1111 results about "Shale oil" patented technology

The invention relates to a shale oil borehole wall collapse pressure prediction method. The method comprises the following steps: acquiring components, structures and physicochemical properties of a shale oil reservoir; carrying out soaking-nuclear magnetism-sound wave-triaxial stress combined measurement experiments of different drilling fluid systems; constructing a shale oil reservoir rock heterogeneous water absorption and strength degradation equation; establishing ground stress and pore pressure profiles; converting the far-field crustal stress into a borehole and bedding coordinate system; calculating a well periphery stress field generated by water absorption of the surrounding rock; simulating and calculating the temperature field distribution of the rock and calculating a thermal stress value; the well periphery stress value under the force-chemical-thermal-bedding coupling effect is calculated in a superposition mode; constructing a well surrounding rock matrix and weak plane shear failure discrimination function and condition; constructing a shale oil reservoir collapse pressure numerical simulation iterative trial algorithm; determining a formation collapse pressure density control factor and a control mechanism; and the shale oil borehole wall collapse risk is reduced through optimization. According to the method, the shale oil borehole wall collapse pressure under the force-chemical-thermal-bedding coupling effect can be predicted more accurately.

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 provides a shale oil reservoir oil content evaluation method, which comprises the following steps: coring a shale sample, and carrying out anhydrous wire cutting processing to obtain a plunger sample and a crushed sample in an original state; respectively carrying out two-dimensional T1-T2 nuclear magnetic resonance testing on the plunger samples in the original state and the oil-water recovery state; according to the T1-T2 nuclear magnetic resonance spectrum, oil signal amplitudes of the plunger sample in an original state and an oil-water recovery state are identified, and a light hydrocarbon recovery coefficient is determined; the crushed sample is subjected to conventional pyrolysis and multi-temperature-order pyrolysis, conventional pyrolysis parameters and multi-temperature-order pyrolysis parameters are obtained, a first equation is established, and the first equation represents the relation between the original state oil content and the conventional pyrolysis parameters; according to the light hydrocarbon recovery coefficient and the first equation, a second equation is established, and the second equation represents the relation between the oil content in the oil-water recovery state and the conventional pyrolysis parameters; and evaluating the oil content of the shale oil reservoir in the oil-water recovery state according to the second equation and the measured conventional pyrolysis parameters.

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 discloses a shale oil high-pressure imbibition micro-fluidic experimental device and method, the shale oil high-pressure imbibition micro-fluidic experimental device comprises a nano-fluidic chip holder, the nano-fluidic chip holder is provided with a matrix type chip model, and the nano-fluidic chip holder is connected with a water bath box; the matrix type chip model is communicated with a pressure tracking pump and a vacuum pump, and the communicating position of the pressure tracking pump and the vacuum pump is communicated with an intermediate container and a power pump in sequence. And a full-period production dynamic process of fracturing fluid injection, well closing and well opening oil extraction under the shale reservoir condition is simulated by utilizing a nanofluidic technology. Meanwhile, a microfluidic experimental method is established by utilizing the experimental device, the flowing process and the distribution state of the oil-water two phases in the whole process of pressing, stuffiness and production are visually monitored and recorded in real time, and the imbibition replacement efficiency is quantitatively calculated by utilizing an image processing method.

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 relates to the technical field of petroleum drilling engineering, and discloses a method and system for maintaining shale oil borehole wall stability under hydration, and the method comprises the following steps: measuring mineral components, pore distribution and permeability anisotropy of shale in a shale oil experimental area to obtain shale related parameters; based on shale related parameters, performing a mechanical experiment on the shale sample, testing mechanical properties of a dry shale core under different confining pressures, and determining an upper and lower limit included angle of shale bedding surface damage; under the soaking of different drilling fluid systems, the strength data of the shale sample is corrected, and the shale strength criterion is perfected; determining a drilling fluid safety density window of the target layer based on actual measurement data of shale in the shale oil experimental area; based on the drilling fluid safety density window, well wall stability control under the engineering condition is carried out. According to the method, the well wall stability control technology is determined by determining the drilling fluid safety density window of the target layer, and technical support is provided for effectively maintaining the well wall stability in gulongshale oil drilling.

The invention provides a method for characterizing the heterogeneity of a millimeter-level shale oil and gas reservoir. The method mainly solves the problem that the reliability and accuracy of a reservoir evaluation result of an existing volume sampling method are low. The method is characterized by comprising the following steps that S1, shale millimeter-level mineral components are recognized and drilled; s2, based on the obtained powdery sample, oil-containing and non-oil-containing tests are carried out; determining occurrence pore size distribution to carry out reservoir characterization through comparison before and after pumping; s3, on the basis of the obtained powdery sample, carrying out oiliness characterization on different lamina / layered components; and S4, carrying out millimeter-level shale oil reservoir heterogeneity characterization on the basis of the reservoir property and oiliness results of the different strata / layered components. According to the method provided by the invention, the identification precision of the shale formation / stratified structure can be enhanced, millimeter-level fine representation of lithology of different formation / strata is realized, and favorable support is provided for shale oil enrichment mechanism, sweet spot prediction and the like.

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 discloses a CO2 geological storage coordinated shale oil and geothermal energy green development system and method. The system comprises a geothermal power station located on the ground, a ground cable, a CO2 injection device, a CO2 conveying pipeline, a CO2 / shale oil separation device, a shale oil conveying pipeline and a shale oil storage tank. Wherein the geothermal power station is connected with the CO2 injection device through a ground cable, the CO2 injection device is connected with the CO2 / shale oil separation device through a CO2 conveying pipeline, and the CO2 / shale oil separation device is connected with the shale oil storage tank through a shale oil conveying pipeline; through multiple utilization and innovative closed circulation of CO2, an efficient energy development system is built, the recovery ratio of shale oil is increased, geological storage of CO2 and geothermal energy development are achieved, energy consumption and carbon emission are reduced, and therefore the environmental pollution risk is effectively reduced, and unification of economic benefits and environmental benefits is achieved.

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 provides a nano imbibition displacement agent suitable for shale oil reservoirs and a preparation method thereof, and the nano imbibition displacement agent comprises the following raw materials in parts by weight: 30-50 parts of sulfonated graphene oxide, 10-15 parts of silane coupling agent modified nano silicon dioxide, 10-20 parts of water-soluble cellulose ether, 10-20 parts of fatty alcohol-polyoxyethylene ether, 5-8 parts of lower alcohol and 50-80 parts of water. Graphene oxide reacts with concentrated nitric acid to prepare acidified graphene oxide, then the acidified graphene oxide reacts with thionyl chloride to prepare acylating-chlorinated graphene oxide, and the acylating-chlorinated graphene oxide reacts with a sodium aminobenzene sulfonate derivative to prepare the graphene oxide. Electrostatic repulsive force is generated among graphene oxide particles through surface sulfonation treatment, the dispersing capacity among the particles is improved, agglomeration and flocculation among the particles are avoided, and the recovery efficiency is improved; sulfonated graphene oxide cooperates with a large-molecular-weight water-soluble cellulose ether surfactant, so that the temperature resistance and the salt resistance of the nano imbibition displacement agent can be remarkably improved.

The invention provides a medium-low maturity shale oil in-situ conversion mining pyrolysis kinetic model construction method, and belongs to the technical field of underground resource in-situ development, and the method comprises the following steps: firstly, preparing medium-low maturity shale samples composed of different organic matters, carrying out a pyrolysis experiment, and collecting and quantitatively analyzing pyrolysis products; based on original experimental data, a data augmentation model is constructed, an adversarial generative network model is established, and the generation effect of pyrolysis substance mass change data is optimized. And merging the generated substance mass change data with the experimental data to obtain merged data. Finally, on the basis of merged data, key parameters such as a reaction kinetic equation, reaction activation energy and a frequency factor are obtained through genetic algorithm optimization, a reliable pyrolysis kinetic model is provided for in-situ conversion mining of shale oil with medium and low maturity, and the problem that an existing model is difficult to accurately describe real kinetic behaviors of pyrolysis conversion of organic matter is solved.

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 provides a pump injection design method based on an effective support coefficient, and belongs to the technical field of oil and gas field development, and the method comprises the following steps: S1, based on a fluid-solid coupling theory, establishing a hydraulic fracture proppant migration equivalent model considering a bedding fracture; s2, with the optimal laying area as the target, the hydraulic fracture proppant migration equivalent model is used for simulating the proppant migration conditions under different parameter combinations, and an effective support coefficient is calculated; s3, based on the calculation result of the effective support coefficient, analyzing the change rule of the effective support coefficient under different parameters, and establishing a distribution pattern; and S4, on the basis of the distribution pattern, the pump injection process is optimized by utilizing the optimal range of the effective support coefficient. By means of the method, optimization of pumping key parameters such as displacement, sand ratio, sand adding particle size and particle size combination can be achieved, improvement of the overall flow conductivity of a shale oil reservoir fracturing fracture system is achieved, and therefore the fracturing effect is 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 discloses a carbon dioxide pressure flooding oil displacement and burying numerical simulation technical system, and relates to the field of CCUS numerical simulation, and the technical system comprises a geological data obtaining module which obtains the geological data of a target oil field site; an oil reservoir geologic model construction module constructs an oil reservoir geologic model in the CO2 pressure drive process of the deep shale oil reservoir according to the geological data; the pressure-drive oil displacement and burying mathematical model building module is used for building a deep shale oil reservoir CO2 pressure-drive oil displacement and burying mathematical model on the basis of the multiphase multicomponent seepage model and the mechanical deformation model in combination with the reservoir damage mechanical constitutive model; and the pressure-drive oil displacement and burying numerical simulation module is used for solving the seepage equation and the mechanical equation, carrying out iterative coupling solution on the fluid-solid two fields based on a definite stress decomposition algorithm, carrying out deep shale oil reservoir CO2 pressure-drive oil displacement and burying numerical simulation, and can better simulate the porosity and permeability change and the evolution of a damaged area in the CO2 pressure-drive oil displacement and burying process.

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 geological sweet spot prediction method based on multiple parameters, and belongs to the field of unconventional oil and gas development, and the method comprises the steps: obtaining well logging data of a known well, carrying out the preprocessing of the well logging data, and obtaining the preprocessed well logging data; constructing a deep neural network model, inputting the preprocessed logging data into the model for training, and obtaining a trained deep network; applying the trained deep network to a target well based on a transfer learning method to generate a transfer model; obtaining target well data, inputting the target well data into the migration model for prediction, and obtaining related parameters; constructing a geological dessert factor model by using related parameters; geological sweet spot factors are obtained based on the geological sweet spot factor model, and shale oil geological sweet spots are divided into different grades based on the values of the geological sweet spot factors. According to the method, dependence on a large amount of logging data is reduced, prediction precision is improved, and technical support is provided for effective development of unconventional oil and gas resources.

The invention belongs to the technical field of petroleum geological exploration, and particularly relates to a shale oil mobility and adsorbability prediction method and device based on machine learning. The method comprises the following steps: S1, acquiring a continental facies shale data set, wherein the continental facies shale data set comprises a shale mineralogy type, basic geochemical parameters, porosity and multi-temperature-order pyrolysis data; s2, the continental facies shale data set is input into a machine learning algorithm model, predicted shale oil mobility parameters and adsorbability parameters are output, and the machine learning algorithm model comprises RF-PSO and RF-DE. According to the method, the optimal OMC and OSC prediction models are screened out based on mineralogy, basic geochemistry and porosity data, so that the OMC and OSC of the shale can be accurately calculated.

The invention belongs to the technical field of petroleum geological exploration, and particularly relates to a method and device for predicting mobility and adsorbability of shale oil based on pore structure parameters. The method comprises the following steps that S1, mineralogy and basic geochemical parameters are used, Misforest iterative interpolation is adopted to supplement pore structure parameters, and pore structure parameter data are obtained; s2, the mineralogy type, the basic geochemical parameters, the porosity, the pore structure parameter data and the multi-temperature-order pyrolysis data form an original data set; and S3, inputting the original data set into the prediction model to obtain a prediction result of the mobility and the adsorbability of the shale oil. According to the method, in order to realize accurate prediction of the OMC and the OSC, pore structure parameters are supplemented by adopting a MissForest iterative interpolation method, and the OMC and the OSC of the shale are calculated based on a machine learning model.

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 discloses a shale oil reservoir nano agent displacement injection pressure prediction method and device, and belongs to the technical field of oil reservoir development. The injection pressure is predicted according to a starting pressure gradient method, the injection pressure is predicted according to a production quantity equivalent method formula and an improved starting pressure gradient experimental device, mutual verification is carried out, and an important basis is provided for shale oil continuous displacement development feasibility. According to the method, in shale oil and shale oil sustainable development mode optimization, the injection pressure serving as a key factor of displacement feasibility is predicted, oil reservoir energy is supplemented through nano-agent displacement, the oil displacement efficiency and the recovery efficiency of unconventional oil reservoirs such as shale oil and shale oil are improved, and if the predicted injection pressure can be achieved on site, the prediction of the injection pressure can be achieved on site. The method is of great significance to determination of economic recoverable reserves of unconventional oil reservoirs, determination of sweet spot areas, improvement of single well EUR and improvement of oil reservoir recovery efficiency.