can be adapted, correlation between geological and engineering dessert evaluation parameters is improved, and fine evaluation of shale oil dessert space distribution is ensured.

The invention relates to the field of oil and gas field exploration and development, in particular to a shale oil dessert well logging evaluation method and device based on source-reservoir coupling characteristics, and the method comprises the steps: determining the reservoir quality according to the effective porosity and effective thickness of a shale oil reservoir in a research area; the effective porosity is greater than a preset porosity lower limit threshold; evaluating the quality of each hydrocarbon source rock stratum section according to the effective points of the total organic carbon content of the kerogen in the research area, the effective thickness of the layer section corresponding to each effective point and the total organic carbon content of the kerogen of the effective point; according to the coupling relation between the reservoir quality and the quality of the hydrocarbon source rock stratum section within the estimated longitudinal distance range of the position of the effective point of the total organic carbon content of the kerogen; according to the coupling relation, shale oil desserts within the longitudinal distance range are evaluated and estimated. On the basis of hydrocarbon source rock quality classification, reservoir quality classification and a source-reservoir coupling relationship, a foundation is laid for accurate classification evaluation of shale oil dessert development sections.

The present description relates to the field of oil and gas field exploration and development, and in particular, to a shale oil sweet spot logging evaluation method and apparatus based on source-reservoir coupling characteristics. The method comprises: on the basis of the effective porosity and effective thickness of a shale oil reservoir in a research area, determining reservoir quality, wherein the effective porosity is greater than a preset porosity lower threshold; on the basis of effective points of kerogen total organic carbon content in the research area, the effective thickness of an interval corresponding to each effective point, and the kerogen total organic carbon content of each effective point, evaluating the quality of source rock intervals; on the basis of an estimated longitudinal distance range of the positions where the effective points of kerogen total organic carbon content are located, determining a coupling relationship between the reservoir quality and the quality of the source rock intervals; and on the basis of the coupling relationship, evaluating a shale oil sweet spot within the estimated longitudinal distance range.

A method for evaluating contribution of each component to shale oil reservoir resistivity at high temperature and high pressure is applied to the field of oil exploration and development. The method comprises the following steps: (1) analyzing the volume percentage of each clay mineral, the pore water content and the mineralization degree of the shale oil reservoir pressure-maintaining closed core; (2) when the fluid pressure is greater than 23MPa, measuring the resistivity of the pressure-maintaining closed rock core at each temperature point; (3) carrying out water balance treatment on pure clay minerals, namely kaolinite, montmorillonite, illite and chlorite, and measuring the resistivity at each temperature point when the fluid pressure is greater than 23MPa; (4) when the fluid pressure is greater than 23MPa, measuring the resistivity of each temperature point of the solution consistent with the mineralization degree of the pore water; and (5) constructing a resistivity evaluation model, and evaluating the contribution of each component to the resistivity of the shale oil reservoir under the condition of high temperature pressure.

The invention discloses a shale oil content prediction method, device and equipment and a medium, and relates to the technical field of shale oil exploration and development. A high-quality model training sample data set is constructed by integrating shale oil content data actually measured by an oil field and associated logging data of the shale oil content data. And based on the data set, performing model training by adopting a long-short-term memory neural network enhanced based on an attention mechanism, constructing a high-precision shale oil content prediction model, and further performing oil content prediction by utilizing the trained shale oil content prediction model. Petroleum logging data and a deep learning technology are combined, accurate calculation of the oil content of the shale reservoir in the stratum in-situ state is achieved, and the reliability of a prediction result is remarkably improved. Compared with a traditional method, the method has the advantages that the analysis period is greatly shortened, the test cost is reduced, meanwhile, the method has excellent generalization ability, the oil content prediction requirements of different types of shale oil reservoirs can be met, and efficient and accurate technical support is provided for shale oil exploration and development.

The invention relates to the field of oil and gas reservoir exploration and development, and discloses a shale oil reservoir carbon dioxide injection exploitation effect prediction method and device, and the method comprises the steps: obtaining the characteristic parameters of a target core and the engineering parameters of a target block; constructing molecular dynamics models corresponding to different minerals in the target rock core according to the characteristic parameters and the engineering parameters; determining a target relational expression according to a simulation result of each molecular dynamics model; based on a target pore network model and the target relational expression, the exploitation effect of carbon dioxide injection of the shale oil reservoir is determined, and the target pore network model is obtained based on the characteristic parameters. Due to the fact that the flow rule of fluid in the nanoscale pores, nanoscale effect changes and differences among different mineral types are considered when the exploitation effect of the shale oil reservoir injected with the carbon dioxide is predicted, the accuracy of prediction of the exploitation effect of the shale oil reservoir injected with the carbon dioxide can be improved.

The invention relates to the technical field of shale oil exploitation, in particular to a shale oil working fluid displacement device and a reservoir physical property evaluation method. In the shale oil working fluid displacement process, dynamic pressure difference time sequence data corresponding to all moments are obtained, and due to the fact that the viscosity and flow characteristic difference of different fluid media is large, dynamic pressure difference fluctuation is remarkable during displacement; determining the fidelity of the displacement pressure at each moment by analyzing the frequency domain and linear regression characteristics; thirdly, all moments are clustered based on the dynamic pressure difference and the displacement pressure fidelity, and the moments in the same displacement state are clustered into one class; in view of the fact that fixed PID parameters are difficult to adapt to different working fluid medium characteristics and can cause control delay, in a cluster to which the current moment belongs, moment distribution characteristics and dynamic pressure difference time sequence data dynamic estimation characteristics are analyzed, the pressure instability degree and the observation uncertainty are reflected, a preset gain coefficient is adjusted accordingly, more accurate PID control is achieved, and the control precision is improved. And the reliability of subsequent reservoir physical property evaluation is ensured.

The present application belongs to the technical field of oil well wax removal and prevention, and relates to a shale oil well shaft wax removal and prevention agent and a preparation method thereof. The shale oil well shaft wax removal and prevention agent comprises the following raw materials in percentage by mass: 40-55% of an oily solvent, 1-3% of a cosolvent, 1-2% of an imidazole double-trifluoromethylsulfonylimide salt, 10-20% of a wax crystal modifier, 3-5% of an emulsifier, 1-2% of an alkaline adjusting agent, and 25-35% of water, with the sum of the percentage by mass of each raw material being 100%; the wax crystal modifier is prepared by copolymerizing (methyl) acrylic C12-C16 ester, (methyl) acrylic C1-C3 ester and (methyl) acryloyl chloride, and then reacting with C20-C30 alkyl alcohol. The wax crystal modifier in the present application has long-mid-short branched chains, and cooperates with the imidazole double-trifluoromethylsulfonylimide salt to improve the wax removal effect and low-temperature fluidity, thereby achieving high-efficiency wax removal and prevention effect and still maintaining good wax removal and prevention effect at low temperatures.

The application discloses a multifunctional biological imbibition agent and a preparation method and application thereof. The preparation method of the multifunctional biological imbibition agent comprises the following steps: (S1), alkylization reaction to obtain alkyl naphthalene; (S2), chloromethylation reaction to obtain halomethyl alkyl naphthalene; (S3), halogen alkyl nucleophilic substitution reaction to obtain hydroxymethyl alkyl naphthalene; and (S4), esterification reaction to obtain the multifunctional biological imbibition agent. The application further discloses application of the multifunctional biological imbibition agent as an imbibition agent in shale oil reservoir oil extraction. The application has the following advantages: (1) the reservoir adsorption amount is small, but the good wetting reversal characteristic is still maintained, and the emulsification is weak; (2) the high-temperature resistance is strong, and the temperature resistance reaches above 200 DEG C; (3) the preparation process is simple, and the yield is high; (4) the dosage is small, the cost is low, and the economic benefit is remarkable.

The utility model relates to the field of oilfield development, and discloses a shale oil high-sulfur flowing well ground desulfurization device which comprises a mixing tank, a support frame, a desulfurizer spraying mechanism, a transition pipeline, an S-shaped distributed ground desulfurization pipeline group and a buffer pool, the S-shaped arrangement ground desulfurization pipeline group comprises a plurality of desulfurization pipelines which are laid on the ground and are parallel to one another and pipe bending mechanisms which are connected with corresponding position ports of the adjacent desulfurization pipelines. The device is simple in structure, small in equipment fixing investment and low in operation cost, and has good economic benefits; the flow velocity is delayed through gravity oil discharge, the flow in the pipeline is increased and the time is prolonged by additionally arranging the S-shaped distributed ground desulfurization pipeline group formed by the bent pipes, and homogenization is performed through the buffer pool, so that shale oil and a desulfurizer are fully and uniformly mixed, the desulfurization effect is better, and the safety production is better guaranteed; the S-shaped arrangement mode of the ground desulfurization pipelines is small in occupied area, land space is saved, and good resource utilization benefits are achieved.

The invention relates to the technical field of model construction, in particular to a displacement fluid and shale rock imbibition law numerical simulation method and system. According to the method, by quantitatively analyzing the linear correlation degree of granularity and experimental capillary constant distribution and the disturbance degree of local feature points, regularization parameters of a regression algorithm are dynamically adjusted, and on the basis of accurately-calibrated capillary constants, a contact angle is determined by combining permeability characteristic data of probe liquid, so that the permeability of the probe liquid is determined. According to the method, shale surface free energy is obtained through surface energy component theoretical model decoupling, the interface action state of displacement fluid, shale and crude oil is reflected through a three-phase contact angle determined through a three-phase equilibrium relation, and the adhesion work needed by shale oil stripping is obtained. According to the method, the high-precision fitting model of the granularity and the capillary constant is established, and the surface energy component theory is combined, so that more accurate calculation of the shale oil stripping adhesion work is realized, and a reliable numerical simulation basis is provided for improving the shale oil recovery ratio.

The invention relates to a resistivity-based shale reservoir artificial fracture relative permeability testing method, which comprises the following steps of: respectively placing a plunger sample rock core, a parallel sample rock core X1, a parallel sample rock core X2 and a parallel sample rock core X3 which are subjected to resistivity testing and are filled with a propping agent into a special insulating rock core holder, and connecting the special insulating rock core holder into a rock core permeability testing device; reducing the reservoir temperature and pressure conditions of the core X3, and performing an independent measurement experiment on the core X3 by a steady-state method; drawing a relational graph of the propping agent filling crack resistance value and the water saturation: performing an experiment on the core X1 and the core X2 by a steady-state method, changing the oil-water injection ratio, and performing a re-experiment; determining the water saturation of the rock core proppant filling crack of the experimental group; calculating the relative permeability of the rock core X1 proppant filling crack; and drawing an oil-water relative permeability curve chart. The method can measure the water saturation of the proppant filling crack in real time under the shale oil reservoir temperature and pressure condition.

The embodiment of the invention relates to the technical field of oil and gas field development, and discloses a shale oil reservoir carbon dioxide huff and puff recovery ratio prediction method and equipment, and the method comprises the steps: determining a first influence weight for a fracturing fracture morphological parameter in geological parameters and fracturing construction parameters; determining a second influence weight of the geological parameter, the fracturing construction parameter, the fracturing fracture morphological parameter and the carbon dioxide huff and puff mining parameter on the shale oil well productivity; according to the fracturing fracture propagation key parameters, the microseism monitoring fracture morphological parameters, the numerical simulation fracturing fracture morphological parameters and a pre-generated type-2 fuzzy logic model, determining a fracturing fracture morphological propagation key parameter range under different geological parameter, rock mechanics and fracturing construction parameter grade conditions; and predicting the recovery ratio of the target shale work area according to the fracturing fracture form extension key parameter range and different artificial neural networks. According to the method, the shale oil reservoir CO2 huff and puff recovery efficiency can be efficiently, intelligently and accurately predicted.

The application provides a method for characterizing millimeter shale oil and gas reservoir heterogeneity, which mainly solves the problem of low reliability and precision of existing volume sampling method for evaluating reservoir results. Its characteristics are as follows: S1: mud shale millimeter mineral component identification and drilling; S2: based on the obtained powder sample, oil and non-oil tests are carried out; by comparing before and after extraction, the occurrence pore size distribution is determined to characterize the reservoir property; S3: based on the obtained powder sample, the oiliness of different lamina / laminated components is characterized; S4: based on the reservoir property and oiliness of different lamina / laminated components, the millimeter shale oil reservoir heterogeneity is characterized. The method can enhance the identification accuracy of shale lamina / laminated structure, realize millimeter fine characterization of different lamina / laminated properties, and provide favorable support for shale oil enrichment mechanism and "sweet spot" prediction.

This application provides a method, apparatus, and system for determining the compressibility of shale oil reservoirs. The method includes: acquiring compressibility evaluation parameters for shale oil reservoirs, whereby these parameters are data corresponding to factors influencing the compressibility of the shale oil reservoir; analyzing these parameters using a dimensionality reduction method to obtain independent evaluation parameters; calculating a compressibility index based on the independent evaluation parameters; and determining the compressibility of the shale oil reservoir based on the compressibility index. This method uses a dimensionality reduction method to analyze the aforementioned compressibility evaluation parameters to obtain independent evaluation parameters, facilitating the calculation of the compressibility index. Based on this index, the compressibility of the shale oil reservoir is determined. Compared to methods that determine reservoir compressibility solely through brittleness indices or experimental methods such as clay mineral content, this method comprehensively considers multiple compressibility evaluation parameters that influence the compressibility of shale oil reservoirs, resulting in a more comprehensive analysis and improved accuracy in compressibility evaluation.

This invention relates to the field of unconventional oil and gas development technology, and to a device and method for quantitatively evaluating the permeability enhancement caused by oxidative thermal stress in shale oil. The former includes a triaxial core holder housed within a constant-temperature chamber, and confining pressure injection system, oxidation medium injection system, detection medium injection system, gas collector, upstream storage tank, downstream storage tank, chromatograph, and acoustic emission sensor spaced apart outside the chamber. This application provides a dynamic multi-field coupled physical simulation system capable of simulating real formation conditions. By collecting pressure, product composition, acoustic signals, and nuclear magnetic resonance relaxation data, it utilizes a mathematical model for dynamic inversion of porosity and permeability using the pressure pulse attenuation method. It integrates acoustic emission RA-AF source identification and nuclear magnetic resonance fractal evaluation to analyze the multi-field coupling effects of thermal, flow, force, and chemical fields generated during air injection, and quantitatively evaluates the degree of improvement in shale permeability and pore structure caused by oxidative expansion.

The invention provides a shale oil stratigraphic development degree identification chart construction method and identification method, and the method comprises the steps: carrying out the element analysis of a shale core or rock debris sample, and obtaining the geochemical parameters of a stratum; rock core observation is carried out on the shale rock core or rock debris sample, and the bedding development degree of the stratum is obtained; on the basis of the geochemical parameters and the bedding development degree, geochemical parameters which are highly related to the bedding development degree are obtained; and obtaining a bedding development degree identification chart based on the geochemical parameters having strong correlation with the bedding development degree. According to the method, the correlation between the stratigraphic element geochemical parameters and the bedding development degree is analyzed, the element geochemical parameter combination strongly related to the bedding development degree is selected, and then the bedding development degree recognition intersection chart is established and used for recognizing the bedding development degree. The method for identifying the bedding development degree while drilling is provided for the shale oil horizontal well.

The application discloses a shale oil reservoir core micro-percolation model and a preparation method and application thereof, and belongs to the technical field of oilfield development experiment researches.The core micro-percolation model comprises a rock sample and adhesive glass sheets used on two surfaces of the rock sample, and according to the oil-water flow direction in the rock sample, the side surface of the rock sample is set as an inflow end, an outflow end, a first end and a second end respectively, one or two needle heads are arranged close to the inflow end, one needle head is arranged close to the outflow end, and the core micro-percolation model is packaged through glue.The single-needle head and double-needle head micro-percolation models are prepared for different types of shale oil reservoir cores, and oil-water two-phase percolation experiments are carried out on typical rock samples; through the experiments, more accurate understanding of the percolation channels of oil and water in the shale reservoir core is obtained, the distribution states of residual oil and bound water in the core are accurately characterized in a visualized mode, and important references can be provided for the research on percolation curves, the understanding of percolation rules and the compilation of development schemes.

The invention provides a method for producing low-carbon olefins and aromatic hydrocarbons from inferior raw materials. The method comprises the following steps: performing hydrogenation upgrading on an inferior raw material, and performing fractionation on a product system obtained by hydrogenation upgrading to obtain first light distillate oil with the boiling point being less than or equal to 180 DEG C, hydrogenation upgraded oil with the boiling point being greater than 180 DEG C and less than or equal to 350 DEG C, and first tail oil with the boiling point being greater than 350 DEG C; mixing the hydrogenated upgrading oil and the heavy crude oil, carrying out catalytic cracking, and separating an oil-gas mixed product system obtained by catalytic cracking to obtain C1-C4 light olefins, second light distillate oil with the boiling point of less than or equal to 200 DEG C and second tail oil with the boiling point of more than 200 DEG C; and carrying out aromatic hydrocarbon extraction on the first light distillate oil and the second light distillate oil to obtain C6-C8 light aromatic hydrocarbons. According to the invention, production raw materials of low-carbon olefins and aromatic hydrocarbons can be expanded to heavy crude oil, shale oil and coal pyrolysis oil.

The invention relates to the technical field of oil development, and discloses a method, a device and equipment for determining soaking time and an oil reservoir imbibition utilization rate. The method comprises the following steps: step S10, selecting a rock sample; step S20, cutting the rock sample into a long plunger and a plurality of short plungers; s30, performing saturated crude oil simulation on the long plunger and the plurality of short plungers to obtain related parameters of the long plunger in an initial oil layer state and water saturation Sw0 of the short plungers in the initial oil layer state; step S40, simulating a soaking process and an imbibition process; s50, the relevant parameters of the long plunger at different imbibition time are obtained at different time of the imbibition process; step S60, measuring the water saturation Sw2 of the short plunger for multiple times; and S70, the soaking time and the oil reservoir imbibition utilization rate are obtained. According to the method, the soaking time of the shale oil reservoir and the imbibition utilization rate of the oil reservoir can be obtained, so that the recovery efficiency of shale oil is improved.

The present application relates to a kind of shale oil carbon dioxide fracturing production dynamic intelligent prediction method, the method is applied to the improved AHP-GRA-EWM method quantitatively calculate the influence weight of different categories factors to different stage carbon dioxide fracturing-throughput shale oil well production dynamic parameter, obtain the main control influence factor of different production stage production dynamic parameter;The main control influence factor of different production parameters of different production stages is respectively introduced into different artificial neural network system, nonlinear polynomial regression model system and different percolation mathematical model, establishes prediction model, selects the model with highest prediction accuracy to correct improvement, combination generates the production dynamic intelligent prediction model of the entire production cycle of target shale reservoir block carbon dioxide fracturing-throughput shale oil well;Based on the intelligent prediction model, the different production parameter values of different production stages of new well are calculated, and the production dynamic curve is drawn.The method designed by the present application can realize the fine and efficient prediction of carbon dioxide fracturing-throughput shale oil well production dynamics, provide basis for the development of development plan and optimization, improve the single-well production and recovery ratio of target shale reservoir block.

The embodiment of the invention provides a shale oil recovery control method, device and equipment and a medium, and belongs to the technical field of oil and gas recovery. The method comprises the steps of obtaining dynamic data of a reservoir, wherein the dynamic data comprises historical production data and multi-scale feature data used for reflecting the reservoir; based on the dynamic data, an oil reservoir digital twinborn model is constructed, and the oil reservoir digital twinborn model couples seepage, geomechanics, thermal and chemical processes; inputting the dynamic data into a pre-trained machine learning model to obtain initial injection-production parameters; inputting the initial injection-production parameters into an oil reservoir digital twinborn model to obtain a prediction result of production data corresponding to the initial injection-production parameters; based on the prediction result, the initial injection-production parameters are optimized, and optimized injection-production parameters are obtained; and on the basis of the optimized injection-production parameters, displacement and energy complementation operation is conducted on the reservoir. According to the method, the shale oil recovery ratio under the complex structure characteristics of the shale reservoir can be improved.

The invention provides an efficient in-situ conversion synergistic hydrogen production method for shale oil with medium and low maturity, and belongs to the technical field of shale oil application. An upper-middle-lower three-well layout system is established, a hydrogen separation membrane layer is welded to a hydrogen production well, electric heating is matched with a conductive proppant to form an artificial fracture network, and a temperature field prediction model is adopted to dynamically regulate and control the heating power based on an artificial intelligence algorithm to maintain the optimal temperature; and an air slug and a steam slug are circularly injected to realize oxidation heat supply to promote organic matter cracking and gasification reaction with coke and other byproducts to produce hydrogen, an injection strategy is adjusted according to the ratio of the oxygen consumption rate to the coke gasification rate, and underground hydrogen separation is realized by virtue of a gravity differentiation effect and a hydrogen separation membrane. The method effectively solves the problem of low conversion rate in the in-situ conversion of the shale oil with medium and low maturity, and realizes clean and efficient underground hydrogen production.

The application discloses a kind of shale oil reservoir's attenuation-elastic-electricity combined modeling and parameter prediction method, belong to geophysical exploration and oil and gas reservoir evaluation technical field.First, obtain mineral components, pore structure and elastic-attenuation-electricity full-dimensional experimental data through core experiment, determine attenuation and resistivity as high sensitivity parameter after sensitivity analysis;Again, based on Hashin-Shtrikman boundary, differential equivalent medium theory, triple-pore medium wave propagation equation, construct the acoustic and electrical rock physics model of completely consistent micro-pore structure;Finally, establish longitudinal wave impedance-attenuation coefficient-resistivity three-dimensional joint rock physics chart, after multi-band correction, simultaneously quantitative prediction reservoir porosity, shale content and fracture porosity.The application breaks through the limitation of conventional acoustic-electricity combined model, significantly reduces the multi-solution of reservoir parameter prediction, and is suitable for fine evaluation of various shale oil tight reservoirs.

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 unconventional oil-gas exploration, and discloses a method and device for predicting the rock surface porosity of a shale oil reservoir, electronic equipment and a medium. In a method, a shale oil sample is processed to include at least two parallel samples; the acoustic emission system observes the longitudinal wave spectrum characteristics of the first parallel sample and extracts the waveform and signal of the longitudinal wave spectrum in the corresponding time window; converting the longitudinal wave from a time domain to a frequency domain based on discrete Fourier transform to obtain a rock sample longitudinal wave frequency spectrum characteristic curve; quantitatively representing the overall distribution range of the longitudinal wave frequency by using the longitudinal wave centroid frequency Fz of the rock sample based on the frequency distribution characteristics in the longitudinal wave frequency spectrum; and fitting the relationship between the longitudinal wave centroid frequency Fz of the rock sample and the corresponding rock surface porosity phi S, and constructing a surface porosity prediction model. According to the technical scheme, the shale oil reservoir pore structure evaluation method is enriched; the method has a good application effect on the shale oil reservoir, is high in practicability, universality and operability, and has good evaluation precision.

The utility model discloses a novel scattered and discharged gas collecting device of a shale oil refining device, which belongs to the technical field of oil shale oil refining waste gas emission and comprises a dry distillation furnace body, a combustion fan, a heat accumulating type heating furnace, a desulfurizing tower, a desulfurizing circulating pump and a chimney. According to the device disclosed by the utility model, the top of the water basin of the dry distillation furnace is blocked by the blocking coaming, so that waste gas generated in the water basin of the dry distillation furnace is guided into the condensation and gas collection box through the waste gas guide-out pipe to be collected, and steam in the waste gas is condensed by utilizing cooling water in the heat exchange copper pipe in the condensation and gas collection box; and the waste gas enters the heat accumulating type heating furnace through the combustion fan, so that the waste gas is directly combusted together with combustion gas in the heat accumulating type heating furnace, the combusted waste gas and flue gas enter the flue gas desulfurization system together for desulfurization and dust removal, and the flue gas is discharged after reaching the standard through a chimney.

This invention discloses an apparatus and experimental method for studying the surface characteristics of rocks after acidizing, belonging to the field of shale oil reservoir acidizing stimulation. The apparatus includes a reaction experiment module for fixing and positioning core samples; an image acquisition module for acquiring image data of the core samples; a 3D scanning module for acquiring stereoscopic images of the core samples; a temperature control module for heating the reaction vessel to provide a high-temperature environment for the acidizing reaction; a movable water injection module for precisely injecting experimental liquid onto the surface of the core samples; a temperature control and acid gas injection module for generating acid gas to acidize the core samples; and also includes a mechanical lifting module and an information calculation module. This invention can analyze different types of rocks and different types of gaseous acids, analyze the characteristics of rocks after acidizing under various combinations, thereby analyzing the mechanism and differences of gaseous acidizing, and providing theoretical support for the continued development of gaseous acidizing.

The invention discloses a shale deposition structure automatic identification method and device, and relates to the field of shale oil exploration and development, and the method comprises the steps: obtaining an image of a rock core and an electric imaging logging image corresponding to the rock core; processing and identifying a bedding boundary in the electrical imaging logging image; determining the number of stratification in the core image; determining a corresponding relation between the number of bedding boundaries in the electrical imaging logging image and the number of bedding in the image of the rock core; based on the corresponding relation and the bedding boundary of the electrical imaging logging image of the non-coring stratum, the actual bedding number of the non-coring stratum is determined, and then the sedimentary structure of the non-coring stratum is determined. After the corresponding relation of the bedding boundary between the actual image of the stratum core and the electric imaging logging image corresponding to the rock is determined, the sedimentary structure of the shale stratum can be automatically determined according to the electric imaging logging image, and the actual core does not need to be sampled and manual identification does not need to be carried out. And the automatic identification of the sedimentary structure of the shale stratum can be realized by adopting electric imaging logging.