209 results about "Tight oil" patented technology

The invention relates to the technical field of oil production engineering, in particular to a fracturing process for a tight oil horizontal well, which comprises the following steps: acquiring geological data information; determining a rock stratum state according to the pore reference value of the to-be-constructed area and the tight oil enrichment degree, and determining a target stratum setting mode according to the rock stratum state; perforation is conducted on the toe end of the horizontal well, and fracturing operation is conducted on all target layers after perforation of the toe end of the horizontal well is completed; the injection amount of CO2 fracturing fluid is determined according to the length of the reference oil-containing sandstone, and the content of a thickening agent is determined according to the reservoir pressure; if the fracture density is smaller than the preset fracture density, it is determined that the fracturing fluid adjusting mode of the rear target layer is an optimization mode determined according to the gravel particle size difference degree or adjustment is conducted according to the injection pressure of CO2 fracturing fluid according to the gravel state of the proppant; after the CO2 fracturing fluid is injected into the whole well section, the well closing time is determined according to the comprehensive reference value; and drilling and removing the bridge plug. The fracturing effect can be improved, and the exploitation efficiency of the tight oil horizontal well is improved.

The invention relates to an infinite intelligent regulation and control fracturing sliding sleeve which is particularly suitable for development of unconventional oil and gas resources such as shale gas and tight oil. The concrete structure of the infinite intelligent regulation and control fracturing sliding sleeve dart part comprises an outer shell, a lower baffle disc, an upper baffle disc, a bolt, a spring, a clamping ring, a blocking ball, a thrust block, a thrust bearing, a flow dividing block, a motor, a flow divider, a capacitive sensor, a silicon rubber sealing piece, a control module and a flow divider end cover. When the infinite intelligent control fracturing sliding sleeve dart part passes through a designated position, the infinite intelligent control fracturing sliding sleeve dart part judges and counts each part needing to be fractured through the three capacitive sensors, when a preset value is reached, the tool is switched to an activated state, the blocking ball is impacted under the pressure of drilling fluid, and the part needing to be fractured is fractured. The thrust block is pushed, the thrust block opens the piston on the casing pipe under the pressure building effect, and fracturing operation is achieved. And the limitation of the size of a steel ball in the traditional ball throwing type sliding sleeve technology is avoided, the operation complexity is reduced, the construction efficiency is improved, and a new technical means is provided for efficient development of unconventional oil gas.

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 belongs to the technical field of oil-gas field development tertiary oil recovery and unconventional oil-gas development, and discloses a low-permeability-tight oil reservoir carbon dioxide injection effective displacement distance evaluation method, which comprises the following steps: obtaining several groups of different permeability core starting pressure gradients, and obtaining a quasi-starting pressure gradient according to the starting pressure gradients; establishing a mathematical relationship between the real starting pressure gradient and the permeability and a mathematical relationship between the quasi-starting pressure gradient and the permeability; effective displacement distances of reservoirs with different permeability under different pressure gradient conditions are obtained through calculation, and an effective displacement distance and permeability relation chart is established; according to the oil field early-stage oil production well average well bottom pressure, oil production well bottom pressure is obtained, and then the pressure gradient between the gas injection well and the oil production well is obtained; and according to the actual permeability of the oil reservoir and the pressure gradient between the gas injection well and the oil producing well, the actual effective displacement distance of oil reservoir carbon dioxide flooding is obtained. According to the method, the limiting distance of fluid flowing is simply calculated by using a limiting well spacing method, the method is simple and rapid, and few basic parameters are needed.

The invention provides a wave propagation characteristic prediction method and prediction device for a compact oil and gas reservoir, and the method comprises the steps: enabling a pore fluid in a compact oil and gas reservoir medium to be equivalent to a power law fluid, and obtaining a dissipation function of a fluid-pore-containing dual-phase medium for a non-Darcy flow seepage mechanism; standard linear body form popularization and fractional order derivative introduction are carried out on the three-dimensional isotropic body constitutive relation, and a system generalized force expression based on a fractional order viscoelastic mechanism is obtained; and finally, according to the combination of a dissipative function, a system generalized force expression and a Biot kinetic energy function with an Euler-Lagrange equation, obtaining a unified wave propagation model which aims at a tight oil and gas reservoir medium and simultaneously contains a non-darcy flow and a fractional order viscoelastic mechanism. According to the method, the propagation rule of the waves in the tight oil and gas reservoir medium can be finely described, and the accuracy of predicting the propagation characteristics of the waves and the accuracy of oil and gas reservoir medium parameter inversion calculation are improved.

The preparation method comprises the steps that firstly, a carbon source and a nitrogen source are stirred and mixed to be uniform, alkylamine polyoxyethylene ether is added into the mixture under the water bath heating condition, the mixture is sealed and stirred to form a light yellow block, then a solid-phase pyrolytic reaction is conducted, and a black solid product is obtained; grinding the black solid product, dispersing in n-hexane, and washing; and adding absolute ethyl alcohol and further washing by combining ultrasonic waves to obtain a black powdery product. Dissolving the product in deionized water, filtering and purifying, and carrying out centrifugal separation on the obtained black liquid; dialyzing the clear liquid, and finally drying the solution in a dialysis bag to obtain the nitrogen-doped quantum dots. Preparing nitrogen-doped quantum dot dispersion liquid by using on-site injection fluid; and injecting the dispersion liquid into a target reservoir, soaking for 1-2 days, and then opening the well for production. The nitrogen-doped quantum dots are suitable for low-permeability (ultra-low permeability) oil reservoirs, compact oil reservoirs and shale oil reservoirs, and the recovery efficiency of crude oil is economically and efficiently improved.

The invention belongs to the technical field of tight oil reservoir exploitation, and provides a method, a system, equipment and a medium for predicting recoverable reserves of a tight oil reservoir, and the method comprises the following steps: collecting single well historical production data of the tight oil reservoir, and arranging and constructing a time sequence according to a time sequence; and calculating autocorrelation and partial autocorrelation functions, and selecting an AR, MA or ARMA model as a prediction model according to function features. After the model is constructed, historical production data is used for training, and a trained prediction model is obtained; and inputting single well historical production data into the model, and outputting a future predicted final recoverable reserve prediction value. The method can accurately predict the predicted final recoverable reserves of the tight oil reservoir single well.

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 provides a tight sandstone discrimination and energy storage fracturing process parameter optimization method, which comprises the following steps: firstly, determining tight oil core physical properties and pore structure characteristics to lay a foundation for energy storage fracturing mechanism and scheme optimization, secondly, based on fracturing fluid imbibition and micro-macroscopic oil displacement tests, revealing a main action mechanism of imbibition, and finally, determining the energy storage fracturing process parameters according to the imbibition and micro-macroscopic oil displacement tests. Determining whether tight sandstone has imbibition, imbibition displacement oil displacement capability and imbibition displacement oil displacement mechanism; an oil-water replacement relational expression in the energy storage stage is established by analyzing data of shut-in time after pressure, the average daily pressure drop and the daily pressure drop in the open flow period; through tight oil fracturing productivity influence factor analysis, geological engineering key parameters influencing the tight oil energy storage volume fracturing effect are determined; an energy storage volume fracturing-productivity integrated analysis model is established, whether a tight reservoir needs energy storage or not and the energy storage mode are determined, applicable technical parameter boundaries are put forward, and theoretical and technical supports are provided for improving the energy storage volume fracturing effect and prolonging the effective period of measures.

The invention relates to a method and a device for determining the organic carbon content of marsh hydrocarbon source rock, and the method comprises the following steps: obtaining the organic carbon content and a plurality of mineral component parameters of a series of rock cores of a sea-land transition phase hydrocarbon source rock stratum section, and determining the correlation between the organic carbon content and each mineral component parameter; screening at least one target mineral component parameter related to the organic carbon content based on the correlation; fitting to obtain a function relation between the organic carbon content and the core logging response value and at least one target mineral component parameter; determining at least one target mineral component parameter of the to-be-measured rock core based on the logging curve; and determining the organic carbon content according to the target logging response value of the to-be-measured rock core, the at least one target mineral component parameter and the function relation. The organic carbon content of the margarious hydrocarbon source rock calculated by the method has the characteristics of high accuracy and reliable result, and effective technical support is provided for logging evaluation of the organic carbon content of the margarious hydrocarbon source rock in exploration and development of shale oil and gas and compact oil and gas.

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 oilfield reservoir transformation, and specifically to a method for calculating the imbibition distance of tight oil horizontal well fracturing energy enhancement. The method mainly solves the problem that the imbibition distance cannot be quantified in the design optimization of tight oil horizontal well fracturing energy enhancement integrated transformation, resulting in a large difference between the post-fracturing capacity prediction and the actual result. The present invention first selects a target well, then determines the well-blocking time by using the well-blocking time formula, and finally determines the target well imbibition distance according to the well-blocking time-reservoir permeability-imbibition distance relationship chart. The present invention is simple and intuitive to operate, can quickly obtain the target well imbibition distance under given conditions, and has guiding significance for the prediction of the post-fracturing capacity of tight oil horizontal wells.

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.