163 results about "Tight gas" patented technology

The invention provides an analysis method for multi-cluster fracturing crossing in a horizontal well section of a sand shale reservoir, which comprises the following steps of: based on a boundary element theory, considering three-dimensional fracture stress interference and flow distribution of each cluster, and establishing a full-three-dimensional fracture propagation numerical model of segmented multi-cluster fracturing stress interference and flow distribution of a tight gas horizontal well; coupling the wellbore flow model and the crack propagation numerical model through bottom hole pressure to obtain a coupling model; based on a three-dimensional boundary element theory, aiming at the coupling model, discretizing different fracture forms into rectangular units, and establishing a three-dimensional boundary element stress interference calculation model through a superposition principle; under the condition that geological factors are kept constant, the influence of different construction parameters on crack propagation and layer crossing behaviors is analyzed, a crack layer crossing main control factor is obtained, and the conditions and boundaries of segmented multi-cluster fracturing layer crossing of the sand-mud interbed horizontal well are determined. The method provides a basis for optimization of crack parameters and construction parameters.

The invention discloses an EUR prediction model construction method and system of a tight gas reservoir gas well, and relates to the field of oil and gas field development technology and artificial intelligence cross technology, and the method comprises the steps: collecting multi-source data; screening the multi-source data by adopting a three-level feature screening method, and removing redundant features; constructing a heterogeneous integrated model comprising a plurality of machine learning models, inputting the screened features into the heterogeneous integrated model to carry out EUR prediction, obtaining respective prediction errors of different machine learning models, correcting each EUR prediction result based on the prediction errors in combination with a material balance equation MBE, a yield attenuation model DCA and fracture network simulation, and carrying out EUR prediction. And carrying out weight distribution on each machine learning model after the EUR prediction result is corrected by adopting an error reciprocal weighting method to generate a final combined EUR prediction model. According to the method, an optimization strategy combining data driving and physical constraint is adopted, and the precision and reliability of EUR prediction are improved.

The invention provides a tight gas and deep coal bed gas collaborative exploitation simulation experiment device. The tight gas and deep coal bed gas collaborative exploitation simulation experiment device is composed of a shaft simulation device, a reservoir simulation device, a gas-liquid two-phase flow supply device and a control system. The casing pipe is provided with a plurality of transparent converging sections, and the oil pipe can be downwards inserted to different layers. And the gas-liquid two-phase flow supply device is provided with a plurality of groups of independent gas-liquid conveying manifolds which are respectively connected with each convergence section of the sleeve through the reservoir simulation device, so that the independent regulation and control of seepage parameters and production pressure difference of each layer are realized. The control system integrates pressure and flow acquisition and image recording functions, monitors and analyzes data in real time, is used for simulating an interlayer coupling relationship, a mutual interference mechanism and dynamic productivity response during multi-layer commingling production, and provides an experimental basis for collaborative production layer strategy optimization.

The invention relates to a novel gas lift process design method based on hydrops dynamic change. The problems that in the current tight gas exploitation field, the gas lift injection amount is unreasonable, and the gas lift duration is too long are solved. According to the technical scheme, the method comprises the steps that the relation between the liquid amount, the gas amount and the injection duration and the relation between the liquid amount, the gas amount and the starting pressure are judged through field working parameters, the injection working gas amount suitable for the current is obtained, gas lift is stopped when a gas well can carry liquid for production, and the total gas lift duration is obtained; according to the method, the invalidation of the gas lift process is avoided, the optimal injection duration and the total injection gas amount under the effective gas injection amount are determined, and the purposes of reducing cost and increasing efficiency can be achieved by real-time self-regulation and popularization and implementation on site editing programs.

The invention provides a productivity evaluation method for a tight gas reservoir horizontal well, and relates to the technical field of tight gas reservoirs, and the method comprises the following steps: obtaining well logging sensitive parameters and rock mechanical parameters of the tight gas reservoir horizontal well; based on the logging sensitive parameters and a comprehensive index model, comprehensive indexes corresponding to different reservoirs in the horizontal well are calculated; based on the comprehensive index, the logging sensitive parameter and the rock mechanical parameter, determining a geological dessert level and an engineering dessert level corresponding to the reservoir; and carrying out productivity evaluation on the horizontal well based on the geological dessert level and the engineering dessert level corresponding to the reservoir. Therefore, the geological sweet spots can be accurately identified based on different data dimensions through the comprehensive indexes determined by the logging sensitive parameters having great influence on lithology and the logging sensitive parameters, collaborative evaluation is performed through the geological sweet spots and the engineering sweet spots, the reservoir capacity and the transformation capacity of the reservoir capacity are considered at the same time, and the accuracy of capacity prediction is remarkably 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 discloses a spontaneous imbibition gas production method and system for a tight gas reservoir, particularly relates to the technical field of yield increase in oil-gas field development, and is used for solving the problem of gas flow channel blockage caused by mismatching of liquid phase suction and gas output time sequences in a soaking process in the prior art. According to the method, a dynamic balance mechanism of imbibition power and gas output power is established, double chemical agents are adopted to cooperatively regulate and control the imbibition process and gas flow channel maintenance, and the well opening opportunity is accurately determined based on the pressure recovery feature recognition technology to achieve efficient gas phase replacement of the tight gas reservoir. Firstly, reservoir rock physical property parameters and fluid property parameters are obtained, a dynamic equilibrium coefficient is calculated, and the optimal concentration of a first chemical agent and the optimal concentration of a second chemical agent are determined; injecting the chemical agent into the fracturing fluid for hydraulic fracturing, and shutting in the well for soaking, so that the chemical agent forms a wetting modified layer and an interfacial tension adjusting film in the reservoir; the characteristic points established by the gas-phase flow channel are identified by monitoring a pressure recovery curve, and production is started to realize efficient gas recovery.

The invention relates to the field of unconventional oil and gas field development, in particular to a model and a method for evaluating damage of fracturing fluid to a tight gas reservoir, the model for evaluating damage of fracturing fluid to the tight gas reservoir is manufactured and comprises a micro-etching matrix model and a micro-etching crack model, nitrogen and fracturing fluid filtrate are injected, injection pressure and model images are recorded, and the model is used for evaluating damage of fracturing fluid to the tight gas reservoir. Calculating the damage degree of the fracturing fluid to the tight gas reservoir matrix; replacing the microcosmic etching matrix model with a microcosmic etching crack model, injecting nitrogen and fracturing fluid gel breaking fluid, recording injection pressure and a model image, and calculating the damage degree of fracturing fluid residues to tight gas reservoir cracks. A reusable microscopic visual etching model is established to simulate a tight gas reservoir, and on the basis of the model, a corresponding evaluation test program is established to evaluate fracturing fluid reservoir damage, so that the technical problems that in the prior art, test fluid is not representative, damage mechanism evaluation is insufficient, errors are large, and repeatability is poor are solved.

The invention discloses a tight gas reservoir fractured horizontal well non-uniform transformation reserve evaluation method, and relates to the field of oil and gas field development. According to the method, a fractured horizontal well non-uniform transformation concept physical model is established, a rectangular closed reservoir fractured horizontal well non-uniform transformation reservoir unstable seepage mathematical model is established and solved, and a fracture model is coupled to obtain a bottom hole pressure asymptotic solution and a quasi-steady state bottom hole pressure asymptotic solution of the unstable seepage mathematical model; according to the method, actual production data are processed to draw a quasi-steady state productivity index curve and a Blasingame yield decline curve, and an actually measured curve is dragged to be compared with a theoretical curve, so that dynamic reserve calculation and inversion of the width and permeability of each sub-region are realized, namely, the permeability and the transformation range of each section of transformed reservoir are obtained through chart fitting; and the reserve evaluation accuracy is improved.

The invention relates to a tight gas reservoir fracturing dessert prediction method and device, electronic equipment and a medium, and belongs to the technical field of hydraulic fracturing of petroleum and natural gas engineering.The method comprises the steps that historical values of reservoir parameters and dessert evaluation parameters are obtained; calculating a difference matrix of each reservoir parameter and the dessert evaluation parameter based on historical values of the reservoir parameters and the dessert evaluation parameter, calculating a correlation degree of each reservoir parameter and the dessert evaluation parameter based on the difference matrix, and selecting a target parameter of which the correlation degree is greater than a threshold value from the reservoir parameters; training the initial lightweight gradient elevator model based on the target parameters and the dessert evaluation parameters to obtain a completely trained lightweight gradient elevator model; and predicting the dessert based on the lightweight gradient elevator model which is completely trained. According to the method, the target parameters are screened from the aspect of trend matching, the non-linear relation between the target parameters is processed through the lightweight gradient elevator model, and high-precision sweet spot prediction is achieved.

The invention provides an adsorption performance evaluation device of a gas tracer for fracturing monitoring and a use method. The adsorption performance evaluation device comprises a methane supply unit, a tracer injection unit, a standard gas preparation unit and a core unit, the methane supply unit and the tracer agent injection unit are connected with the standard gas preparation unit; the standard gas preparation unit is connected with the core unit. The adsorption performance evaluation device is reasonable in design, the using method is easy to operate, adsorption performance evaluation of the core gas tracer agent under different conditions can be achieved, and data support is provided for application of the gas tracer agent in coal bed gas, tight gas and shale gas fracturing.

The invention discloses a quantitative evaluation method for the reservoir capacity of a tight gas reservoir, and relates to the field of petroleum and natural gas engineering. The method comprises the following steps: preparing a standard rock core, and obtaining Young modulus of the rock core, mineral types and mineral Young modulus and mineral percentage content of various minerals; minerals in the standard rock core are classified to obtain dragged minerals, raised minerals and mixed minerals; obtaining the limit Young's modulus and the percentage content of the dragged mineral, the percentage content of the mixed mineral and the percentage content of the drawn mineral of the dragged mineral and the drawn mineral; determining a reservoir capacity index, and evaluating the reservoir capacity of the reservoir corresponding to the standard core; and performing reservoir grading on the reservoir based on the reservoir capacity. The method provided by the invention is simple and feasible, has good adaptability to the mine field, also greatly reduces the test expenditure of the mine field, and has good application prospect and popularization value for similar tight gas reservoirs.

The invention discloses a method for judging the full life cycle production stage of a horizontal tight gas well, and belongs to the field of gas reservoir engineering. For a horizontal tight gas well, a seepage mathematical model considering multiple sections of fracturing cracks is constructed, model solving is achieved through a semi-analytical method, a gas well full-life-cycle seepage law curve with pressure and a pressure derivative curve as reference is drawn, and a judgment method for dividing different life stages is established according to curve characteristics. According to the method, main control factors influencing occurrence and ending of life stages are defined, and a calculation method for occurrence time of each life stage is constructed, so that the life stage of the horizontal tight gas well and the future development life of the horizontal tight gas well are evaluated, and a theoretical reference is provided for efficient development of tight gas reservoirs.

The invention discloses a method and a device for determining a gas reservoir water plugging and pore plugging radius boundary based on a capillary tube bundle, and the method is characterized in that the method comprises the following steps: collecting physical property data of a tight gas reservoir, and obtaining a capillary tube bundle pore diameter sample set; according to the capillary tube bundle pore diameter sample set, single-tube gas-water two-phase flow is calculated one by one; accumulating the single-tube gas-water two-phase flow to obtain the total flow of a capillary tube bundle under different water saturations, and obtaining a simulated water-gas ratio according to the total flow of the capillary tube bundle; according to the simulated water-gas ratio, obtaining a global optimal solution of the maximum permissible plugging pore radius; and obtaining a field recommendation scheme according to the global optimal solution of the maximum allowable plugging radius. According to the method, the critical plugging aperture under different reservoir conditions can be accurately identified, and the gas production capacity and the water control effect are effectively considered.

The present invention provides a method for optimizing the production and control of the same layer in a low-permeability tight gas reservoir, belonging to the technical field of oil and gas field development. First, the present invention constructs a reservoir parameter matrix, conducts stress sensitivity and starting pressure gradient tests, solves the equation by means of Laplace transform and Fourier series iteration method, calculates the drainage radius of each well, and constructs a drainage field description function. The well spacing coefficient is calculated according to the drainage radius of adjacent wells and the actual well spacing, and the pressure reduction wells, pressure increase wells and normal development wells are divided. The bottom hole flowing pressure is adjusted at a gradient of 0.1 MPa, the gradient projection optimization function is applied to calculate the optimal adjustment scheme, the well spacing coefficient and well type are re-evaluated, and a pressure stable change index is constructed. Iterative adjustment is carried out until all wells are normal development wells, or the area requiring densification is identified. Finally, the recommended bottom hole flowing pressure of all wells after optimization and control is obtained, and the balanced utilization of the reservoir and the optimization of production capacity are realized.

A core permeability testing device and method are disclosed, belonging to the technical field of oil and gas field development. The testing device includes a core holder for holding the core to be tested; a constant temperature chamber for providing the testing environment temperature, which is equal to the temperature of the tight gas reservoir; the core holder and the core to be tested are placed inside the constant temperature chamber; a confining pressure loading pump for applying confining pressure to the core holder, the magnitude of which is equal to the pressure of the overlying strata of the tight gas reservoir; and a high-pressure gas cylinder for pressurizing a standard container, which is connected to the core holder. The standard container forms upstream and downstream pressures applied to the core holder according to the formation pressure of the tight gas reservoir. The core permeability under temperature, pressure, and saturation conditions is obtained by measuring and calculating. The testing device of this invention has a simple structure, and only pressure needs to be measured during the testing process, without the need to measure flow rate, which can effectively improve the evaluation effect of tight gas reservoir permeability.

The invention discloses a tight gas fiber sand fracturing optimization design method and system, and the method comprises the steps: employing a numerical simulation technology, taking the reservoir transformation volume and the crack complexity as optimization targets, and carrying out the optimization to obtain fracturing construction parameters; under the optimized fracturing construction parameters, indoor experiments are carried out, and the fiber type, the use amount, the pump injection mode and the like which have the minimum influence on the backflow capacity of a proppant filling layer and have the optimal sand prevention effect are determined, so that the whole process of tight gas fiber sand fracturing is optimized, the sand production rate is effectively reduced, the backflow capacity of a crack is guaranteed, and the fracturing efficiency is improved. And the reservoir transformation effect is improved to the maximum extent, the yield is increased, and the cost is reduced.

The present invention discloses a method and device for predicting liquid accumulation in tight gas wells. The method includes: obtaining production data of the tight gas well to be predicted, preprocessing the production data of the tight gas well to be predicted, and performing normalization processing on the preprocessed production data of the tight gas well; dividing the normalized production data of the tight gas well into multiple subsequences according to time, inputting them into the trained liquid accumulation prediction model, and obtaining a liquid accumulation prediction result, where the liquid accumulation prediction result includes a predicted value or confidence interval of the liquid accumulation. This method combines the LSTM and Informer methods for predicting liquid accumulation in tight gas wells, can quickly and effectively predict the liquid accumulation situation in tight gas wells, combines the advantages of the LSTM model and the Informer model, and realizes high-precision short-term and long-term time series prediction.

The embodiment of the invention provides a method for simulating full-life-cycle gas-water occurrence and utilization of a low-permeability tight gas reservoir, and belongs to the technical field of gas reservoir development. The method comprises the following steps: constructing an online nuclear magnetic core displacement experimental device; debugging test parameters of the online nuclear magnetic core displacement experiment device; according to the online nuclear magnetic core displacement experimental device, gas-water occurrence and dynamic changes of a reservoir forming stage, a depletion exploitation stage and a gas injection recovery efficiency improving stage are continuously simulated for a core. According to the method, the gas-water occurrence and dynamic change characteristics in the full life cycle process of low-permeability tight gas reservoir filling reservoir forming-depletion exploitation-gas injection recovery efficiency improvement can be accurately described from the microscopic angle, and technical support is provided for deployment and adjustment of a gas reservoir development scheme and optimization of technical measures for gas injection recovery efficiency improvement in the later development period.

The application discloses a novel compact gas reservoir gas well reasonable production allocation method and system based on stable production period, and the reasonable production allocation method comprises the following steps: S1, obtaining the production-time data of a target gas well, and arranging the production-time data according to the production size in a power reduction manner; S2, calculating the matter balance time-production data of the production data arranged in the power reduction manner; obtaining the maximum matter balance time according to the matter balance time-production data; S3, judging the relationship between the stable production time and the maximum matter balance time, and then substituting the stable production time into the matter balance time data according to the matter balance time-production data to obtain the reasonable working system of the target gas well at the stable production time. The method depends on the static data and dynamic data in the gas well production data, effectively reduces the cost of a large number of experiments and dynamic monitoring required by other methods, can quickly determine a reasonable production allocation scheme, and realizes efficient and stable exploitation of the gas well.

The invention relates to the technical field of abnormal high-pressure formation pressure calculation, in particular to an abnormal high-pressure tight gas well formation pressure calculation method and device. The method comprises the following steps: acquiring gas well data of a target gas well in an abnormal high-pressure state, and calculating first formation pressure; calculating a real-time compression factor based on the gas well data and the first formation pressure; calculating a second formation pressure based on the real-time compression factor and the first formation pressure; and performing iterative optimization on the second formation pressure according to the first formation pressure and a preset comparison threshold value to obtain target formation pressure. According to the embodiment of the invention, the calculation precision of the formation pressure of the abnormal high-pressure gas well can be greatly improved.

The present application relates to the technical field of oil and gas field development, in particular to a kind of calculation method of reserve control degree of multi-layer superimposed tight gas reservoir.A kind of calculation method of reserve control degree of multi-layer superimposed tight gas reservoir, the reserve control degree of gas reservoir=(the control reserves of all gas wells-intersection control reserves-waste control reserves) / geological reserves of gas reservoir.The present application establishes a kind of calculation method of reserve control degree of multi-layer superimposed tight gas reservoir, considers the difference of different production layer control radius and control reserves, and has important guiding significance to the effective development of multi-layer superimposed gas reservoir.

The invention provides a tight gas reservoir fractured horizontal well fracture parameter optimization method, system and equipment. The method comprises the steps that a river channel sand body space distribution model is determined according to geological parameters; determining a channel sand body heterogeneous attribute model according to the horizontal shaft parameters and the channel sand body spatial distribution model; determining an actual gas reservoir numerical simulation model of the heterogeneous river channel sand body according to the simulation production dynamics determined by the horizontal shaft parameters, the working system parameters and the heterogeneous attribute model of the river channel sand body and the actual production dynamics corresponding to the parameters; determining a heterogeneous river channel sand body crack parameter optimization mathematical model; and establishing a gas reservoir numerical simulation model considering the spatial distribution characteristics and the heterogeneous characteristics of the river channel sand body through the micro-seismic interpretation picture and the logging interpretation data of the river channel sand body of the target gas reservoir. Through fracturing fracture parameter optimization, the cumulative gas production rate is maximized, optimal matching between fracture parameters and sand body distribution is achieved, and effective guidance is provided for efficient development of tight gas reservoirs.

The invention provides a tight gas reservoir gridding evaluation method, system and device and a storage medium, and the method comprises the steps: obtaining dynamic and static data of a target block, the dynamic and static data comprising geological data and production dynamic data; geological reserve gridding parameters are determined based on the geological data, and the geological reserves are gridded; determining the dynamic reserves of each well in the target block based on the production dynamic data, and meshing the dynamic reserves of each well; calculating the unused reserves and the ratio of the dynamic reserves to the static reserves of the target block grid by grid based on the geological reserve gridding and the dynamic reserve gridding of each well; and obtaining a gas reservoir evaluation result based on the unused reserves and the dynamic and static reserve ratio. According to the method, fine evaluation and infilled well arrangement of the tight gas reservoir are achieved, well pattern infilled evaluation refinement is high, calculation is convenient, and the method has great significance in development evaluation of the tight gas reservoir, development scheme compiling, recovery ratio improving countermeasure making and the like.

The application discloses a kind of considering the dynamic change of water saturation tight gas reservoir productivity calculation method.This application method is by selecting multiple core samples, combined with the geological data of research area, using the way of steady state method and seepage method, experimental measurement each core sample under different water saturation conditions Start-up pressure gradient and gas-water relative permeability, dynamic start-up pressure gradient empirical formula is established, according to the gas-water relative permeability of each core sample under different water saturation conditions, the gas-water ratio of each core sample is calculated, and based on the physical model of tight gas reservoir fracturing horizontal well and considering the mathematical model of one-way shale gas reservoir fracturing horizontal well, the productivity model of tight gas reservoir fracturing horizontal well considering gas-water two-phase is established, and the IPR curve considering the dynamic change of start-up pressure under different water saturation conditions is obtained.The application realizes the accurate calculation of the productivity of tight gas reservoir, and lays a foundation for the development of tight gas reservoir.

The application discloses a method, device, equipment, medium and product for predicting fracture complexity of a tight gas reservoir section. The method comprises the following steps: determining a first fracture complexity index according to physical property parameters of cores of the tight gas reservoir section; determining an interlayer fracture mutual influence coefficient according to P-wave data of each layer in the tight gas reservoir section; and determining fracture complexity of the tight gas reservoir section according to the first fracture complexity index, the interlayer fracture mutual influence coefficient and the P-wave data of each layer in the tight gas reservoir section. The technical scheme can shorten the prediction period of the fracture complexity of the tight gas reservoir section, reduce the cost of predicting the fracture complexity of the tight gas reservoir section, and improve the accuracy of the predicted fracture complexity of the tight gas reservoir section.

The present invention provides a favorable reservoir identification method based on double occlusion, including: obtaining logging curves, performing outlier processing and normalization processing on them, and conducting histogram analysis to obtain the histogram distribution ranges of sandstone, mudstone, coal seam and limestone. Conducting histogram analysis on the natural gamma logging curve, combining the logging curve with seismic data, and performing waveform indication inversion to obtain a longitudinal wave impedance inversion body. Based on the natural gamma logging curve and the post-stack seismic data volume, performing waveform indication simulation to obtain a GR data volume, combining the waveform indication to invert the longitudinal wave group antibody, performing lithology occlusion processing on the GR data volume to obtain a sand-mudstone lithology body, obtaining a porosity body, and occluding the porosity body through the sand-mudstone lithology body to obtain a favorable reservoir body with high porosity. The favorable reservoir identification method based on double occlusion provided by the present invention improves the accuracy of lithology prediction effect and can provide a reliable geological basis for tight gas exploration.

The invention relates to the technical field of petroleum and natural gas development, in particular to a method for rapidly evaluating the well control gas-bearing area of a compact gas field, which comprises the following steps of: according to plane well position coordinates of gas wells in a research block, taking a well point gas release range as a clustering range; establishing a coordinate set of single wells on a plane, performing clustering to obtain a cluster set, calculating intersection points of all well control ranges for each well in each cluster in the cluster set on the basis of the well control range of the current well by using an operation principle of plane geometry, and obtaining a plane control range of a current cluster object; calculating the plane control ranges of all clusters in sequence to obtain the plane control range of the current research area; according to the method, the problems of low efficiency of manually drawing the plane well control gas-bearing area and large batch modification workload in the traditional compact gas field development determination process are solved, and the workload of a compact gas field development engineer for evaluating the gas field development degree can be greatly reduced.

The application discloses a method and equipment for predicting production decline of a tight gas horizontal well with a variable decreasing exponent, and a storage medium, and comprises the following steps: collecting historical gas production data of a target well; performing nonlinear regression analysis by taking a dimensionless time function as an independent variable and taking a logarithmic value of the production as a dependent variable, and determining a second key undetermined parameter and a linear expression by a characteristic curve fitting method; substituting the parameter and a theoretical initial production into a formula to obtain a time-varying prediction model of the gas well production; comparing and analyzing measured data in the field to obtain an absolute error value; if the absolute error value is greater than an absolute error threshold value, the next step is performed; repeating the steps based on historical gas production data of a measure section to obtain a time-varying prediction model of the gas well production of the measure section. The application can more accurately represent an actual percolation law of the tight gas reservoir, and the theoretical calculation result is more in line with a dynamic material balance principle of the gas reservoir, thereby providing a new theoretical basis and technical means for optimizing a development scheme of the tight gas horizontal well.

The invention provides a method for improving the productivity of a tight gas reservoir horizontal well, and relates to the technical field of tight gas reservoirs, and the method comprises the following steps: obtaining well logging sensitive parameters and rock mechanical parameters of the tight gas reservoir horizontal well; based on the logging sensitive parameters and a comprehensive index model, comprehensive indexes corresponding to different reservoirs in the horizontal well are calculated; based on the comprehensive index, the logging sensitive parameter and the rock mechanical parameter, determining a geological dessert level and an engineering dessert level corresponding to the reservoir; and on the basis of the geological dessert level and the engineering dessert level corresponding to the reservoir, the fracturing transformation parameters of the horizontal well are optimized with the purpose of improving the productivity of the horizontal well. Therefore, the geological dessert is accurately identified through different data dimensions, and the fracturing transformation parameters of the horizontal well are optimized through the geological dessert and the engineering dessert, so that a customized parameter optimization scheme can be provided for fracturing construction of the horizontal well, fracturing energy and a propping agent are ensured to be efficiently put into a layer section with high gas yield potential, and the fracturing efficiency of the horizontal well is improved. And the productivity of the horizontal well can be obviously improved.