122 results about "Fracture conductivity" patented technology

The invention relates to the technical field of petroleum and natural gas engineering, in particular to a method, a system and equipment for acquiring artificial fracture parameters. The method comprises the following steps: acquiring initial fracture form data through a core experiment, wherein the initial fracture form data comprises the straightness, the branch number and the roughness parameter of a fracture; performing verification analysis based on morphology on the initial fracture morphology data, and adding morphological characteristics of irregular fractures to obtain fracture morphology data; according to the fracture form data, fracture conductivity simulation based on proppant distribution and stratum conditions is carried out, preliminary evaluation is carried out, and fracture conductivity data are generated; and carrying out dynamic adjustment processing based on crack pressure on the crack form data by using micro-seismic imaging to generate crack three-dimensional form model data. Through systematic core experiment and strict morphological verification, the obtained data has higher accuracy and reliability, and firm data support is provided for subsequent flow conductivity analysis and model construction.

The invention discloses a reservoir particle migration damage and crack filling layer composite damage productivity evaluation method, which comprises the following steps of: predicting the damage degree of reservoir particle migration to reservoir permeability and productivity through a particle migration permeability damage evaluation method of a loose sandstone reservoir under different production conditions; evaluating the fracture flow conductivity damage and productivity damage degree through a flow conductivity damage evaluation method under the compaction-embedding-blocking composite action of the fracturing filling well; reservoir particle migration damage and fracture conductivity damage are comprehensively considered, and dynamic productivity prediction and evaluation are achieved. According to the method, reservoir particle migration damage and fracture conductivity damage are comprehensively considered, the production time effect is considered, all-factor productivity dynamic prediction and evaluation are achieved, and optimization and implementation of particle migration and sand production control countermeasures are supported.

The invention discloses a deep coal and rock gas horizontal well pressure drainage working system optimization method and system, and the method comprises the steps: building a dynamic relation between the pressure drop and the flow of an oil nozzle based on a Gilbert model, and predicting the change of the gas-water ratio at different stages in combination with a double logarithmic segmentation fitting formula of the flow-back rate and the gas-water ratio; constructing a fracture quasi-steady-state flowing substance balance equation, and deducing an inflow dynamic curve of the flowing bottomhole pressure and the water yield; a Gray multiphase flow model is adopted to calculate the wellbore pressure gradient, and an outflow dynamic curve of the flowing bottomhole pressure and the liquid production capacity is generated; a reservoir, a shaft and an oil nozzle pressure system are coupled through a node system analysis method, an inflow-outflow coordination point is matched, and the size range of the oil nozzle is dynamically optimized. The method realizes accurate prediction and real-time regulation and control of drainage and mining parameters, solves the problem of rapid attenuation of fracture conductivity caused by high stress sensitivity of coal rocks, reduces the risk of pulverized coal blockage, improves the gas recovery efficiency, and is suitable for efficient development of deep coal rock gas wells.

The invention relates to the field of underground multi-physics field monitoring, in particular to an intelligent well completion underground multi-parameter fusion monitoring system, which comprises a functional casing acquisition module, an acoustic-electric-magnetic excitation module, an acoustic-electric-magnetic excitation module and a multi-parameter fusion monitoring module, wherein the functional casing acquisition module is integrated with a strain sensing element, a temperature sensing element, a stress sensing element and a resistivity sensing element; a double-domain inversion fusion module based on a multi-physics field equation and a graph time sequence causal network; the edge closed-loop regulation and control module adopts entropy modulation dual strategy reinforcement learning; and the communication interface has time slot encryption and version verification functions. According to the method, second-level data alignment, minute-level adaptive regulation and control and hour-level global optimization are realized, the crack conductivity is improved, the energy consumption is reduced, and yield increase and well completion integrity are considered.

Systems and methods are disclosed for determining a hydraulic fracture aperture within a subsurface region of interest. The methods may include obtaining, from a wellbore imaging tool, an image of a portion of a wellbore wall, wherein the wellbore penetrates the subsurface region of interest, obtaining, from a sonic logging tool, a full waveform sonic dataset for the portion, and identifying, using a well log interpretation system, a location of each member of a plurality of fractures in the image. The method may further include using a full waveform sonic processing system, for each member of the plurality of fractures, identifying a reflected sonic signal originating at the location of the fractures, and determining, from the reflected sonic signal, a hydraulic aperture.

Tuning fracture hydraulic conductivity can be provided so that high hydraulic conductivity in high temperature zones and low hydraulic conductivity in low temperature zones can be defined in enhanced geothermal systems (EGS). Uniform thermal gradient along flow paths can be provided or defined to help provide such conductivity zones. Experimentation performed to evaluate embodiments showed that embodiments could prevent appearance of dominant flow paths between the wells and maintain high heat extraction rates. Embodiments can greatly increase cumulative heat extraction. Embodiments can also be provided for application solely to the injection wells. Other embodiments can position tuning agents between the wells and still help provide control of the fluid flow in the reservoir and enhance heat extraction.

The invention discloses a shale gas reservoir proppant fracture conductivity testing device and a using method, and relates to the technical field of petroleum engineering, the shale gas reservoir proppant fracture conductivity testing device comprises a conductivity testing device and a data acquisition module, and the data acquisition module is used for acquiring pressure data, flow data and temperature data in the testing process of the conductivity testing device. Pressure, flow and temperature data in the testing process are accurately acquired through the integrated data acquisition module, the actual stratum condition can be comprehensively simulated by combining a pressure applying device, a fluid injection and output system and oil liquid supply with the adjustable temperature in the flow guide testing device, and meanwhile, the flow guide testing device can be used for testing the pressure, the flow and the temperature. Through the arrangement of the upper fixing plate and the pressure applying device, the upper simulation rock stratum and the lower simulation rock stratum are used for clamping the proppant, and the pressure sensor is arranged in the proppant layer in an embedded mode, so that accurate testing and analysis of the fracture conductivity of the proppant are achieved, and reliable data support is provided for effective development of a shale gas reservoir.

The invention discloses a global fracture conductivity ultra-long-term prediction method and system, belongs to the technical field of crossing of oil and gas reservoir engineering and artificial intelligence, and is used for solving the technical problem that the calculation cost is high when an existing physical model is used for predicting fracture ultra-long-term conductivity. The method comprises the following steps: generating a global fracture conductivity evolution data set covering multiple working conditions through a numerical simulation system; constructing a multi-channel input tensor containing dynamic fracture conductivity and static proppant concentration distribution; using the data set to train a plurality of Fourier neural operator models for different prediction time scales; and based on a hierarchical time sequence aggregation strategy, iteratively calling trained models of different time scales, and realizing rapid prediction of fracture conductivity in a few years to tens of years in the future. According to the method, on the premise of ensuring the prediction precision, the calculation time consumption of ultra-long-term prediction can be remarkably reduced, and decision support is provided for crack design and production strategy optimization.

The invention discloses a shale gas recoverable reserve calculation method and system, and relates to the technical field of shale gas exploitation calculation. The method comprises the following steps of fracturing construction data collection and fracture network three-dimensional modeling, fracture conductivity space distribution inversion, flow simulation and recoverable reserve calculation, inter-well interference effect quantitative correction and closed-loop verification and model parameter optimization. Through three-dimensional crack modeling, flow conductivity dynamic evaluation and inter-well interference correction, and in combination with a closed loop verification mechanism, the accuracy and reliability of recoverable reserve prediction are significantly improved; the invention provides a shale gas recoverable reserve calculation system based on the method, which comprises a data acquisition module, a crack modeling module, a flow simulation module, an inter-well interference correction module and a model verification optimization module, and realizes automation and intelligentization of the whole process from data input to result output. And the accuracy and reliability of shale gas recoverable reserve prediction are obviously improved.

A method of designing a multi-well fracturing operation comprising determining a probability of a large fracture stress extending from a treatment wellbore contacting an observation wellbore with a fracture model. The treating wellbore and the observation wellbore are arranged in a wellbore pattern within a subterranean formation. Determining with the fracture model a probability of a small fracture stress from a fracturing operation on the observation wellbore providing a threshold value of fracture conductivity to achieve a desired drainage radius for the observation wellbore. Outputting the treatment wellbore, the observation wellbore, the wellbore pattern, and the fracturing operation in response to the volume of fracturing fluid utilized in the observation wellbore being less than a threshold value.

The invention belongs to the technical field of reservoir transformation of oil and gas field development engineering, and particularly relates to an acid fracturing transformation method for a complex lithologic carbonate reservoir. According to the method, during acid fracturing construction, the fracturing fluid and the acid fluid are alternately injected for multiple times, on one hand, the reservoir temperature is reduced, the acid rock reaction rate is slowed down, and the effective action distance of acid etching is increased, and on the other hand, the fingering phenomenon of the acid fluid in the crack is formed, non-uniform etching is formed, and the flow conductivity of the crack is improved. The low-viscosity gelled acid has low viscosity and high acid rock reaction rate, the low-viscosity gelled acid is injected firstly, and the corrosion crack width can be further enlarged on the basis that early-stage fracturing fluid forms a long-distance fracturing crack; according to the method, the high-viscosity acid liquid is injected, then the high-viscosity gelled acid is injected, the characteristics that the high-viscosity acid liquid is high in viscosity, low in acid rock reaction rate and long in acid etching effective action distance can be utilized, on the basis of an existing crack channel, the acid liquid is communicated to a far-end grey matter / cloudy matter filling crack, and a corrosion crack net is formed in a long distance.

The invention constructs a fracture conductivity evaluation method considering shale hydration. The method mainly comprises the following steps: 1, carrying out a triaxial hydration creep mechanics experiment, establishing an elastic-viscoelastic-viscous plastic multi-stage creep constitutive equation based on triaxial experiment data, and analyzing shale elastic and viscous deformation mechanisms; 2, secondly, constructing a shale creep constitutive model by stages according to a stress threshold value, describing a viscoelastic stage by adopting an improved Burgers model, and establishing a viscoplastic strain equation based on an overstress theory; 3, coupling hydration action parameters to correct a shale creep equation, and quantifying the influence of hydration on rock modulus, viscosity coefficient and yield stress; 4, the creep strain and the crack dynamic width are correlated through a mathematical model, and a multi-field coupling relation is established in combination with a permeability evolution rule; and 5, finally constructing a fracture conductivity prediction model when the hydration effect is considered, and realizing fracture conductivity dynamic analysis under the hydration-creep synergistic effect. According to the method, the shale hydration-creep coupling effect is creatively fused into fracture conductivity prediction, and a quantitative tool is provided for shale reservoir long-term productivity evaluation.

The application discloses a kind of acquisition methods, devices, media and electronic equipment of complex fracture conductivity, and its method includes: (A) extracting the specific form of complex fracture formed in stratum by hydraulic fracturing, calculating the average filling concentration of proppant in complex fracture;(B) complex fracture is divided into multiple simple straight fracture units, and the closure stress suffered by each fracture unit in stratum is calculated;(C) carry out simple straight fracture conductivity experiment, obtain the change curve of fracture conductivity with closure stress, and the relationship between fracture conductivity and closure stress is fitted;(D) the fracture conductivity corresponding to each fracture unit is calculated;(E) the fracture conductivity of each fracture unit is used to calculate the conductivity of the whole complex fracture.The application principle is reliable, simple to operate, and has strong practicability, can more accurately obtain the conductivity of complex fracture formed by hydraulic fracturing, and then provide effective guidance for hydraulic fracturing construction effect evaluation.

The present application relates to oil and gas exploration technology field, disclose a kind of fracture conductivity test method and device of formation condition simulation, the present application is based on similarity criterion selects and actual reservoir and similar material of surrounding rock as model raw material, then according to design size manufacturing surrounding rock model and reservoir model with fracturing fracture;Reservoir model and surrounding rock model are assembled to form reservoir surrounding rock model, and fixedly placed on triaxial loading unit;Reservoir surrounding rock model, triaxial loading unit and fluid injection and monitoring unit and displacement detection unit are connected to form fracture conductivity test experimental device, finally based on the experimental device carries out the fracturing fracture conductivity test experiment of reservoir surrounding rock model, and calculates the fracture conductivity coefficient of model.The present application can more accurately simulate the deformation law of fracture in actual reservoir, provide more accurate parameters for oil and gas reservoir numerical simulation model, so as to more accurately evaluate and calculate gas well productivity.

The application provides a method and system for calculating the conductivity of a sand-acid fracturing reservoir simulation system, which comprises the following steps: constructing a simulation parameter combination set around sand-acid fracturing operation parameters for reservoir types with sand-acid fracturing requirements; analyzing fracture acid erosion data of different reservoirs by using a preset fracture acid erosion calculation model, and analyzing the embedding depth and deformation data of the proppant in combination with the injection rate parameters and the proppant data; further analyzing the sand concentration of sand-acid fracturing, and setting a rough body simulation distribution coefficient in combination with the injection rate, so as to form a reservoir fracture model that presents a real fracturing state; analyzing the permeability state of the reservoir fracture model after fracturing based on the rough body simulation distribution coefficient and the reservoir closure pressure; and further calculating the corresponding conductivity in combination with the fracture width calculated according to the fracture acid erosion data, the embedding depth and deformation data of the proppant. The method solves the problem that the sand-acid fracturing conductivity cannot be quantitatively analyzed, and provides support for field acid fracturing design and productivity prediction.

The invention relates to a nano tackifying fluid and supercritical CO2 fluid synergistic fracturing method. In the target stratum development area, nano tackifying fluid and supercritical CO2 fluid are adopted for collaborative fracturing, sand-carrying fluid and displacing fluid are combined to form a fracture network, and the corresponding relation between the construction parameter combination and the fracture flow conductivity and the corresponding relation between the construction parameter combination and the fracturing construction fluid amount are established; based on the corresponding relation, a multi-target optimization model with the fracture conductivity maximization and the fracturing construction liquid amount minimization as the target is constructed, and through population initialization, non-dominated sorting, crowding distance calculation, crossover variation selection and iterative updating, a construction parameter optimization result is output. The shale reservoir fracture flow conductivity and the fracture network complexity can be improved, the construction liquid amount is reduced, and the fracturing transformation effect and economical efficiency are improved.

The application provides a fracturing reconstruction method and application for ultra-deep high-stress reservoirs, and mainly aims to solve the problems of high fracture pressure, small reconstruction volume and low fracture conductivity of high-stress reservoirs. Specifically, the application analyzes the fracturing problems of the current ultra-deep high-stress reservoirs, points out the limitations of the current technical measures, and proposes a new fracturing reconstruction technology for high-stress reservoirs. The technology takes the pre-composite pressure reduction process, forced fracture expansion process and fracture effective support process as the core, solves the problems of difficult fracturing, difficult fracture expansion and difficult support of high-stress reservoirs, and has good application effect.

The invention belongs to the technical field of oil and gas exploitation engineering in the petroleum and natural gas development industry, and particularly relates to an integrity evaluation method and a validity period prediction method for a marine shallow soft natural gas hydrate reservoir fracturing filling crack system. The integrity evaluation method comprises the steps of building a fracture structure integrity evaluation index Ke, building a fracture sand blocking capacity evaluation index Kd, building a fracture flow conductivity integrity evaluation index Ks and building a natural gas hydrate fracture system integrity comprehensive evaluation index K. The systematic and quantifiable crack system integrity evaluation method is provided for ocean shallow soft natural gas hydrate reservoirs, and the crack flow conductivity, the structural stability and the sand blocking capacity of a fracturing filling sand control well can be comprehensively evaluated under the complex geological conditions and the dynamic production working conditions.

The invention discloses a numerical simulation characterization method and system based on a pressure-driving oil increasing mechanism of a low-permeability oil field, and relates to the technical field of oil-gas field development, and the method comprises the steps: building a fluid pressure-crustal stress-physical property coupling equation set based on the total stress tensor of a target low-permeability oil field, calculating a time-varying porosity field, a time-varying permeability field and pressure-driving fracture dynamic expansion parameters of the target low-permeability oil field; establishing a fracture conductivity attenuation function of the target low-permeability oil field based on fracture long-term conductivity test experimental data; respectively establishing a dynamic relative permeability curve control function and a dynamic capillary force curve control function of the target low-permeability oil field based on unsteady-state method relative permeability curve test experimental data and mercury injection experimental data; and establishing a numerical simulation model of the target low-permeability oil field, and performing numerical simulation characterization on the oil increasing mechanism in the pressure driving process of the target low-permeability oil field. The technical problem that in the prior art, coupling characterization means for various pressure-driving oil increasing mechanisms are lacked is solved.

This invention discloses an optimization method for flowback nozzles in deep coal and rock gas formations, considering the influence of multiple factors, belonging to the field of coal and rock gas extraction technology. Addressing the challenge of flowback fluid velocity control in deep coal and rock gas development, this method establishes models for matrix and fracture seepage and two-phase flow within the wellbore. It comprehensively considers the migration of pulverized coal and proppant, as well as the influence of coal seam cleavage fractures, to optimize wellhead nozzle size, reduce the probability of pulverized coal clogging fractures, and improve fracture conductivity. Compared to traditional methods, this invention has significant advantages in improving fracturing efficiency and high-efficiency coal and rock gas extraction, providing an innovative solution for the scientific research and engineering applications of deep coal and rock gas.

The invention provides an offshore bottom water thin mutual reservoir fracturing parameter design method, and relates to the technical field of oil and gas exploitation, the method comprises the following steps: S1, determining vertical distribution of a reservoir section mud layer, a sandstone layer and a water layer according to logging data, and establishing a target well section crustal stress and rock mechanics profile; s2, acquiring the fracture toughness of rocks with different shale contents under different stresses to obtain a corrected fracture toughness profile; s3, according to the fracture half length, the fracturing displacement, the critical mudstone layer penetrating thickness corresponding to the fracturing fluid viscosity and the penetrating layer fracture height of the reservoir are initially calculated, and parameters needed for avoiding a water layer and fully transforming a thin interbed are obtained; s4, according to the fracture flow conductivity, the sand amount and the sand-carrying fluid amount are calculated initially; s5, the liquid efficiency is determined according to block fracturing historical data, the prepad fluid proportion range is initially calculated, and the prepad fluid amount is calculated; and S6, optimizing parameters through numerical simulation, and determining final fracturing parameters and a pump injection program. According to the method, the requirements of geological and offshore construction can be met, and the optimal fracturing scheme and the optimal pumping program can be rapidly determined.

The application discloses a method, device and equipment for determining reservoir fracture conductivity, wherein the method comprises the following steps: acquiring fracture data of a target reservoir; determining a fracture width distribution result of a support fracture in the target reservoir based on the fracture data, wherein the fracture width distribution result comprises a continuous distribution result of a fracture width of the support fracture along a fracture length and a fracture height direction of the support fracture; and determining a conductivity distribution of the target reservoir based on the fracture width distribution result and a pre-determined mapping relationship between the fracture width and the conductivity, wherein the conductivity distribution represents a distribution of the conductivity of the support fracture of the target reservoir along the fracture length and the fracture height direction of the support fracture. The application can obtain a more accurate and reliable conductivity distribution, and can predict the conductivity of the support fracture in multiple dimensions, so that the prediction of the conductivity distribution is more comprehensive.

The application discloses a kind of oil and gas horizontal well segmented fracturing parameter optimization method, belong to the reservoir reconstruction technology field in oil exploitation, specifically includes the following steps: step 1: using reservoir numerical simulation method to optimize fracture half-length, fracture conductivity and fracture spacing;Step 2: using fracturing simulation method, fracture half-length and fracture conductivity under different fracturing parameter conditions are calculated;Step 3: according to the fracturing simulation result under different fracturing parameter conditions, fracture half-length and fracture conductivity box plot are drawn;Step 4: according to the result on box plot four digits, median and lower four digits, complete fracturing parameter optimization.The optimization method of the application can directly show the concentration degree and distribution of fracture half-length and fracture conductivity under different fracturing parameter conditions, so as to realize the reasonable optimization of horizontal well segmented fracturing parameter, lay a foundation for the technical personnel in the field to optimize process measures, obtain more reasonable fracture half-length and fracture conductivity, optimize development index.

The invention relates to the technical field of oil and gas field development engineering, and discloses a shale fracturing complex fracture conductivity determination method and device and electronic equipment, and the method comprises the steps: predicting a complex fracture distribution form of a target reservoir after hydraulic fracturing; establishing a proppant migration geometric model according to the complex fracture distribution form, and executing a proppant migration paving numerical simulation operation according to the proppant migration geometric model under preset geological factor conditions and preset engineering factor conditions to obtain a numerical simulation result; according to a numerical simulation result, the complex crack area is divided into an effective supporting crack area and a self-supporting crack area; according to a preset effective support fracture conductivity calculation model, a preset self-support fracture conductivity calculation model and the numerical simulation result, the fracture conductivity of the effective support fracture area and the fracture conductivity of the self-support fracture area are determined respectively. According to the method, the flow conductivity of the whole deep shale complex fracture system can be obtained more accurately.

The invention provides a method and a device for determining the long-term flow conductivity of a carbonate rock acid-etched fracture. The method comprises the following steps: acquiring mineral composition, porosity, permeability, formation Young modulus, formation closing stress, formation Poisson's ratio, acid liquor concentration and temperature of rock in a work area; determining a damage factor of the acid etching crack based on rock mineral composition, porosity, permeability, Young modulus, acid liquor concentration and temperature; based on the formation Young modulus, the closing stress, the Poisson's ratio and the acid rock reaction rate, the fracture width change of the acid-etched fracture surface after acid etching is determined; based on the initial fracture width, the Young modulus, the Poisson's ratio and the damage factor, the creep quantity of the acid etching fracture conductivity is determined; and finally, the long-term flow conductivity is determined through the crack width and the formation creep after acid etching. According to the method, lithology, stratum physical properties, rock mechanics parameters, acid etching damage and creep effect are comprehensively considered, and the flow conductivity of the acid etching crack can be rapidly and accurately determined.

The application provides a method and device for determining long-term conductivity of acid-etched fractures in carbonate rocks. The method comprises: obtaining rock mineral composition, porosity, permeability, formation Young's modulus, formation closure stress, formation Poisson's ratio, acid concentration and temperature; determining the damage factor of acid-etched fractures based on rock mineral composition, porosity, permeability, Young's modulus, acid concentration and temperature; determining the change in acid-etched fracture width after acid etching of the fracture surface based on formation Young's modulus, closure stress, Poisson's ratio and acid-rock reaction rate; determining the creep variable of acid-etched fracture conductivity based on the initial fracture width, Young's modulus, Poisson's ratio and damage factor; and finally, determining the long-term conductivity by the fracture width after acid etching and the formation creep variable. The method comprehensively considers lithology, formation physical properties, rock mechanics parameters, acid etching damage and creep effect, and can quickly and accurately determine the conductivity of acid-etched fractures.

The application discloses a kind of EGS grading support agent regulation fracture conductivity and interwell communication method, belong to geothermal resource development field, including the following steps: S1: fracture network partition and conductivity design: based on the geomechanical parameter of target dry hot rock reservoir, geothermal field distribution and well layout, with injection well and production well as center, the fracturing influence area of injection well and production well is divided into near well high conductivity area, transition regulation area and far well communication area;Injection well and production well far well communication area interpenetration forms interwell continuous conductivity channel.The application constructs gradient conductivity fracture network, solves the problem of traditional EGS single support agent high temperature conductivity attenuation, interwell flow dead zone, early heat breakthrough, realizes long-term stability of fracture conductivity, improves interwell communication and heat extraction efficiency, delays heat breakthrough, applicable to deep high temperature dry hot rock artificial thermal reservoir construction.

Tuning fracture hydraulic conductivity can be provided so that high hydraulic conductivity in high temperature zones and low hydraulic conductivity in low temperature zones can be defined in enhanced geothermal systems (EGS). Uniform thermal gradient along flow paths can be provided or defined to help provide such conductivity zones. Experimentation performed to evaluate embodiments showed that embodiments could prevent appearance of dominant flow paths between the wells and maintain high heat extraction rates. Embodiments can greatly increase cumulative heat extraction. Embodiments can also be provided for application solely to the injection wells. Other embodiments can position tuning agents between the wells and still help provide control of the fluid flow in the reservoir and enhance heat extraction.

The application provides a heterogeneous reservoir acid fracturing parameter design method and system, the method constructs an acidification reconstruction geometric model for a reservoir to be reconstructed, introduces required acidification section length and section thickness data to calculate acid liquid flow rates in fractures under different construction discharge capacities in combination with fracture attribute data, further considers acid etching reaction rates and mass transfer coefficients to calculate acid concentrations on inner walls of fractures reacted with a reservoir matrix, determines etching widths of natural fracture walls according to attribute parameters of the reservoir matrix, further calculates reservoir etching volumes corresponding to different construction acid amounts and acid etching fracture widths and lengths, finally decides corresponding acid etching fracture conductivity capacities according to a correction principle of an N-K model, and selects optimal acid injection parameters according to preset optimization conditions. By using the scheme, the problems of small calculation scales and complicated operations in the prior art are effectively overcome, analytical solutions are flexibly used in the calculation process, and an acid injection scheme with optimal acid etching effects and conductivity capacities is accurately and efficiently selected.

The invention provides a new tight oil fracturing transformation production prediction method based on modern yield decline analysis. The new tight oil fracturing transformation production prediction method based on the modern yield decline analysis comprises the steps that 1, the development condition of a fracture section is determined according to the geological characteristics of a reservoir, the reservoir fracturing transformation construction condition and microseism observation data; step 2, establishing a fracture physical model after pressure transformation; 3, establishing a matrix system mathematical model; 4, establishing a seepage mathematical model of the hydraulic fracturing system; 5, establishing a relation between the fracture conductivity and time, space and stress sensitivity; and step 6, carrying out model fitting and model solving. According to the new tight oil fracturing transformation production prediction method based on modern yield decline analysis, the influence of the space-time heterogeneity of the fractures on the production speed is considered, the method is suitable for modern yield decline analysis of the space-time heterogeneity of the fractures for tight reservoir fracturing transformation, and the fractures and reservoir parameters can be well explained.