861 results about "Shale oil" patented technology

The invention belongs to the technical field of shale oil horizontal well three-dimensional development, and particularly discloses a shale oil three-dimensional well network well location multi-objective optimization method which is used for solving the problem of how to achieve multi-objective collaborative optimization of the recovery ratio, the economic benefit and the inter-well interference degree. Comprising the following steps: (1) constructing a multi-field coupling dynamic oil drainage volume characterization model; (2) establishing an inter-well interference degree quantitative evaluation system based on the dynamic oil drainage volume characterization model; (3) realizing multi-source data fusion and high-precision prediction on the dynamic oil drainage volume, the recovery ratio, the net present value and the inter-well interference degree by combining a CNN-LSTM deep learning prediction model; and (4) implementing multi-objective optimization based on an NSGA-III multi-objective optimization algorithm, and comprehensively balancing the recovery ratio, the net present value and the inter-well interference degree on the premise of meeting engineering and economic constraints. Reliable technical support is provided for decision deployment of oil reservoir engineers under complex development conditions.

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 present invention belongs to the field of shale oil exploration. Provided are an evaluation method for the content of movable oil in shale, and a device and a storage medium. The evaluation method comprises the following steps: on the basis of pyrolysis test data of a sample to be tested at different aging times, determining a first recovery coefficient; on the basis of pyrolysis test data of said sample in different sample crushing environments, determining a second recovery coefficient; on the basis of pyrolysis test data of said sample at different crushing particle sizes, determining a third recovery coefficient; on the basis of pyrolysis test data of said sample at different pyrolysis temperatures, determining a fourth recovery coefficient; determining the product of the first recovery coefficient, the second recovery coefficient, the third recovery coefficient and the fourth recovery coefficient to be a light hydrocarbon recovery coefficient; and on the basis of the light hydrocarbon recovery coefficient, evaluating the content of movable oil in shale. The method provided in the present invention offers guidance for quantitatively evaluating the oil content of shale, and a finally determined free oil content result has a relatively small difference from the actual situation.

The invention belongs to the technical field of oil and gas field development engineering, and particularly relates to an experimental method and device for evaluating energy-increasing and permeation-increasing effects of thermal-assisted carbon dioxide huff and puff after shale oil reservoir fracturing. The experimental method comprises the following steps: S1, preparing a shale core sample: selecting two shale cores from the same geological reservoir, taking one as a fractured core and taking the other as a matrix core; s2, carrying out heat-assisted CO2 huff and puff simulation experiment test on the matrix rock core sample; carrying out a heat-assisted CO2 huff and puff simulation experiment test on the fractured rock core sample; and evaluating the energy increasing efficiency of the heat-assisted CO2 huff and puff and the permeation increasing effect on the artificial fracture. According to the experimental method, the limitation of evaluating the energy-increasing and permeability-increasing effect of the heat-assisted supercritical CO2 on the shale reservoir in the prior art is overcome, and the energy-increasing and permeability-increasing effect of the CO2 on the shale reservoir in the heat-assisted extraction process can be comprehensively and systematically evaluated.

The invention relates to the field of oil well opening and killing fluid production, in particular to a solid-free well killing fluid for shale oil reservoir and a preparation method of the solid-free well killing fluid. The solid-free well killing fluid for the shale oil reservoir comprises the following raw materials in parts by mass: 50-70 parts of water, 10-30 parts of a density regulator, 3-6 parts of a copolymer tackifier, 1-3 parts of a dispersant, 3-7 parts of a filtrate reducer and 2-4 parts of a corrosion inhibitor. The copolymer tackifier is obtained by initiating copolymerization by taking acrylamide, a quaternary ammonium salt-containing monomer, an unsaturated silane coupling agent and polyethylene glycol diacrylamide as monomer free radicals, and the dispersing agent comprises gas-phase nano silicon dioxide and a fluorine-containing surfactant. Through reasonable compatibility of all the components in the formula, especially the copolymer tackifier, the effect that one agent has multiple functions is achieved, and meanwhile the high temperature resistance, the corrosion inhibition performance and the clay stability of the well killing fluid are improved.

The invention belongs to the technical field of shale oil horizontal well three-dimensional development, and particularly discloses a three-dimensional well pattern interference evaluation method based on dynamic oil drainage volume. The method is used for solving the problem of how to establish an accurate inter-well interference evaluation method under the conditions of high reservoir heterogeneity and complex inter-well mutual influence. Comprising the following steps: (1) constructing a multi-field coupling dynamic oil drainage volume characterization model based on reservoir pressure field evolution, fluid seepage characteristics and fracture network response, and realizing quantitative and dynamic evaluation of shale oil reservoir inter-well interference; and (2) establishing an inter-well interference degree quantitative evaluation system based on the multi-field coupling dynamic oil drainage volume characterization model, and measuring the space overlapping degree and the pressure field difference of the oil drainage volume of each well by using the inter-well interference degree quantitative evaluation system so as to provide a quantitative basis for well pattern layout and interference control. According to the method, the dynamic seepage characteristics of the shale oil reservoir and the inter-well competition relationship are tightly coupled, and the interference identification precision is improved.

The invention discloses a shale oil carbon dioxide flooding surfactant and a preparation method thereof, and belongs to the technical field of surfactants. The rock oil carbon dioxide flooding surfactant is prepared from the following components in parts by weight: 100 parts of water, 40 to 60 parts of fluorine-containing copolymer, 15 to 25 parts of sodium dodecyl benzene sulfonate, 10 to 20 parts of polyoxyethylene ether surfactant containing siloxy and 5 to 10 parts of nanoparticles. The fluorine-containing copolymer, the sodium dodecyl benzene sulfonate, the siloxy-containing polyoxyethylene ether surfactant and the nanoparticles are compounded, so that on one hand, the surfactant has relatively high salt tolerance and temperature tolerance so as to adapt to the environment of a shale oil reservoir; on the other hand, the surface activity is synergistically improved, the interfacial tension is reduced, the rock surface wettability is changed, and the system stability is enhanced, so that higher recovery efficiency is realized.

Provided is a method for determining huff and puff fluid volumes in multi-scale spaces of shale oil reservoirs, including the following steps: rock sample pretreatment; porosity stress sensitivity testing; high pressure hg injection testing and nuclear magnetic resonance testing benchmarking; online nuclear magnetic resonance testing; data processing and analysis. Firstly, a changing law of multi-scale spaces of shale oil reservoirs with an effective stress is characterized through a pore stress sensitivity measurement and online nuclear magnetic resonance measurement combined experiment, and then the huff and puff fluid volumes of multi-scale spaces of shale oil reservoirs under a condition of a certain stimulated reservoir volume are calculated. A usage amount of a fracturing fluid for a fracturing horizontal well in the shale oil reservoir is determined from the perspective of giving full play to the imbibition replacement role of micro-nano pores.

The invention provides a shale oil gathering and transportation pipeline leakage risk analysis and safety prevention and control method which comprises the following steps: establishing an FTA model to analyze a pipeline leakage accident of a shale oil gathering and transportation pipeline, and defining pipeline erosion as a key risk factor causing the pipeline leakage accident; performing quantitative risk analysis on pipeline leakage by using a Bayesian network, and calculating the probability of pipeline leakage; establishing a pipeline erosion model in Fluent software, and simulating reasons of pipeline leakage risks; establishing a pipeline leakage diffusion model of the shale oil gathering and transportation pipeline in FLACS software; performing grid division on the pipeline leakage diffusion model; setting pipeline leakage output gas components and component proportions in the pipeline leakage diffusion model; setting a pipeline leakage aperture and leakage pressure in the pipeline leakage diffusion model; setting factory environment parameters; analyzing a shale oil and gas leakage diffusion rule by using FLACS software; and formulating pipeline leakage risk safety prevention and control measures based on quantitative analysis of influence factors before and after pipeline leakage.

The invention belongs to the technical field of shale oil development and research, and discloses a shale oil mobility evaluation method based on a two-dimensional nuclear magnetic resonance experiment, which comprises the following steps: dividing an oil-containing shale sample harvested by a closed coring well into three parts which are respectively marked as a sample 1, a sample 2 and a sample 3; carrying out a TOC determination experiment on the sample 1 to obtain the TOC content of the sample; carrying out a step-by-step pyrolysis experiment on the sample 2 to obtain the contents of the sample S1-1 and the sample S2-2; calculating to obtain a shale oil mobility evaluation factor which is marked as FMO; carrying out a two-dimensional nuclear magnetic resonance experiment on the sample 3 before and after centrifugation to obtain the movable oil content of the sample before and after centrifugation, calculating to obtain the percentage of two-nuclear magnetic resonance movable oil, and recording the percentage as MO2D-NMR; and shale oil mobility evaluation is realized through analysis of the relationship between MO2D-NMR and FMO. According to the method provided by the invention, nondestructive testing of the sample can be realized in the two-dimensional nuclear magnetic resonance experiment process, the loss of light hydrocarbon can be reduced to the greatest extent, and the mobility evaluation precision of shale oil is effectively improved.

The invention relates to an economic evaluation method and system for in-situ conversion of medium and low-cooked shale, and belongs to the technical field of shale oil development. Comprising the following steps: 1) establishing a medium-low mature shale in-situ conversion geological model; 2) constructing a three-dimensional heat conduction equation, setting a definite solution condition, and solving the three-dimensional heat conduction equation in combination with the thermophysical parameters to obtain a temperature field on each time-space node in the medium-low mature shale in-situ conversion geological model; the method comprises the steps of (1) obtaining a dynamic hydrocarbon generation process, (2) obtaining a hydrocarbon generation kinetic parameter, (3) obtaining a total energy output, (5) obtaining a total energy input in a heating process, and (6) calculating an energy consumption ratio (ER), and carrying out economic feasibility evaluation of a shale in-situ conversion technology. The method can calculate a dynamic hydrocarbon generation process at any time and position in a shale bed in real time, and obviously improves the prediction precision of the hydrocarbon generation amount.

The invention provides a shale oil reservoir well factory horizontal well fracturing parameter optimization method, and relates to the technical field of horizontal well fracturing parameter optimization, and the method specifically comprises the steps: obtaining a plurality of groups of horizontal well historical fracturing parameters, and obtaining an oil and gas production value corresponding to each group of historical fracturing parameters, performing one-to-one mapping on the historical fracturing parameters and the corresponding oil and gas yield values to generate a sample data set; and constructing an oil and gas yield prediction model, inputting the initial optimized fracturing parameter combination into the oil and gas yield prediction model to obtain an oil and gas yield prediction value, constructing a fitness function according to the oil and gas yield prediction value, and obtaining an optimal fracturing parameter combination through a genetic algorithm. Parameters in the optimal fracturing parameter combination are corrected according to the environment correction factors, specific values of the fracturing parameters are obtained, the horizontal well fracturing parameters are optimized according to the specific values of the fracturing parameters, the trial and error cost in the horizontal well fracturing process is reduced, and the resource utilization rate is increased.

The invention discloses a shale oil reservoir flow simulation method based on a limited fluid state equation, which belongs to the technical field of oil-gas field development and comprises the following steps of: establishing a limited fluid generalized state equation by considering a nano confinement effect; oil / gas phase balance is calculated based on the limited fluid generalized state equation; oil / gas two-phase physical property parameters are calculated; and establishing a multi-component multi-phase flow shale oil flow simulation formula. By adopting the method, the P-R state equation is corrected based on the nano confinement effect, phase equilibrium calculation is performed based on the corrected P-R state equation, the oil / gas two-phase physical property parameters are calculated, the parameters are substituted into the shale oil reservoir flow equation, the flow characteristics of the shale oil reservoir are defined, and the simulation efficiency is improved.

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 provides a shale oil reservoir fracturing process monitoring method, device and system, and belongs to the field of shale oil development. The method comprises the steps that original stratum physical property parameters and stress parameters of a target reservoir are obtained, and an initial reservoir model is constructed through numerical simulation; performing CT scanning and core pore three-dimensional reconstruction on the core obtained by the first coring to obtain an initial core pore network model; applying the monitored fracturing construction process to the initial reservoir model to obtain a dynamic construction reservoir model; after fracturing construction is finished, CT scanning and three-dimensional reconstruction of core pores are carried out on the core obtained through second-time coring, and a fractured core pore network model is obtained; through the model, the process of fracturing transformation on the target reservoir is visually displayed. And the shale reservoir fracturing crack propagation characteristic rule is obtained on the spatial scale, the influence of the production process on the fracturing crack is monitored for a long time on the time scale, and the production dynamic rule is predicted more accurately.

The invention discloses a method for evaluating the crude oil utilization rate during shale oil in-situ heating modification exploitation, and is applied to the field of oil development. The method comprises the following steps: (1) constructing a three-dimensional grid model of shale oil reservoirs between two horizontal wells, and determining parameters such as initial temperature, initial fluid pressure, initial porosity, initial oil saturation, initial gas saturation, initial water saturation and initial dissolved gas volume of three-dimensional grid units of each reservoir; (2) determining the pressure of each reservoir three-dimensional grid unit when the fluid pressure is balanced according to the shale oil layer section bottom hole pressure and the reservoir displacement pressure gradient; (3) according to the characteristics of a temperature field, a pressure field and the like of the in-situ heating shale oil reservoir, obtaining three-dimensional grid unit temperature and instantaneous fluid pressure parameters of each reservoir, and determining porosity and fluid saturation at each time point; and (4) according to the instantaneous fluid pressure and the balanced fluid pressure of the three-dimensional grid unit of each reservoir, determining the oil, gas and water production quantity and the production rate of the grid unit of each reservoir in combination with the oil, gas and water saturation.

The invention provides a shale oil pyrolysis adsorption oil and free oil correction method based on a nuclear magnetic experiment, and belongs to the field of exploration and development of unconventional oil and gas fields. According to the method, on the basis of a shale rock physical experiment and a shale nuclear magnetic resonance experiment, the occurrence space and content of adsorbed oil are determined by using multi-state nuclear magnetic resonance experiments such as original sample, saturated oil, washing oil and different temperatures, so that a nuclear magnetic adsorbed oil model is constructed, and the content of the adsorbed oil is determined by further combining a different-temperature-order parallel crushed sample lithologic pyrolysis experiment-nuclear magnetic combined measurement experiment. The content of the free oil and the content of the adsorbed oil are calculated through the two-dimensional nuclear magnetism T1-T2 spectrum semaphore, the content of the free oil and the content of the adsorbed oil are compared and analyzed, the difference between the nuclear magnetism adsorbed oil and the pyrolysis adsorbed oil is matched with a free hydrocarbon curve to achieve adsorbed oil correction, and the free oil and the adsorbed oil are obtained.

The invention discloses a complex lithofacies shale oil reservoir multi-scale productivity prediction method and system. The method comprises the following steps: establishing a complex lithofacies shale oil reservoir model with a multi-scale aperture structure; representing the complex lithofacies shale oil reservoir model by adopting a dual-medium model and an embedded discrete fracture model; establishing a complex lithofacies shale oil reservoir seepage model and a numerical solution algorithm considering the starting pressure gradient and the stress sensitive effect, and forming a complex lithofacies shale multi-scale numerical simulation method; the complex lithofacies shale multi-scale numerical simulation method is adopted to carry out complex lithofacies shale oil reservoir seepage numerical simulation, and the shale oil reservoir oil and gas yield is obtained through calculation. According to the method, the seepage simulation and productivity calculation of the complex lithofacies shale oil reservoir can be quickly and accurately realized by establishing the seepage numerical simulation method of the complex lithofacies shale oil reservoir considering the multi-scale aperture characteristics, the starting pressure gradient and the stress sensitive effect.

The invention provides a shale oil well pressure recovery well test interpretation method and device and electronic equipment.The method comprises the steps that effective well shut-in pressure test data and well entering time of a pressure gauge are obtained, the effective well shut-in pressure test data are well bottom pressure data after well shut-in and after the pressure gauge is lowered to the target test depth away from a well opening, and the well entering time is obtained; the well entering time is the time required for lowering the pressure gauge to a target test depth from a well mouth after the well is closed; obtaining well shut-in starting time and a pressure gradient in a well entering process of the pressure gauge; according to the pressure gradient, fluid pressure data at the well shut-in starting time and the target test depth from the well mouth are calculated to serve as supplementary pressure data; according to the effective shut-in pressure test data, the well entering time and the supplementary pressure data, a complete pressure recovery well test curve is determined; and on the basis of the complete pressure recovery well test curve, pressure recovery well test interpretation is carried out. According to the method, the problem of data missing in the early stage of well shut-in testing can be solved, the integrity of a pressure recovery well testing curve is guaranteed, and the accuracy of pressure recovery well testing interpretation is improved.

The invention belongs to the technical field of oil well paraffin removal and prevention, and relates to a paraffin removal and prevention agent for a shale oil shaft and a preparation method thereof. The paraffin remover and inhibitor for the shale oil wellbore comprises the following raw materials in percentage by mass: 40-55% of an oily solvent, 1-3% of a cosolvent, 1-2% of imidazole bis (trifluoromethanesulfonyl) imide salt, 10-20% of a wax crystal modifier, 3-5% of an emulsifier, 1-2% of an alkaline regulator and 25-35% of water, wherein the sum of the mass percentages of the raw materials is 100%. The wax crystal modifier is prepared by copolymerizing (methyl) acrylic acid C12-C16 ester, (methyl) acrylic acid C1-C3 ester and (methyl) acryloyl chloride and then reacting with C20-C30 alkyl alcohol. The wax crystal modifier provided by the invention has long-medium-short branched chains, and interacts with the imidazole bis (trifluoromethanesulfonimide) salt capable of improving the paraffin removal effect and low-temperature fluidity, so that the efficient paraffin removal and inhibition effect is realized, and the better paraffin removal and inhibition effect can still be kept at low temperature.

The invention relates to the field of oil and gas exploration and development, and discloses a shale oil chromatography fingerprint identification model, a model construction method and an identification method, and the method comprises the following steps: detecting a plurality of shale oil saturated hydrocarbon samples by using a gas chromatography-mass spectrometry technology to obtain initial detection data; extracting retention time and chromatographic response data from the initial detection data; based on the retention time and the chromatographic response data corresponding to each shale oil saturated hydrocarbon sample, obtaining each initial chromatographic fingerprint time sequence signal, and optimizing each initial chromatographic fingerprint time sequence signal to obtain each target chromatographic fingerprint time sequence signal; and based on a K-Shape algorithm and each target chromatographic fingerprint time sequence signal, constructing a shale oil chromatographic fingerprint identification model. The shale oil chromatographic fingerprint identification model is constructed based on a K-Shape algorithm with a better clustering effect, so that the shale oil saturated hydrocarbon chromatographic fingerprint can be accurately identified by using the shale oil chromatographic fingerprint identification model.

The invention belongs to the technical field of petroleum and natural gas development, and particularly provides a shale oil ultra-long horizontal well volume fracturing fracture pressure reduction method which comprises the following steps: taking rock samples underground at different positions of a horizontal section of an ultra-long horizontal well, and testing initial physical property parameters, mineral component contents and rock mechanical parameters of the rock samples; a rock sample and liquid CO2 soaking experiment is carried out under the reservoir temperature and pressure condition, rock mechanical parameters of the rock sample after the experiment are tested, rock damage factors are defined, the fracture reduction capacity is evaluated according to the rock damage factors, and a fracturing section is selected; and establishing a shale oil reservoir geologic model based on the reservoir physical property parameters of the selected fracturing section, performing CO2 injection productivity numerical simulation, and determining the optimal CO2 injection rate. The problems that an existing method for reducing the fracture pressure of the shale oil ultra-long horizontal well is small in application object range, large in construction risk, low in operation efficiency and high in cost are solved, the CO2 injection amount is optimized, the dual effects of reducing the fracture pressure and increasing the yield through CO2 are achieved, and the construction risk and the operation cost are reduced.

The invention belongs to the field of shale oil exploration evaluation, and discloses an LgR method logging source rock evaluation model fitting parameter prediction method and a shale type shale oil resource quantity calculation method and system. The prediction method comprises the following steps: screening mudstone data in a logging curve; determining a plurality of combinations of possible values of fitting parameters K, a and b, and calculating corresponding mudstone baseline parameters; aiming at different combinations of possible values of fitting parameters K, a and b and corresponding mudstone baseline parameters, according to the screened mudstone data, utilizing an LgR method well logging source rock evaluation model to respectively calculate and obtain organic matter abundance fitting values; and based on the organic matter abundance fitting value and the organic matter abundance measured value, evaluating a fitting effect, and screening out a parameter value combination with the optimal fitting effect as a predicted fitting parameter of the well with the organic matter abundance measured value in the work area. According to the method, all possible parameter value combinations can be comprehensively screened, the influence of subjective factors is eliminated, and undetermined parameters are objectively and accurately predicted.

The invention discloses a shale oil carbon dioxide huff and puff graded pressure drop mining experiment method. The method comprises the following steps that S1, the crude oil recovery degrees under different huff and puff experiment requirements are obtained through experiments; the method is suitable for the technical field of oil and gas field development, the CO2 utilization rate and the recovery percentage of each stage in the shale oil carbon dioxide huff and puff graded pressure drop exploitation process can be accurately measured, a database is established in combination with influence factors of different injection conditions, and the reliability of the shale oil carbon dioxide huff and puff graded pressure drop exploitation process is improved. And on the basis of experimental results, weight analysis of shale oil carbon dioxide huff and puff graded pressure drop mining is carried out on each factor, so that main influence factors of shale oil carbon dioxide huff and puff graded pressure drop mining can be screened out, which is of great significance to subsequent shale oil carbon dioxide huff and puff mining adjustment.

The invention relates to the technical field of shale oil phase state evaluation, in particular to a nanometer space shale oil in-situ phase state and shale oil reservoir type intelligent evaluation method which comprises the steps that a pressure maintaining rock core is obtained from a shale target layer series; the method comprises the following steps: taking out a blocky frozen-state pressure-maintaining rock core, quickly crushing, putting into a pyrolysis device sample boat, feeding into a pyrolysis furnace, acquiring pyrolysis data at each acquisition moment in a pyrolysis process, determining a comparison interval coefficient at the current moment, and constructing an accumulated comparison coefficient for adjusting control parameters so as to adjust the pyrolysis temperature; the method comprises the following steps: preparing a pressure-maintaining rock core, rapidly heating a heat release sample, separating the sample into various monomeric compounds to obtain a pressure-maintaining rock core pyrolysis gas chromatography spectrogram, calculating the content of each component, using simulation software and combining thermodynamic parameters of oil and gas components to obtain a shale oil P-T phase diagram, and further determining a nano space shale oil in-situ phase state and a shale oil reservoir type. The accuracy, efficiency and convenience of shale oil phase state and oil reservoir type evaluation are improved.

The invention discloses a method for segmenting different strata series of stratified shale and identifying oiliness, and belongs to the field of oil-gas exploration. The invention discloses a strata division method based on XRF (X-Ray Fluorescence) mineral scanning and single polarization-fluorescence-laser confocal optical lens combined observation, which realizes accurate identification and segmentation of micron-sized strata boundaries of a layered rock core sample from different scales, and performs group component extraction on segmented independent strata. And carrying out chromatography-mass spectrometry analysis and FT-ICR MS analysis on the extracted saturated, aromatic, non-aromatic, leached and other family components. The TSF spectrum, light and heavy components, biomarker compounds, non-hydrocarbon compounds and other data obtained through the experiments are comprehensively analyzed, layering scale oiliness difference quantification and oil source comparison are achieved, and the shale oil micro-migration phenomenon is determined. The influence of the heterogeneity of the layered rock core sample on a result obtained by a traditional analysis method is overcome. According to the technology, direct evidences are provided for accurate prediction of shale oil desserts, exploration risks are reduced, and economic benefits are improved.

The invention provides a shale oil horizontal well inter-well interference intensity quantification method based on a physical model. The shale oil horizontal well inter-well interference intensity quantification method comprises the steps that 1, a large-scale three-shaft physical model rock core and a standard-size rock core are prepared; 2, testing the initial permeability of the standard-size rock core; 3, adjusting experimental parameters, and carrying out multi-well three-dimensional fracturing physical model experiments in groups; 4, drilling a fractured physical model standard diameter rock core, and cutting a sample and manufacturing a standard sample; 5, testing the permeability of the core with the standard size after fracturing; step 6, forming a chart curve by taking the coring position and the permeability as variables, measuring the permeability after the pressure is measured, and analyzing the interference intensity; and 7, drawing a field scale inter-well interference area chart curve, analyzing a variable relationship and perfecting a fitting formula. According to the shale oil horizontal well inter-well interference intensity quantification method based on the physical model, shale oil horizontal well three-dimensional fracturing inter-well interference intensity quantification can be achieved, and the method has important significance on reasonable design and optimization of well pattern and well spacing.

Provided in the embodiments of the present description is a method for determining a reasonable soaking time for a shale oil / gas well. The determination method uses a shale oil / gas well reasonable soaking time testing apparatus to carry out testing experiments, and comprises: selecting a rock core sample; measuring to obtain the porosity of the rock core sample; simulating the in-reservoir state of a first rock core sample; injecting methane and reaching the reservoir pore pressure; injecting a simulated fracturing fluid into a rock core clamping holder; measuring the resistivity change curve of the first rock core sample; measuring and obtaining the pressure attenuation half-life of a first pressure sensor until an inflection point appears on the resistivity change curve of the first rock core sample; obtaining the experiment durations under which the first rock core sample and a second rock core sample have the shortest pressure attenuation half-life; obtaining the time points at which the first rock core sample and the second rock core sample exhibit maximum rock core nuclear magnetic signal change amplitude; after sorting, obtaining a soaking time at the rock core scale; and obtaining a soaking time for the shale oil / gas well.

The invention discloses a shale oil reservoir permeability calculation method, device and equipment based on combined driving, and relates to the field of oil-gas exploration, the method comprises the following steps: constructing a permeability physical model, and constructing a data set by using logging data and core experiment permeability data; screening target logging data from the logging data in the data set; calculating according to the permeability physical model and nuclear magnetic logging data in the logging data to obtain fitting permeability; taking the target logging data and the fitting permeability as sample data, and constructing label data by using core experiment permeability data to form a training sample set; according to the training sample set, carrying out model training by adopting a random forest algorithm to obtain a permeability intelligent model; and inputting the target logging data corresponding to the shale oil reservoir to be measured and the fitting permeability into the permeability intelligent model, and predicting the permeability of the shale oil reservoir to be measured. According to the method, the interpretation precision of the permeability of the shale oil reservoir is greatly improved.

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.