87 results about "Tight gas" patented technology

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 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 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 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.

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 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 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 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.

The invention discloses a tight gas well unstable open-flow capacity evaluation method based on production dynamic data, and belongs to the technical field of gas reservoir engineering. The method comprises the following steps: firstly, collecting tight gas well production dynamic data and basic parameters and preprocessing; then, a deconvolution algorithm and a Duhamel principle are introduced, and variable-yield variable-pressure data are standardized into constant-pressure variable-yield data; then, in combination with a gas reservoir seepage differential equation considering natural gas compressibility, a'bottom hole flowing pressure-yield-time 'relation model is established; a yield-time function is reversely deduced, the bottom hole flowing pressure is made to be 0, and the unstable open-flow capacity is calculated; and finally, drawing a change curve, analyzing a dynamic rule and a decline mechanism, and providing reference for development countermeasures. The method realizes efficient utilization of production dynamic data, accurately captures an open-flow capacity decline rule, improves evaluation precision and timeliness, reduces cost, is suitable for unconventional gas reservoirs such as tight gas reservoirs, and provides support for efficient development of the gas reservoirs.

This invention discloses a method and equipment for evaluating tight reservoir gas well parameters based on stress sensitivity, including: acquiring actual production data of the gas well; determining the reservoir stress sensitivity coefficient; obtaining a normalized production-mass balance pseudo-time curve, a normalized production integral-mass balance pseudo-time curve, and a normalized production integral derivative-mass balance pseudo-time curve considering stress sensitivity; fitting the above three curves to a typical curve chart for production instability analysis to determine the time shift, production shift, and position number; obtaining the dynamic reserves of the first gas well and the second gas well; using the average of the dynamic reserves of the first and second gas wells as the dynamic reserves of the gas well under the mutual constraint of the flow mass balance method and the chart fitting method; and calculating reservoir parameters and fracture parameters. This invention enables accurate evaluation of parameters such as dynamic reserves of gas wells in low-permeability tight gas reservoirs, and can conveniently, quickly, accurately, and effectively evaluate gas well parameters and reservoir parameters.

The invention discloses a tight gas reservoir prediction method for calculating formation pressure based on basin simulation, relates to the field of oil-gas exploration, and solves the problem that existing tight gas is difficult to benefit exploration and effectively use. The method comprises the following steps: S1, carrying out statistics on actually measured formation pressure data in a research area, and judging whether an overpressure gas reservoir condition exists in the area or not; s2, stratum paleo-pressure is recovered through inclusion calculation; s3, determining an overpressure formation mechanism on the basis of drilled data in the research area, and establishing a relational expression between the existing gas reservoir resource quantity or single well yield and pressure; s4, establishing a basin simulation model through basin simulation; and S5, dividing an overpressure area on the basis of the basin simulation model, and predicting a gas reservoir enrichment area in an overpressure environment. According to the tight gas reservoir prediction method for calculating the formation pressure based on basin simulation, gas reservoir enrichment prediction is carried out through basin pressure simulation and by applying the current formation residual pressure, a high-yield and stable-yield tight gas reservoir can be found, and the benefit gateway is broken through.

The utility model relates to the technical field of gathering and transportation pipeline maintenance, and provides an auxiliary device for tight gas ground gathering and transportation maintenance, which comprises a door-shaped frame and a mounting plate, two control grooves matched with each other are formed in the inner side wall of the door-shaped frame, and first threaded rods are rotatably connected in the control grooves; the top ends of the two first threaded rods penetrate through the control groove to be connected with chain wheels, a chain is in transmission connection between the two chain wheels, the two first threaded rods are in threaded connection with first threaded parts, a mounting plate is connected between the two first threaded parts, and a second servo motor is mounted at the top end of the mounting plate. The output end of the second servo motor penetrates through the mounting plate and is connected with a control box, a two-way threaded rod is rotationally connected to the interior of the control box, two corresponding second threaded parts are in threaded connection to the two-way threaded rod, and the bottom ends of the two second threaded parts penetrate through the control box and are connected with clamping parts, so that the pipeline is prevented from accidentally moving; therefore, the purpose of improving the equipment stability is achieved.

This invention discloses a method for determining the upper limit of water saturation in tight gas reservoirs using two-phase permeability analysis, comprising: 1. Selecting several rock samples for gas-water two-phase permeability analysis, and establishing a gas-water phase permeability curve based on the relative permeability of the water phase, the relative permeability of the gas phase, and the water saturation value of each rock sample; 2. Based on the gas-water phase permeability curve, first reading the water saturation value of each rock sample when the relative permeability of the water phase is a set value A, then reading the relative permeability of the gas phase corresponding to the same water saturation value of each rock sample, and determining the upper limit of water saturation for each rock sample accordingly; 3. Calculating the average value of the upper limit of water saturation for each rock sample, and the obtained average value is the upper limit of water saturation for the tight gas reservoir. This invention can accurately determine the upper limit of water saturation in tight gas reservoirs using relatively simple means, simplifying the determination process and improving accuracy compared to existing technologies, providing an accurate basis for the rational exploitation of tight gas reservoirs.

The invention relates to the technical field of tight gas reservoir development, and discloses a composition for pickling blockage removal, which is characterized in that the composition for pickling blockage removal comprises acid, a water block removal agent and phosphate, wherein the water lock removing agent comprises a fluorocarbon surfactant, a polyether surfactant and a silicon ion type surfactant. The composition for pickling and blocking removal can efficiently remove a mud cake blocking barrier formed between a tight gas reservoir seepage channel and a shaft, so that the permeability is improved, the water blocking removal agent can interact and synergistically interact, and the capillary pressure of water is greatly reduced; and water blocking damage caused by percolation of drilling fluid and spontaneous imbibition of capillary force of a tight gas reservoir in the drilling process is eliminated.

The invention discloses a T2 spectrum form correction method, device and equipment in a tight gas reservoir oil-based mud invasion state and a storage medium, and relates to the technical field of logging data processing in oil-gas exploration. The method comprises the following steps: firstly, acquiring T2 spectrum data of to-be-corrected oil-based mud in a research area in an invasion state, secondly, decomposing the T2 spectrum data by utilizing a T2 spectrum decomposition method combining wavelet transform and Gaussian fitting, and determining a T2 spectrum correction equation by utilizing a fluid replacement method based on a decomposition result; and correcting T2 spectrum data to be corrected in an oil-based mud invasion state by using the obtained T2 spectrum correction equation. According to the method, many problems brought to NMR logging fluid identification after the oil-based mud invades the stratum can be solved more comprehensively and effectively, and more reliable and accurate technical support is provided for tight gas reservoir fluid identification work.

The utility model provides a leakproof gas purification device which comprises a purification tank body supported by supporting legs and a tank cover detachably fixed at the top of the purification tank body, a sealing ring is fixed on the inner wall of the tank cover, the sealing ring is sleeved with a gas inlet pipe fitting in an interference mode through a sealing strip on the inner side of the sealing ring, a support is fixed on the outer wall of the gas inlet pipe fitting, and the gas inlet pipe fitting is sleeved with a gas outlet pipe fitting. A telescopic device is fixed to the outer wall of the support through bolts, the telescopic end of the telescopic device is fixed to the outer wall of the top of the tank cover through bolts, and liquid alloy is arranged in the purification tank body; the gas impurity concentration after impurity removal is monitored by arranging the sensor assembly, and the depth of the gas inlet pipe fitting extending into the liquid alloy is controlled by utilizing the expansion of the expansion piece, so that the depth of the gas inlet pipe fitting can be controlled according to the comparison between the monitoring result and the required impurity concentration; on the basis that reliable impurity removal is guaranteed, the situation that the insertion depth of the air inlet pipe fitting is large, and the energy consumption rate is increased due to large air inlet resistance can be prevented.

This application provides a method, system, and equipment for predicting the dynamic reserves of tight gas wells in sandstone lenses, relating to the field of oil and gas field development technology. This application calculates the average daily gas production in the first year of a typical gas well in a target well area using unobstructed flow data from multiple first reference gas wells. By acquiring production data from the reference gas wells and analyzing their decline patterns, a decline characteristic curve for the typical gas well is obtained. Based on the decline characteristic curve, the annual decline rate parameter is determined, and a EUR evaluation model is constructed by combining the average daily gas production in the first year and the annual decline rate. Finally, the cumulative gas production of the target gas well is calculated based on the EUR evaluation model, thereby determining its dynamic control reserves, improving the accuracy of production prediction and reserve estimation for tight gas wells in sandstone lenses.

The invention discloses a genetic algorithm-based tight gas reservoir horizontal well fracturing section automatic division method. The method comprises the following steps of S1, determining a reasonable fracturing section division principle; s2, performing quantitative expression on the key parameters of the fractured section of the tight gas reservoir horizontal well; s3, acquiring continuous parameter values of the key parameters of the target layer section of the horizontal well according to the logging curve data, and respectively constructing a porosity vector, a Young modulus vector, a Poisson's ratio vector and a minimum horizontal principal stress vector of each fracturing section; s4, taking the standard deviation minimization of the attribute values of the fracturing sections as an optimization target, and establishing a mathematical model for dividing the fracturing sections of the single well; and S5, fracturing section division is converted into an optimization problem, and a genetic algorithm (GA) is adopted for efficient solving. According to the method, automatic division of the tight gas reservoir horizontal well fracturing sections can be rapidly and efficiently achieved, balanced crack initiation of hydraulic fractures is facilitated, the fracturing effect is improved, and tight gas reservoir development is optimized.

The application discloses a novel method and device for calculating dynamic reserves of a gas well in a tight gas reservoir, and the method comprises the following steps: S1, acquiring daily production data of the gas well; S2, drawing a time-yield curve and a material balance time-yield curve; S3, judging whether there is a straight line with a slope greater than -1 in the time-yield curve and the material balance time-yield curve and whether the two straight lines are parallel to each other; S4, if it is judged that there is, judging whether the time-yield curve or the material balance time-yield curve is offset; S5, if it is judged that the curve is offset, extracting an offset point as a boundary flow critical time point t c ; S6, extracting a time-daily production sequence after the boundary flow critical time point t c ; S7, performing logarithmic transformation on the time and the daily production; S8, judging whether the logarithmically transformed time-daily production is in a linear relationship, and further determining a formula for calculating the dynamic reserves of the gas well. The application solves the problem that the calculation result of the dynamic reserves of the gas well in the tight gas reservoir is inaccurate.

The invention discloses an interface wetting regulator for tight gas reservoir water control fracturing and a preparation method of the interface wetting regulator. The preparation method comprises the following steps: S100, carrying out acidolysis on cellulose; s200, carrying out a hydrothermal reaction on the cellulose acidolysis product and a Gemini surfactant; and S300, compounding a quaternary ammonium salt cationic surfactant with a product obtained in the step S200 to obtain the interface wetting regulator for water control fracturing of the high-temperature and high-salt tight gas reservoir. The interface wetting regulator for water control fracturing of the high-temperature and high-salt tight gas reservoir, prepared by the preparation method provided by the invention, has multiple adsorption sites and high surface performance, is stronger in adsorption on the rock surface, has good wetting performance, and can convert a hydrophilic surface into a neutral wetting state and reduce the water phase permeability. Meanwhile, the surface tension is low, the flowback rate of fracturing fluid can be increased, and water control fracturing yield increase of tight gas reservoirs is achieved.

The application is suitable for the technical field of oil and gas field stimulation and reconstruction, and provides a gas reservoir water lock releasing method based on adsorption-desorption dynamic balance regulation and control. The method first injects a low-concentration water lock releasing agent solution into a reservoir to form a non-saturated adsorption layer; then, a high-concentration water lock releasing agent is injected in a slug mode, and the surfactant component is redistributed and rearranged on the interface driven by the concentration gradient; by controlling the residence time, the interface molecules are partially desorbed and re-adsorbed to establish adsorption-desorption dynamic balance; combined with injection parameter window regulation and control, the periodic reconstruction of the interface structure and the release of water lock are realized. Through the synergistic mechanism of "staged injection-concentration gradient-residence regulation", the surfactant component presents a dynamic conversion behavior, effectively weakens the stability of the water film and promotes the release of bound water. The application does not depend on the structure of a specific chemical agent, has wide application range and strong interface regulation and control capability, and is suitable for the release of water lock in low-porosity and low-permeability and tight gas reservoirs.