159 results about "Tight oil" patented technology

The invention belongs to the field of single-well gas injection, and discloses a low-permeability tight oil reservoir single-well CO2 gas injection and displacement speed determination method and a related device. The method comprises the following steps: constructing a carbon dioxide gas flooding and injection velocity model containing matrix overburden pressure permeability and starting pressure gradient; the method comprises the following steps: testing the permeability of a reservoir core sample of a tight sandstone reservoir under different effective stresses to obtain a first relation curve, and carrying out regression analysis to obtain a first coefficient corresponding to the matrix overburden pressure permeability; respectively carrying out starting pressure gradient testing on the core samples with different matrix overburden pressure permeability to obtain a second relation curve, and carrying out regression analysis to obtain a second coefficient corresponding to the starting pressure gradient; and the collected basic data, the first coefficient and the second coefficient are input into the carbon dioxide flooding gas injection speed model for calculation, and the gas injection speed of the single well is obtained. According to the method, the carbon dioxide flooding and gas injection speed can be better optimized, and therefore the exploitation efficiency of an oil field is improved.

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 relates to the technical field of thickening agents, and particularly discloses a novel thickening agent for oil well fracturing and a preparation method thereof. The preparation method of the novel thickening agent for oil well fracturing comprises the following steps: preparing modified hydroxyethyl methylacrylate; preparing a gradient branched polymer solution; preparing sulfonic acid-boric acid double-modified montmorillonite powder; preparing a colloidal solution; the colloidal solution is centrifuged, spray-dried and sieved, and the novel thickening agent for oil well fracturing is obtained. The novel thickening agent for oil well fracturing has temperature resistance, salt resistance and self-repairing performance, in practical application, in the low-temperature pumping injection stage, the thickening agent can be rapidly thickened and carry a proppant, the self-repairing performance is triggered after the thickening agent enters a high-temperature stratum, a dynamic network part is dissociated during flowback, the viscosity is reduced, and reliable technical support is provided for development of deep shale gas and tight oil.

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 provides a tight oil reservoir fracturing construction effect evaluation method based on a pump stopping curve, and relates to the technical field of oil and gas exploitation. Firstly, fracturing construction and microseismic data of a target well section are collected, and a pump stopping stage is identified and a pressure change curve is extracted; water hammer effect parameters (such as boundary condition number, period number and attenuation rate) are utilized to preliminarily judge crack expansion condition and fracturing operation effectiveness. Then, an integrated simulation technology is applied, microseismic data are combined to constrain fracture boundaries, and fracture forms and inherent rules are revealed by means of numerical simulation. Finally, parameters such as the fracture length and the permeability of a single fracturing section are calculated in an inversion mode based on the optimal simulation result, and the fracturing construction effect is comprehensively evaluated in combination with water hammer effect analysis. According to the method, multiple data sources are creatively fused, the limitation that judgment only depends on a pump stopping curve is effectively overcome, accurate evaluation on the fracturing efficiency, the fracture complexity and the reservoir contact state is achieved, and a more accurate decision basis is provided for oil reservoir development.

The present invention relates to the technical field of thickeners, and specifically discloses a novel thickener for oil well fracturing and a preparation method thereof. The preparation method of the novel thickener for oil well fracturing includes: preparing modified hydroxyethyl methacrylate; preparing a gradient-branched polymer solution; preparing a sulfonic acid-boric acid double-modified montmorillonite powder; preparing a colloidal solution; centrifuging, spray-drying, and sieving the colloidal solution to obtain the novel thickener for oil well fracturing. The novel thickener for oil well fracturing prepared by the present invention has the characteristics of temperature resistance, salt resistance, and self-healing performance. In practical applications, it can quickly thicken and carry proppants during the low-temperature pumping stage, trigger the self-healing performance after entering the high-temperature formation, and partially dissociate the dynamic network to reduce the viscosity during backflow, providing a reliable technical support for the development of deep shale gas and tight oil.

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 utility model belongs to the technical field of oil extraction devices, and particularly relates to a tight oil horizontal well staged oil extraction device which comprises a well body and a sampling device, the side wall of the well body is communicated with a main pipe, and the surface of the well body is communicated with an auxiliary pipe. A sampling device is arranged on the surface of the auxiliary pipe and comprises a placement ring, the placement ring is located under the auxiliary pipe, the inner surface of the placement ring is rotationally connected with a rotating block, the surface of the rotating block is fixedly connected with four fixing rings, sampling bottles are inserted into the inner walls of the fixing rings, and a blocking device is arranged on the inner wall of the auxiliary pipe and comprises a moving block; the surface of the moving block is slidably connected with the inner wall of the auxiliary pipe, and a baffle disc is fixedly connected to the side wall of the moving block and inserted into the inner wall of the auxiliary pipe; by arranging the whole device, tight oil can be conveniently sampled, meanwhile, multiple times of sampling can be conveniently carried out, the time for taking the sampling bottle is shortened, and meanwhile tight oil in different time periods can be conveniently sampled.

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.

The present invention proposes a prediction method, device, electronic equipment and medium for the EUR of a tight oil horizontal well, which is applicable to the field of oil extraction technology, including: accumulating the basic data of the tight oil horizontal well twice, that is, the j-th primary accumulated data includes accumulating the dimensionless data of the basic data of the first j time units in n time units according to the cumulative production and each main controlling factor, and the j-th secondary accumulated data includes accumulating the primary accumulated data of the first j time units in n time units according to the cumulative production and each main controlling factor, so as to weaken the adverse effects of the randomness of historical data, and establish a tight oil horizontal well cumulative production prediction model based on the secondary accumulated data, which can accurately describe the correspondence between the cumulative production of the tight oil horizontal well and the main controlling factors, so as to predict the cumulative production of the tight oil horizontal well in the next time unit, thereby improving the accuracy of predicting the cumulative production of the tight oil horizontal well.

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 relates to the technical field of oil and gas field development, and relates to a compact oil reservoir lithogenous phase quantitative characterization method and device based on pore transformation strength, and the method comprises the steps: obtaining the pore loss amount caused by the cementation effect, the pore loss amount caused by mechanical compaction, and the pore increase amount caused by the corrosion effect in a research area; based on the surface porosity of the research area, the pore loss amount caused by the cementation effect, the pore loss amount caused by mechanical compaction and the pore increment amount caused by the corrosion effect, the modification strength of the cementation effect on pores, the modification strength of the compaction effect on the pores and the modification strength of the corrosion effect on the pores are obtained; according to the modification strength of the cementing effect on the pores, the modification strength of the compaction effect on the pores and the modification strength of the corrosion effect on the pores, a tight oil reservoir diagenetic phase division parameter table is constructed; and determining the diagenetic phase of the target tight oil reservoir based on the diagenetic phase division parameter table of the tight oil reservoir. The method can provide a certain guiding effect for tight oil-gas exploration, and can be used for reference of similar cases.

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 present disclosure provides a method and device for determining the average formation pressure of a reservoir after pressure drive in a low-permeability tight oil reservoir, relating to the technical field of oilfield development, including: determining the control equation and constraint condition equation for the average formation pressure of the target reservoir after pressure drive based on the physical model of the average formation pressure of the target reservoir after pressure drive; determining the prediction relationship between the reservoir pressure, radial distance, and production time in different seepage capacity regions of the target reservoir after pressure drive under stress-sensitive conditions based on the control equation and constraint condition equation for the average formation pressure of the target reservoir after pressure drive; and determining the average formation pressure of the target reservoir after pressure drive based on the prediction relationship between the reservoir pressure, radial distance, and production time in different seepage capacity regions of the target reservoir after pressure drive under stress-sensitive conditions and the production history data of the target reservoir. The method provided by the present disclosure is used to calculate the average formation pressure of the reservoir after pressure drive.

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.

The invention discloses a tight reservoir exploitation method, and belongs to the technical field of petroleum development. The mining method for the tight reservoir comprises the steps that S1, a well pattern is arranged, wherein the well pattern is a vertical well and horizontal well combined well pattern; s2, fracturing and gas injection are conducted on the vertical well; s3, fracturing and soaking the horizontal well; s4, all the horizontal wells are opened for production, and all the vertical wells are closed until the production effect does not meet the first set requirement; s5, the horizontal wells in even rows are controlled to be shut down, the horizontal wells in odd rows are controlled to be converted into injection wells and inject gas into the stratum, and the vertical wells are controlled to serve as the injection wells to inject gas into the stratum; s6, after gas injection is finished, all the vertical wells are shut in for soaking, and all the horizontal wells are shut in for soaking; s7, after soaking is finished, all the horizontal wells are controlled to be opened for production, and all the vertical wells are controlled to be closed until the production effect does not meet the second set requirement; and S8, repeatedly executing the steps S5 to S7 for a plurality of times. The method can provide help for the development of tight oil / shale oil reservoirs.

The invention discloses a water-controlling oil-increasing refracturing method and system for a high-water-content oil well in a low-permeability tight oil reservoir, and relates to the technical field of reservoir reformation, and the method comprises the steps that S101, refracturing opportunity charts of high-water-content oil wells in different oil reservoirs are established, the quantitative relation between the stratum pressure and the maximum and minimum crustal stress differences and crustal stress deflection angles of the stratum pressure and the horizontal maximum and minimum crustal stress differences and the quantitative relation between the stratum pressure and the horizontal minimum crustal stress deflection angles are determined, and the stratum pressure is determined; determining whether the high-water-content well can be subjected to refracturing or not; s102, if the high-water-content well can be subjected to refracturing, further determining the dosage of low-viscosity high-strength gel and a composite blocking agent of the high-water-content well according to the water breakthrough characteristics; s103, low-viscosity high-strength gel and a composite plugging agent are pumped and injected at the displacement of 0.8-2.0 m < 3 > / min and are displaced to the reservoir and the deep part of the crack; s104, the high-water-content oil well is closed until the composite plugging agent is cured, and injection is tested for plugging effect verification; and S105, a double-upper-seal fracturing pipe column is put down, and repeated fracturing construction of the high-water-content well is completed. The effective rate of measures can be effectively increased, the risk of water breakthrough after pressure is reduced, and the probability of crack steering is greatly increased.

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 provides a compact oil and gas reservoir fracturing fracture sanding concentration design method considering pressure-sensitive damage. The compact oil and gas reservoir fracturing fracture sanding concentration design method comprises the steps that 1, the optimal flow conductivity of a compact oil and gas reservoir fracturing fracture is obtained through optimization with an oil reservoir numerical simulation method; 2, measuring the flow conductivity of the tight oil and gas reservoir support fracture under different conditions, and establishing a relation equation between the flow conductivity of the support fracture and the sanding concentration as well as the effective closing pressure; 3, according to the maximum effective closing pressure formed in the fracturing crack in the compact oil and gas reservoir depressurization production process and the optimal crack flow conductivity obtained through digital-analog optimization, the fracturing crack sanding concentration considering the pressure-sensitive damage is designed with reference to the supporting crack flow conductivity relation equation. According to the compact oil and gas reservoir fracturing crack sanding concentration design method considering the pressure-sensitive damage, a basis can be provided for reasonable sanding concentration design of a compact oil and gas reservoir hydraulic fracturing process, productivity loss caused by crack pressure sensitivity in the pressure reduction production process is avoided, and then a longer stable production period is obtained.

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 discloses a method and system for evaluating the pressure-driving potential of a low-permeability tight reservoir, and relates to the technical field of oil and gas field development, in the method, a pressure-driving potential prediction sample set is constructed, and a DRSN-Adaboost model is trained to serve as a pressure-driving potential prediction model; geological parameters, fluid property parameters and pressure driving construction parameters are obtained, and a corresponding pressure driving potential evaluation index prediction result is obtained through the pressure driving potential prediction model; and finally, according to a pressure driving potential evaluation index prediction result and the weight of each pressure driving potential evaluation index, calculating to obtain a pressure driving potential comprehensive score of each pressure driving well group of the target oil reservoir, thereby realizing pressure driving potential evaluation, and guiding an oil field on-site pressure driving well selection decision. According to the scheme provided by the invention, the pressure-driving effects of different oil reservoirs and different schemes can be predicted, the prediction efficiency is high, the time cost and repetitive work of a traditional numerical simulation method can be reduced, and the method has important guiding significance for evaluating the pressure-driving potential of the low-permeability tight oil reservoir.

The present application belongs to the technical field of petroleum and natural gas geology and exploration and development engineering, and particularly relates to a method and system for identifying fluid properties of high-salinity tight reservoirs. The macroscopic capture cross-section theoretical value under the condition of high-salinity formation water is calculated by using mineral content, then the difference value between the macroscopic capture cross-section theoretical value and the measured value of the macroscopic capture cross-section is used as a sensitive factor for oil-bearing property judgment, and the difference value and the effective porosity are used to form a fluid property identification chart, so that the fluid properties of tight oil reservoirs under the condition of high-salinity background can be accurately identified; the ratio of the relative yield of chlorine element to the effective porosity is used as a salt-bearing sensitive factor, and the salt-bearing sensitive factor and the effective porosity are used to form a salt-bearing evaluation chart, so that the salt-bearing degree of the sweet spot section can be judged, and it is determined whether oil testing is necessary. The method can accurately identify the fluid properties under the condition of high-salinity tight reservoir background, and give oil testing suggestions.