83 results about "Tight oil" patented technology

The invention discloses a tight gas reservoir rock compressibility evaluation method and system, computer equipment and a medium, and relates to the technical field of petroleum and natural gas development. The method comprises the following steps: testing to obtain rock sample parameters of a target reservoir rock sample; on the basis of the rock sample parameters of the target reservoir rock sample, the rock natural fracture crushing degree is obtained through calculation; based on the rock sample parameters of the target reservoir rock sample, obtaining the potential of reservoir transformation to form a fracture network; and according to the natural fracture crushing degree of the rock and the potential of forming a fracture network through reservoir transformation, calculating to obtain a rock compressibility index which is used for evaluating the rock compressibility. The rock compressibility is dynamically evaluated by comprehensively considering the natural fracture crushing degree and whether the potential of forming a complex fracture network through reservoir transformation can obtain high productivity or not, and technical support is provided for tight oil and gas exploration and development.

The invention discloses a tight oil and gas reservoir horizontal well volume fracturing fracture network wave and volume prediction method, which comprises the following steps of: based on geological engineering parameters of a fractured horizontal well and microseism monitoring fracture volume data, calculating weight factors of each geological and engineering parameter by establishing a multi-factor evaluation model; aiming at a to-be-predicted fracturing section, combining the solved weight factor and the geological parameters of the perforation positions of the fracturing clusters in the fracturing section, and calculating a fracturing crack-making efficiency coefficient representing the distribution uniformity of fracturing fluid; multiplying the original micro-seismic monitoring fracture volume of the fractured section by the calculated fracture forming efficiency coefficient to obtain a corrected effective fracture network wave and volume; according to the method, the fracture forming efficiency coefficient is introduced to correct the original microseismic monitoring volume, the problem that prediction results of an existing method are generally large is solved, accurate quantitative prediction of the effective fracture network waves and the volume is achieved, and a scientific basis is provided for fracturing effect evaluation and scheme optimization.

The invention discloses an injection and production system and method for improving the CO2 huff and puff effect of a shale and compact oil and gas reservoir based on high-pressure pressure-maintaining soaking, and belongs to the technical field of shale and compact oil and gas reservoir development. The constant temperature device comprises a CO2 intermediate container, an experimental oil intermediate container and a high-temperature and high-pressure reaction kettle which are arranged in a constant temperature box; the CO2 gas cylinder is respectively communicated with the CO2 intermediate container, the experimental oil intermediate container and the high-temperature and high-pressure reaction kettle; and both the CO2 intermediate container and the experimental oil intermediate container are communicated with the constant pressure pump. According to the method, the reservoir energy can be effectively maintained by adopting a high-pressure pressure-maintaining soaking technology, the problem of poor recovery efficiency caused by pressure drop in the CO2 huff and puff process can be effectively solved, the oil displacement effect of CO2 in the shale reservoir is remarkably improved, and the recovery degree of each turn can be remarkably improved.

The invention relates to the technical field of oil-gas field development, and particularly discloses a fracturing flow-back fluid oil-water separation method based on a centrifugal down-flow same-term capture technology. Comprising the following steps: S1, pretreatment: filtering the fracturing flow-back fluid to remove large-particle-size suspended solids contained in the fracturing flow-back fluid so as to obtain a pretreatment fluid; s2, demulsification: adding a demulsifier into the pretreatment solution obtained in S1, and stirring and mixing to obtain a demulsification solution; s3, air flotation separation; s4, performing centrifugal downstream same-term capturing; s5, collecting an oil phase; s6, water phase purification; and S7, recovering and circulating the medicament. The oil-water separation method for the fracturing flow-back fluid can be used for treating the fracturing flow-back fluid with the high emulsification degree generated in the exploitation process of unconventional oil and gas resources such as shale gas and tight oil and gas, and has the advantages of being high in separation efficiency, low in oil content of effluent, high in system adaptability, controllable in comprehensive operation cost and environmentally friendly.

The embodiment of the invention provides a carbon dioxide huff and puff experimental device and method under a tight oil reservoir, and relates to the technical field of oil and gas development. The experimental device comprises a sample chamber which is provided with an accommodating cavity; the injection structure is used for injecting water and oil into the containing cavity so that the rock core sample can be filled with the water and the oil, and the injection structure is used for injecting carbon dioxide into the containing cavity so that the carbon dioxide can enter the rock core sample and part of the water and the oil can be extracted; the pressure control system is used for applying pressure to the rock core sample; the heating device is used for heating the rock core sample; the pore detection device is used for detecting the pressure in the sample chamber; the resistance meter is used for detecting resistance parameters of water and oil in the rock core sample. Compared with the prior art, the amount of water and oil contained in the rock core sample can be detected and calculated through the pore detection device and the resistance meter, precision is high, errors are small, injection parameters of carbon dioxide can be conveniently adjusted according to the content of water and oil in the rock core sample, and the experiment efficiency is improved.

The application discloses a kind of tight oil fracturing horizontal well differentiation energy storage methods, system and storage medium constrained by full-cycle stratum energy level evolution.The method comprises: constructing flow field prediction base based on local grid encryption and micro-osmotic equation coupling, embedding low-speed non-Darcy seepage control osmosis oil production velocity equation and dynamic zoning evolution algorithm of relative permeability curve;Based on streamline simulation module, carry out full-time domain flow field evolution tracking, accurately locate the decoupling breakpoint of injection-production space;Based on multidimensional orthogonal matrix, nonlinear collaborative optimization is carried out on single round extraction parameter, and the optimal process parameter combination of single round is locked by variance analysis;Cross energy level evolution scanning and establishing full life cycle differentiation energy storage chart.The application solves the problems of micro-mechanism distortion, multi-parameter collaborative optimization inefficiency and strategy and energy level evolution mismatch, and significantly improves the recovery efficiency of tight oil reservoir.

The invention discloses a tight oil reservoir depletion type development wave and region evaluation device and method. The device comprises a tight oil reservoir simulation system, a horizontal well system, a pressure monitoring system and a production system, the tight oil reservoir simulation system comprises a reservoir simulation device and a fluid injection device which are connected. The reservoir simulation device can be filled with sand grains in a layered manner so as to simulate a target tight oil reservoir; the fluid injection device is used for injecting simulated formation water and simulated formation oil; the horizontal well system comprises a plurality of horizontal wells; each liquid production pipe is connected with a corresponding horizontal well outlet and is connected with a produced liquid metering device; the pressure monitoring system comprises a signal processor, a pressure sensor and a plurality of pressure probes; and the plurality of pressure probes are arranged in the reservoir simulation device. According to the device, the distribution rule of the sweep area can be identified according to the pressure change, the recovery ratio corresponding to the sweep area can be obtained, and therefore sweep area evaluation is achieved through physical simulation, and production guidance is provided for depletion type development of tight oil reservoirs.

This invention relates to the field of oil and gas geological exploration technology, and particularly to a method and apparatus for predicting thin interbedded mud-sand reservoirs based on pre-stack waveform indication inversion. The method includes: processing pre-stack CRP gathers to obtain corner gather data; performing AVO attribute analysis on the corner gathers; stacking them at different angles to generate an offset stacked data volume; obtaining shear wave curves for all wells in the work area based on logging curves and geological parameters; determining rock elastic parameters that reflect reservoir and fluid characteristics based on these curves; establishing a rock physical quantity scale and selecting sensitive parameters that can distinguish between sandstone and mudstone and fluids; setting key inversion parameters; performing inversion on the offset stacked data volume based on the sensitive parameters and key inversion parameters; and predicting thin interbedded mud-sand reservoirs based on the obtained inversion results. This invention achieves high-precision inversion results, effectively improving the accurate prediction of thin interbedded layers, meeting the well accuracy requirements for development, and providing support for the efficient development of tight oil and gas.

The invention discloses fracturing fluid and a shale oil exploitation method, and belongs to the technical field of oil and gas exploitation. The fracturing fluid is prepared from raw materials in percentage by weight as follows: 0.8%-1.5% of a first surfactant, 0.5%-1.2% of a second surfactant, 1%-2% of an aid, 10%-25% of a film-coated proppant, 0.01%-0.08% of a gel breaker and the balance of water, the first surfactant is organic acid modified hexadecyl trimethyl ammonium bromide; the second surfactant is alkylphenol polyoxyethylene ether and / or fatty alcohol-polyoxyethylene ether; a film covering material of the film covering proppant is a graphene nanosheet. The fracturing fluid and the shale oil exploitation method can provide a high flow guide channel for oil and gas seepage, obviously improve the recovery efficiency, and are especially suitable for fracturing transformation of unconventional compact oil and gas reservoirs.

This invention proposes a method and apparatus for predicting fracture pressure and production classification in tight oil reservoirs, relating to the field of reservoir exploration technology. The method includes: acquiring tight oil horizontal well data; extracting factors affecting fracture pressure from the tight oil horizontal well data, inputting these factors into a tight oil horizontal well fracture pressure prediction model to obtain the fracture pressure; extracting factors affecting tight oil production from the tight oil horizontal well data, inputting these factors into a tight oil production prediction model to obtain the tight oil production; classifying the tight oil horizontal wells according to the tight oil production to obtain tight oil production classification results; and generating a tight oil horizontal well development strategy based on the tight oil horizontal well fracture pressure and tight oil production classification results.

The invention belongs to the field of petroleum gas field development, and discloses a tight oil horizontal well productivity influence factor and measure well selection quantitative evaluation method, which is based on a productivity main control factor evaluation model of multiple mathematical methods: integrating dynamic and static data in the aspects of geology, development, engineering and the like, and applying mathematical methods such as partial correlation analysis and a grey correlation method to evaluate the productivity main control factor evaluation model. Calculating the correlation coefficient of the main control factors of the tight oil reservoir horizontal well, calculating the geological, engineering and yield scores according to the evaluation result of the productivity main control factors and the correlation coefficient in combination with the actual oil testing and production data, and adding the three scores to obtain the total score, thereby realizing the quantitative evaluation of the main control factors, the comprehensive evaluation of the reservoir transformation effect and the quantification of measure well selection. According to the method, the problems of large development effect difference and unclear productivity main control factors of the tight oil fractured horizontal well are solved, and the method has guiding significance on new well deployment and later development adjustment of a tight oil field.

The invention discloses a fracturing parameter determination method and device, electronic equipment and a machine readable storage medium. The fracturing parameter determination method comprises the steps that an initial rock core scale numerical simulation model is established according to geological parameters; fitting an initial component model in the initial rock core scale numerical simulation model to obtain a rock core scale numerical simulation model; a rock core scale numerical simulation model is used for analyzing the synergistic effect after carbon dioxide enters the reservoir in the target area and the influence of the first initial fracturing parameter on the synergistic effect, and a first analysis result is obtained; constructing an oil field scale numerical simulation model according to the geological parameters, the component model and an original oil reservoir numerical simulator; and according to the first analysis result and the target index, performing fracturing parameter optimization by using an oil field scale numerical simulation model to obtain fracturing parameters. Therefore, the determination efficiency and accuracy of the fracturing parameters are improved, and the fracturing parameters can better meet the efficiency requirement of tight oil reservoir exploitation.

A method for identifying fractured and porous zones using P-wave and S-wave logging is proposed. First, a nonlinear relationship between P-wave and S-wave logging data of the target formation is fitted based on density, natural gamma, and full-wave logging data. The S-wave logging curves for all wells are then calculated based on this relationship. Second, the P-wave and S-wave velocity ratios of the wells are calculated. Third, the P-wave and S-wave velocity ratios of mudstone with a certain thickness in the target formation are identified and statistically analyzed. If the P-wave and S-wave velocity ratio of a mudstone section is less than 1.7, similar to the sandstone layers above and below, and significantly lower than the corresponding values ​​of the overlying and underlying mudstone, it indicates the presence of fractures or pores in or near that mudstone section. Alternatively, it suggests that the well is located on a strike-slip fault zone, and the fractured and porous low-Vp / Vs mudstone section is near the fault location. This method offers low cost and high accuracy in identifying downhole fractures and pores. It has significant practical value for identifying drilling mud loss sections, sweet spots in tight oil and gas and shale oil and gas, evaluating production capacity, determining reservoir formation models, assessing fracturing, and determining oil, gas, and water permeability.

The invention discloses a dense oil reservoir carbon dioxide drive layered gas injection decision-making method. The method comprises the following specific steps that 1, a heterogeneous reservoir high-permeability gas suction proportion theoretical mathematical model based on the starting pressure gradient is constructed; 2, drawing a reservoir stratified gas injection permeability range boundary chart according to the theoretical mathematical model in the step 1; 3, the permeability and the permeability range of the low-permeability reservoir of the oil reservoir to be decided are obtained; 4, the permeability and the permeability range of the low-permeability reservoir in the step 3 form coordinate points, the coordinate points are substituted into the reservoir stratified gas injection permeability range boundary plate in the step 2, and when the coordinate points are located above a curve of the reservoir stratified gas injection permeability range boundary plate, stratified gas injection work is conducted on the reservoir to be decided; according to the method, by drawing the stratified gas injection boundary quantification chart of the reservoirs with different matrix permeability, the stratified gas injection permeability range boundary is defined, and the problem that the permeability range boundary of the carbon dioxide drive stratified gas injection reservoir is not clear is effectively solved.

The invention discloses a method for quantitatively characterizing the occurrence state of tight oil and related equipment, relates to the field of oil and gas exploitation, and mainly aims to solve the problem of lack of a better method for detecting the occurrence state of tight oil. The method comprises the following steps: acquiring a CT in-situ recovery scanning image of a target area sample; representing the basic structure of the rock based on a CT in-situ recovery scanning image; determining a rock pore throat structure based on the rock basic structure in combination with the distribution range and contribution rate of the pore throat radius; based on the CT in-situ recovery scanning image and the gray level change data of the same vision field image before and after oil washing, the gray level range of the tight oil fluid image is determined, and the content of the movable fluid and the content of the bound fluid are calculated according to the proportion data of the communicated pores. The method is used for quantitatively characterizing the tight oil occurrence state process.

This invention proposes a storage fracturing method suitable for low-permeability tight oil reservoirs. By selecting shale reservoir samples with four different clay mineral contents, an organic swelling inhibitor solution is prepared. Displacement experiments are conducted on the four samples with different clay contents. By measuring the changes in porosity and permeability, sample volume, and sand production before and after displacement with the organic swelling inhibitor solution, the effectiveness of the organic swelling inhibitor under different clay contents is determined. This leads to the determination of the dosage of the organic swelling inhibitor for reservoirs with different clay contents, and a method for evaluating the effect of the swelling inhibitor on the hydration and swelling inhibition of shale reservoirs is derived. This invention's evaluation system is highly effective, employs multiple evaluations, is highly persuasive, and has strong generalizability.

The invention relates to the field of oil-gas field development, in particular to a quantitative evaluation method for an ultra-low permeability reservoir oil well yield contribution rate. The method mainly solves the problems that an existing method for evaluating the yield contribution rate of the ultra-low permeability reservoir fractured geology oil well is poor in accuracy of a judgment result of oil well potential detection and low in accuracy of an oil well reserve evaluation result. Comprising the following steps: S1, detecting an oil well, and performing structural analysis on a detection result; s2, carrying out oil well potential detection according to a structural analysis result; s3, reserve evaluation; and S4, contribution rate calculation. According to the quantitative evaluation method for the yield contribution rate of the ultra-low permeability reservoir oil well, whether the ultra-low permeability reservoir fractured geological oil well has potential or not can be accurately judged, the evaluation result is accurate and reliable, and a reliable basis is provided for subsequent rapid optimization of a tight oil area.

The invention relates to the field of oilfield chemistry, and discloses a surface active discharge aiding agent for oilfield fracturing flow-back and a preparation method of the surface active discharge aiding agent. The molecular structure of the cleanup additive is composed of a betaine type cation head group, a sulfonic acid hydrophilic group and a hydrophobic chain connected by an intermediate ester bond, and the cleanup additive has good amphipathy and interface regulation and control capability. The cleanup additive is prepared through quaternization, hydroxyethylation and esterification reactions, the process is simple, and the structure is adjustable. The prepared cleanup additive shows excellent interfacial activity under high-temperature and high-salt conditions, significantly reduces the oil-water interfacial tension, improves the oil carrying rate and fluidity of fracturing flow-back fluid, has good biodegradability, and reduces the risk of stratum pollution. The method is suitable for flowback operation of shale oil and tight oil unconventional oil reservoirs, and has the characteristics of high efficiency, environmental protection and large-scale application.

A kind of compact oil and gas reservoir productivity splitting method, step one, calculate oil and gas splitting coefficient KH;Step two, to oil and gas splitting coefficient KH heterogeneity correction;Step three, based on the heterogeneity of the corrected reservoir KH, introduce gas saturation, gas measuring total hydrocarbon and formation depth, using the data model of different single layer of well composition, each gas testing result data of this data model is regarded as the liquid production of pseudo liquid profile, carry out production splitting, establish new production splitting model;The calculation result shows that, on the basis of the heterogeneity correction of KH coefficient, by simultaneously introducing gas layer depth, sand body gas saturation and gas measuring total hydrocarbon parameters, the advantages of accurately evaluating the productivity of compact oil and gas reservoir can be obtained, easy to popularize, with important application prospect and economic value.

The present application relates to the technical field of petroleum geological exploration, and specifically discloses a method for exploring geological tight oil of a lower combination of Yanchang Formation in Ordos Basin, which screens effective formation water samples through double indexes, establishes a three-dimensional mineralization degree spatial distribution body and dynamically corrects water saturation, fuses oil saturation, seismic attributes and core mercury injection data to construct a multi-source feature matrix, applies differential correction to three types of low-resistance causes, namely, high bound water type, high mineralization type and micro-fracture conductive type, trains a sweet spot prediction model by using a random forest and XGBoost integrated learning framework, introduces a SHAP method to verify geological interpretability, generalizes the solidified model to the whole area to obtain a three-dimensional sweet spot probability body, introduces a source-reservoir pressure difference driving index to perform reservoir forming dynamics weighted correction, and grades favorable exploration target areas according to a probability threshold to output recommended well location coordinates, effectively solving problems such as low-resistance oil layer misjudgment, lack of interpretability in prediction, and lack of reservoir forming dynamic constraints in spatial evaluation.

The invention belongs to the field of shale oil and gas and tight oil and gas exploration, and discloses a shale gas geological sweet spot post-stack earthquake prediction method, system and program product based on a rock physical quantity edition, and the method comprises the steps: analyzing rock physical sensitive parameters of a shale gas geological sweet spot in a research area; establishing a rock physical quantity version of the shale gas geological dessert in the research area based on analysis of rock physical sensitive parameters; and carrying out post-stack seismic inversion based on the rock physical quantity plate to predict the plane distribution of the shale gas geological sweet spots in the research area. According to the method, the rock physical quantity edition and the post-stack seismic data of the shale sample are organically combined in a breakthrough mode, the problem that multiple solutions exist in geological sweet spot distribution such as shale TOC prediction by directly utilizing the seismic data is solved, and the plane distribution characteristics of the geological sweet spots in the shale gas can be effectively predicted.

The present application relates to the technical field of tight oil and gas development, and particularly discloses a method and device for calculating the permeability of a tight oil and gas reservoir based on fine classification of pores. The method comprises the following steps: obtaining multiple sets of sample data of multiple samples of the tight oil and gas reservoir, each set of sample data including the characteristic pore size of different types of pores of the corresponding sample and the experimentally measured permeability; based on the multiple sets of sample data, fitting to construct a permeability calculation model representing the correlation between the permeability and the characteristic pore size of each pore type; and based on the permeability calculation model, calculating the permeability of the sample to be evaluated. The present application classifies the pore types finely and determines the characteristic pore size of different types of pores, and constructs a permeability calculation model based on the characteristic pore size of different types of pores by considering the contribution of different types of pores to the permeability, thereby greatly improving the calculation accuracy of the permeability.

The invention discloses a tight oil shale oil reservoir surface activity authigenic agent and a preparation method thereof. The surface activity authigenic agent is composed of a hydrogen bond complexing ligand, an auxiliary solubilizing stabilizer and an auxiliary synergist according to the mass ratio of (1.3-12): (1.5-25): (0.01-1). The surface active authigenic agent can excite an authigenic surfactant in a reservoir, and is used in fracturing fluid, so that addition of a discharge aiding agent is omitted, the cost of the fracturing fluid is reduced, and the economy of tight oil reservoir development is improved; when the hydrogen bond complex is used in fracturing fluid, the newly generated hydrogen bond complex can be rapidly enriched on an oil-water interface, interfacial tension and surface tension are remarkably reduced, and the low-tension characteristic is beneficial to reducing capillary resistance and promoting efficient flowback of gel breaking fluid from a reservoir, so that the water locking effect and stratum damage are reduced, and the yield is increased; and meanwhile, the dual goals of increasing the yield and reducing the cost are achieved.

The invention discloses a fractured tight oil reservoir saturation modeling method. The method comprises the following steps that S100, a well-seismic combined structure fault model is established; s200, under the constraint of a sedimentary facies mode, utilizing a single well facies as hard data in the longitudinal direction and data analysis according to a variation function on a plane as guidance, applying an SIS random algorithm to simulate sandstone facies distribution, and establishing a sandstone-mudstone spatial distribution model; s300, based on the seismic fusion attribute three-dimensional body and the sandstone three-dimensional model, establishing a fracture phase three-dimensional geologic model; s400, establishing a fault distance-saturation function through a fitting method, and establishing an oil saturation three-dimensional geologic model according to the function; compared with a traditional saturation modeling method, the saturation model established through the method has the advantages that the control effect of fracture on the oil-water distribution rule is described more accurately, the coincidence rate of the saturation model established through the method is 90% compared with that of a real drilled well, a good oil reservoir geologic model is provided for numerical simulation, and the development effect of an oil field is improved.

This invention discloses a method for fracturing fractures in tight oil reservoirs, belonging to the field of reservoir stimulation technology. This method induces test fracturing by determining the brittleness index and the number of perforations in the surrounding rock layers, thus obtaining the original natural fractures in the surrounding rock layers. By controlling the net pressure of the main fractures in these original natural fractures and rationally adjusting the dosage and injection method of slickwater, adhesive, and sealing agents, the complex natural fractures in the tight oil reservoir are extended and sealed over a large area. Finally, by heating the fracturing area, new fractures are opened, thereby opening reservoirs with different stresses and increasing the production of tight oil. This method effectively solves the problems of difficult fracturing initiation, simple fracture morphology, and low fracture complexity in tight oil reservoirs, thus improving the extraction efficiency of tight oil and having significant implications for enhancing the commercial value of tight oil.

The invention relates to the technical field of hydrocarbon source rock evaluation standard establishment methods, in particular to a hydrocarbon source rock evaluation standard establishment method based on rock pyrolysis, which comprises the following steps: based on five original parameters obtained by pyrolysis, calculating six derived parameters including total organic carbon content, hydrogen index, hydrocarbon source rock oil production rate, hydrocarbon potential, effective carbon content and residual carbon content; establishing an evaluation standard of the hydrocarbon source rock according to the organic matter abundance, the organic matter type and the maturity, wherein evaluation parameters of the organic matter abundance comprise the total organic carbon content and the hydrocarbon production potential quantity; the evaluation parameters of the organic matter type comprise a hydrogen index and a hydrocarbon source rock oil generation rate; the maturity evaluation parameters comprise a pyrolysis temperature peak value of kerogen cracked hydrocarbon. According to the method, the evaluation standard of the hydrocarbon source rock is established, evaluation is carried out from the three aspects of organic matter abundance, organic matter type and maturity, technical guarantee is provided for exploration, development and evaluation of the hydrocarbon source rock, and the method is particularly suitable for evaluation of tight oil hydrocarbon source rock.

The invention provides a volume fracturing optimization method for improving the single well yield of a tight oil reservoir. The volume fracturing optimization method comprises the following steps that (1) well selection and layer selection are conducted according to the purpose of increasing the reservoir transformation volume; on one hand, natural fractures are relatively developed, the natural fractures are communicated through fracturing, and net-shaped fractures are achieved; the brittleness index of the reservoir is high, and rock is prone to shear slippage to form complex cracks; 2) optimizing fracturing fluid systems in a prepad fluid stage and a sand-carrying fluid stage; and (3) fracturing construction parameters are optimized. According to a conventional tight reservoir volume fracturing design method and an underground micro-seismic test result, aiming at a tight reservoir with poor reservoir physical properties, developed natural fractures and high brittleness index, the method aims at increasing the reservoir transformation volume and improving the fracture complexity, and on the basis of a conventional conventional volume fracturing large-liquid-amount, high-displacement and low-mucus design mode, the method is suitable for the volume fracturing design of the tight reservoir and the underground micro-seismic test result. And the fracturing fluid, the pumping sequence of fracturing parameters and the technological property are changed, the reservoir transformation volume is further increased, and the single well yield is increased.

The embodiment of the invention relates to the technical field of oil and gas field development, and discloses a carbon dioxide injection oil displacement development method and equipment for a tight oil reservoir. Establishing a multi-factor hierarchical structure model according to geological parameters, fluid parameters, construction parameters and injection-production parameters in the influence parameters; determining a quantitative scale value of the multi-factor hierarchical structure model according to a main control parameter in the predetermined influence parameters; and according to the main control parameters, the quantitative scale values and a pre-established type-2 fuzzy logic-artificial neural network system, determining construction parameters and injection production parameter ranges under different levels of geological parameters and fluid parameters. According to the method, a large amount of data can be processed in a short time, the construction and injection-production parameter optimization range is locked, and the well pattern deployment-fracturing construction-CO2 injection-production oil displacement integrated optimal design scheme is obtained.

The invention relates to the technical field of tight oil reservoir fracturing, in particular to a tight oil vertical well carbon dioxide energy storage fracturing process method. The method comprises the following steps: acquiring a crack image of a tight oil reservoir; determining the type of a crack node based on the position of the crack node in a crack region in the crack image, constructing a topological structure diagram, and determining the connectivity rate of the topological structure diagram; according to the number of the crack nodes of each type, the length distribution of the cracks and the connectivity rate, the crack density is obtained; constructing an equivalent permeability matrix of the tight oil reservoir by combining the matrix permeability of the tight oil reservoir, the porosity of the fracture, the fracture density and the extension direction of the fracture; and the effective thickness of the reservoir, the equivalent permeability matrix, the difference between the formation fracture pressure and the original formation pressure and the critical carbon dioxide viscosity are integrated, and the type of the fracture node is combined, so that the target injection amount of carbon dioxide is determined. According to the method, the sufficiency of hydraulic fracturing energy supplementation is guaranteed, and the yield of a tight oil reservoir is increased.

The invention relates to the technical field of oil and gas field development, in particular to a tight oil geological engineering integrated well selection method and device, equipment and a medium, and the method comprises the steps that according to work area tight oil reservoir classification, a reservoir parameter yield prediction equation is established, and work area oil well reservoir parameter yield is determined; the fracturing parameter yield is determined through a multi-fracture productivity prediction formula; determining a reservoir transformation coefficient according to the reservoir parameter yield and the fracturing parameter yield; determining the economic production capacity coefficient of the horizontal well based on the cumulative oil production of the single well; and establishing a well selection chart according to the reservoir transformation coefficient and the economic production capacity coefficient, and determining to perform energy supplement or refracturing on the well points according to the quadrant where the well points are located in the well selection chart. According to the method, multi-aspect related factors are comprehensively and quantitatively considered in the aspect of productivity evaluation, the problem that different results cannot be transversely compared is solved, geological cognition change along with work promotion and data supplementation can be helped to be displayed, and higher convenience and systematicness are achieved.