607 results about "Shale gas" patented technology

The invention discloses a shale gas well dessert prediction method and device based on integrated learning. The method comprises the steps of obtaining main control factors and feature data of a shale gas well to be predicted, and inputting the main control factors and the feature data into a trained dessert prediction model to obtain dessert prediction data; the model training process comprises the following steps: determining main control factors influencing the dessert according to the correlation between each parameter in the prediction data of the sampled shale gas well in the target area and the dessert; the prediction data comprises first data and second data, the first data comprises geological data, perforation data and oil and gas production data, and the second data comprises logging data and fracturing construction data; performing feature extraction on each parameter in the second data to obtain feature data; constructing a training data set according to the main control factors and the characteristic data of the shale gas well; and training the dessert prediction model based on the training data set. The accuracy of a prediction result can be improved, and fracturing design is effectively guided.

The invention relates to the technical field of oil development, in particular to a shale oil and gas fracturing sliding sleeve capable of being opened and closed repeatedly and a using method. According to the technical scheme, a central pipe fracturing liquid inlet is formed in the upper side of a central pipe, and a reversing rail is arranged on the surface of the outer wall of the middle; a sealing cylinder sleeve and a one-way circulating valve carrier are sleeved outside the central pipe, a fracturing piston, a swivel pressing cap and a reset spring are installed in an annulus, a constant-pressure opening cavity is formed in the inner wall of the fracturing piston, a swivel is installed in the swivel pressing cap, a track pin is installed in the swivel, and the position is moved along a reversing track on the surface of the outer wall of the central pipe through the track pin. The fracturing piston moves downwards to the position of the cylinder sleeve fracturing liquid outlet under the action of pressure, the fracturing function is started, fracturing liquid is sprayed out along the cylinder sleeve fracturing liquid outlet to enter a target fracturing layer, fracturing construction of a plurality of fracturing layers can be achieved through multiple times of fracturing liquid injection and injection stopping, the fracturing sliding sleeve can be repeatedly opened and closed, and the fracturing construction efficiency is improved. And fracturing construction requirements of shale oil and gas with different layers can be met.

The invention provides a method for preferably selecting a shale gas structure storage favorable area not based on formation pressure. The method comprises the steps that a target research area is selected, and a core exploration target layer series is determined; on the basis of a target stratum shale gas preservation mechanism, core parameters independent of stratum pressure data are screened, and a comprehensive evaluation index system containing target stratum self-sealing performance, regional cover stratum conditions and structural transformation action parameters is constructed; spatial distribution analysis is carried out on each parameter, grading is carried out according to geological laws and adjacent region experience, and weight coefficients are distributed according to the influence degree of the parameters on storage conditions; obtaining a comprehensive score of the structure storage condition of each evaluation unit through grade assignment and weighted stacking calculation; and delineating a shale gas structure storage favorable area according to the comprehensive score. The method is suitable for low-exploration-degree areas with complex structures, sparse drilling wells or lack of formation pressure data, and has the advantages of objective evaluation, high operability and high practical value.

The invention relates to the technical field of drilling compositions, in particular to a composite plugging agent, a plugging composition and plugging cement paste for shale gas formation cracks. The composite plugging agent for shale gas stratum cracks is composed of a bridging material, a filling material and an end-capping material, the mass ratio of the bridging material to the filling material to the end-capping material is (1.2-1.4): 0.5: (0.1-0.3), the bridging material is organic fibers with the length of 3-5 mm, the filling material is composed of inert particles with the particle size of 35-280 [mu] m and micro-silicon with the particle size of 0.15-1 [mu] m, and the end-capping material is a mixture of silicon oxide and silicon oxide. The end-capping material is composed of organic fibers with the length of 8-9 mm and walnut shells with the particle size of 3-5 mm. Through compounding of different types of bridging materials, filling materials and end sealing materials and grading of fibers with different lengths and plugging particles with different particle sizes, the plugging agent can be matched with cement paste in complex cracks and large cracks (1-4 mm) of a stratum to form a stable and compact plugging layer, the compressive strength is high, effective retention is achieved, and the effect of plugging a complex leakage layer is achieved.

The invention discloses a shale gas well fracturing parameter optimization design method and system based on a depth Q network, and relates to the technical field of shale gas development, and the method comprises the following steps: S1, collecting geological parameters, fracturing construction parameters and productivity data of a shale gas well in advance; s2, constructing an agent model and performing environment simulation; and S3, constructing a DQN model. According to the method, a LightGBM algorithm is adopted to construct a data-driven proxy model to simulate a real fracturing environment, an optimization model is constructed based on a deep Q network (DQN), state, action, reward and epsilon-greedy strategies are defined, and technologies such as a variable step size search mechanism, experience playback and target network soft update are combined, so that the real fracturing environment is simulated. The problems that a traditional optimization method is weak in local search capability and low in convergence speed are effectively solved, multivariable synchronous optimization of the unit perforation length proppant dosage and the fracturing fluid dosage is achieved, and a global optimal parameter combination can be rapidly explored.

The invention belongs to the technical field of petroleum and natural gas exploration and development, and particularly relates to a coiled tubing bottom seal dragging pressure testing and leakage finding packer and a using method thereof, and the pressure testing and leakage finding packer comprises an upper centralizer, a pressure balancing mechanism, a setting packing mechanism and a lower centralizer which are coaxially and sequentially connected in a threaded mode. The pressure balance mechanism comprises a sleeve shell assembly and a pressure relief assembly. A pressure relief opening is formed in the side face of the sleeve shell assembly, and the pressure relief assembly is arranged in the sleeve shell assembly. The setting packing mechanism comprises a central pipe; a rubber sleeve assembly, a slip assembly and a centralizing assembly are sequentially installed on the basis of the center pipe from top to bottom, the rubber sleeve assembly is movably connected with the center pipe in an axial limiting mode, the slip assembly is fixedly connected with the centralizing assembly, and the centralizing assembly is movably connected with the center pipe based on the track pipe groove. According to the technical scheme, pressure bearing reasons and leakage point positions which cannot be found out by dragging pressure testing for multiple times in one-time well entering can be achieved, and it is guaranteed that follow-up fracturing construction operation of the shale gas well is safely and efficiently carried out.

The invention relates to a shale or coal rock gas evaluation method based on a gas-water two-phase flow isotope fractionation model. The shale or coal rock gas evaluation method comprises the following steps: 1, collecting data; 2, establishing a gas well model; 3, establishing a control equation set; 4, coupling the influence of the real gas effect and the effective stress; 5, establishing a gas transmission model and a relative permeability model; 6, establishing a relation between capillary pressure and saturation; 7, considering critical desorption pressure; 8, setting boundary conditions of initial conditions; 9, solving a control equation set; 10, calculating production dynamic parameters and isotope values; 11, performing history fitting; 12, verifying historical fitting quality; 13, predicting productivity; 14, calculating a gas dynamic output proportion; 15, identifying a fractionation inflection point and gas production mechanism conversion; by coupling gas-water two-phase flow, multiple gas transmission mechanisms, stress sensitivity and methane isotope competitive adsorption theories, yield prediction of the deep reservoir and quantitative evaluation of the dynamic proportion of produced gas are realized.

The invention provides a shale gas well inter-well pressure channeling identification method, system, device and medium, the shale gas well inter-well pressure channeling identification method comprises the following steps: carrying out well test analysis in a pump stop pressure drop stage after fracturing, and collecting data; the bottom hole pressure is calculated, and pressure data oscillation caused by the water hammer effect is eliminated; drawing a pressure difference and pressure difference derivative double logarithmic curve based on the bottom hole pressure data; establishing a shale gas well non-uniform fracture multi-zone coupling well test seepage model; the model parameters are adjusted, a pressure difference and pressure difference derivative double logarithmic curve is fitted, and when the model result is close to the drawn pressure difference and pressure difference derivative double logarithmic curve, the crack parameters of the model parameters are obtained through inversion; judging whether the crack parameter is too high or not; and determining the relationship between the child well group and the mother well group, analyzing the pressure difference and pressure difference derivative curve morphological characteristics of the fracture parameter high section, and judging whether pressure channeling occurs or not. The system can realize the method. According to the method, the inter-well pressure channeling identification efficiency in the well group synchronous fracturing period can be improved.

The invention discloses a shallow shale gas self-sealing reservoir formation identification method, which comprises the following steps: firstly, carrying out dual-energy CT scanning on a shale full-diameter core sample to obtain DEI values, and the difference of the DEI values embodies different lithologic (physical property) longitudinal change rules, i.e., different shale lithologic grain interlayer interlayers, different shale lithologic grain interlayer interlayers, different shale lithologic grain interlayer interlayers, different shale lithologic grain interlayer interlayers, different shale lithologic grain interlayer interlayers, and different shale lithologic grain interlayer interlayers; the development of the top and bottom plates of the high-quality shale reservoir enables the shale gas to have a self-sealing reservoir forming characteristic; then simulating the adsorbability of the shale gas through laboratory thermal cracking to obtain a shale gas adsorbability rule, and identifying whether the shale gas has a self-sealing reservoir forming characteristic or not. And finally, measuring the distribution rule of the microscopic porosity and the pore diameter through a scanning electron microscope, judging whether the shale layer is a non-or ultra-low permeability layer under the formation temperature and pressure condition or not, and identifying whether the shale gas has the self-sealing reservoir forming characteristic or not. According to the method, the self-sealing reservoir forming of the shale gas is identified in multiple aspects, and the method provides effective technical support for evaluating the favorable layer section of the shale and is of great significance in improving the exploration and development effect of the shale gas.

The invention provides a method for determining the filling concentration of a foam scrubbing agent in the full life cycle of a shale gas well foam scrubbing process, and relates to the field of gas well drainage gas recovery processes. The influence of high pressure on the using effect of the foam scrubbing agent is considered, a liquid holdup and frictional resistance pressure drop model of the using coefficient of the foam scrubbing agent is introduced, a shaft outflow curve under different foam scrubbing agent concentrations is drawn, the initial filling point of the foam scrubbing agent is determined, and the gas well formation pressure is determined on the basis of the change relation of the gas well formation pressure along with time. And extrapolating to obtain the production time corresponding to different formation pressures, and finally obtaining the change relation of the optimal filling concentration of the foam scrubbing agent along with the corresponding production time under different formation pressures, thereby determining the filling concentration of the foam scrubbing agent in the full life cycle of the gas well. According to the method, the influence of the pressure and the foam scrubbing agent concentration on the shaft pressure drop and the liquid holdup is fully considered, the reasonable filling concentration of the foam scrubbing agent at different production times in the full life cycle of the gas well is determined, and an important theoretical support is provided for optimization of a foam scrubbing agent filling system of a shale gas well foam scrubbing process.

The invention relates to the technical field of shale gas development underground water monitoring, and discloses a shale gas development area deep underground water environment intelligent monitoring and early warning method. According to the method, a dynamic simulation model of a deep groundwater environment is constructed based on geological structure characteristics and historical environment data of a shale gas exploitation area, and a basic framework is provided for subsequent analysis. And then, acquiring a groundwater environment real-time monitoring data set including water quality concentration, water level fluctuation and soil seepage rate through a preset monitoring well array, and realizing comprehensive capture of groundwater environment information. Then, the real-time monitoring data set is imported into the dynamic simulation model for calibration, and it is ensured that the model can accurately reflect the actual situation. And then operating the calibrated model, simulating the migration process of the pollutants in the underground water, and outputting a risk prediction value. And finally, comparing the risk prediction value with a preset safety critical value, and generating an early warning instruction according to a result.

The invention relates to the technical field of oil and gas field surface engineering, and discloses a compressor distribution and working condition parameter planning optimization technology in a shale gas pressurization process, and an optimization method comprises the following steps: establishing a mathematical model for accurately describing pipe network pressure loss and compressor operation power; the outlet pressure of each intermediate booster stage is defined as a decision variable, and a nonlinear programming model with the lowest system total power or the lowest full life cycle cost as an objective function is constructed; solving the model by adopting a global optimization algorithm to obtain a group of optimal intermediate interstage pressure values; and by analyzing the optimal solution, determining an optimal compressor physical distribution scheme and accurate working condition parameters of each stage of compressor under the scheme. According to the method, a complex engineering planning problem is converted into a mathematical problem with a clear solving path, a global optimal planning scheme considering technology and economy can be provided for the shale gas pressurization system, and the energy consumption and total cost of the system are remarkably reduced.

The invention provides a shale fracture attribute inversion method based on clay matrix dominant azimuth distribution correction, which utilizes an azimuth distribution function to describe the influence of directional arrangement of a clay matrix part on rock anisotropy, and meanwhile, utilizes an improved anisotropic matrix Eshelby-Cheng model to simulate the influence of a horizontal fracture. According to the method, a shale rock physical model considering directional arrangement and horizontal cracks of a clay matrix part at the same time is constructed, shale reservoir crack attributes and anisotropy parameters are estimated in combination with logging information, and in the inversion process, a simulated annealing particle swarm optimization (SA-PSO) is used for improving the solving capacity of a non-linear objective function. According to the method, the influence of anisotropy caused by directional arrangement of the clay matrix on fracture attribute inversion can be reduced, the accuracy of shale reservoir fracture attribute estimation and anisotropy parameter inversion is improved, and development of a shale gas resource exploration and development technology is assisted.

The invention relates to a reservoir compressibility evaluation method and system considering shale formation development characteristics, and belongs to the field of shale oil and gas development geology. Comprising the following steps: 1, performing experimental research on the influence of shale formation development characteristics on mechanical properties; 2, researching the influence of the shale formation on the tensile property; 3, researching the influence of the shale formation on the compressive property; step 4, performing a longitudinal fracturing fracture network layer-crossing physical simulation experiment considering the strata stress barrier belt; 5, longitudinal fracturing crack net layer-penetrating finite element numerical simulation considering the strata stress barrier belt is carried out; 6, researching the influence rule of the lamina development characteristics on the hydraulic fracture crossing behavior; 7, establishing a fracturing performance evaluation index of the shale reservoir; and step 8, evaluating the combination distribution position of the dominant lamina of the target block and the compressibility of the reservoir. According to the method, the reserve utilization rate, the recovery rate and the yield rate of shale gas development are maximized, and theoretical basis and technical support are provided for efficient development of shale gas reservoirs.

The invention discloses a shale gas exploration method, device, equipment and medium, and relates to the technical field of shale gas exploration and development, and the shale gas exploration method comprises the following steps: obtaining respective mass fractions of long quartz minerals, clay minerals and carbonate minerals of a shale reservoir in each well section of a current well, determining the maximum difference degree index, the local onrush characteristic index and the relative change amplitude index of the corresponding mineral content of the shale reservoir in each well section based on each mass fraction, and constructing a comprehensive heterogeneity index representing the shale reservoir in each well section; the porosity, the water saturation and the total gas content of the shale reservoir in each well section are obtained, so that the initial sweet spot grade of each well section is divided; performing grade correction on the initial dessert grade of the corresponding well section according to each comprehensive heterogeneity index to obtain a target dessert grade corresponding to each well section after correction; and determining a well track optimization scheme and a fracturing design scheme based on the target dessert grade so as to carry out corresponding shale gas exploration operation. And accurate shale gas exploration is realized.

The invention relates to the technical field of nuclear magnetic resonance logging, aims to solve the problem that a method for jointly correcting a nuclear magnetic resonance logging T2 spectrum by integrating multiple factors does not exist at present, and provides a gas-containing shale nuclear magnetic resonance relaxation time spectrum correction method, a storage medium and a device. The method comprises the steps of obtaining target layer information; determining a T2 spectrum correction position; factors influencing the difference between the nuclear magnetic porosity and the conventional logging porosity are analyzed, and the influence of the factors on the nuclear magnetic resonance logging T2 spectrum is corrected according to the factors; respectively fitting each spectrum peak of the T2 spectrum through a Gaussian distribution curve, completing correction of each factor on the spectrum peak, and obtaining a final corrected nuclear magnetic offset T2 spectrum; superposing the porosity components of the corrected T2 spectrum Gaussian distributions of the fluid peaks at the corresponding distribution points to obtain corrected effective porosity and total porosity; according to the invention, automatic correction of the nuclear magnetic resonance logging T2 spectrum can be realized.

The invention provides a shale primary formation water ion composition evaluation method and device. The method comprises the following steps: acquiring ion composition and tritium content of flow-back fluid in at least one time after hydraulic fracturing of a target well section of a target shale gas well; the ion composition and the tritium content of fracturing fluid used for hydraulic fracturing of the target well section of the target shale gas well are obtained; on the basis of the obtained tritium content of the flow-back fluid at each time and the tritium content of fracturing fluid used for hydraulic fracturing of the target well section of the target shale gas well, the mixing proportion of formation water in the flow-back fluid at each time is determined; and determining the ion composition of the formation water of the target well section of the target shale gas well by combining the determined mixing proportion of the formation water in the flow-back fluid at each time based on the obtained ion composition of the flow-back fluid at each time and the obtained ion composition of the fracturing fluid at each time. According to the method, the water ion composition of the primary formation of the shale reservoir can be accurately determined by utilizing the fracturing flow-back fluid ion content and tritium nuclide characteristics.

The invention belongs to the field of carbon dioxide geological sequestration and oil-gas field development, and relates to a shale carbon dioxide adsorption expansion damage experiment method considering a hydration state, which comprises the following steps: processing a shale sample according to requirements; the shale is subjected to constant-humidity regulation and control pretreatment, and in the process, different relative humidity environments can be used for pretreatment, so that the influence of different clay mineral hydration interlayer spacing states on adsorption expansion is obtained; soaking the pretreated shale in supercritical carbon dioxide, adsorbing the sample when the temperature and pressure conditions reach a set value, soaking until the rock sample reaches adsorption saturation, and treating by using carbon dioxide with different pressures and temperature gradients; according to collection of sample microstructure and mechanical data, damage can be treated through crack initiation position comparison, porosity and gray scale quantitative analysis and macro-mechanical parameter evolution. The method provides an experimental method for carbon dioxide geological sequestration safety assessment and shale gas fracturing parameter optimization.

The invention relates to the technical field of shale identification, in particular to a shale gas sweet spot self-adaptive identification and optimization prediction method based on machine learning, which comprises the following steps of: identifying a reservoir physical property mutation interface in a well depth direction, and performing discontinuous layer section division based on a brittleness evolution trend, the discontinuous interval division is used for generating an unsteady reservoir unit set; a machine learning model with stage perception ability is constructed by introducing a jump type productivity criterion, a dessert score body with hierarchical constraint is output, and the dessert score body represents a productivity potential level and an activation probability of each reservoir unit; and correcting the dessert score body by using model residual feedback, and outputting a final dessert prediction map with unsteady features and interlayer differential expression ability. According to the method, the attention mechanism is introduced to enhance the recognition of the key productivity transition stage, so that the accurate prediction of the productivity response of the reservoir unit is realized.

The invention provides a logging data preprocessing system and a logging data preprocessing method. The logging data preprocessing system comprises a data standardization module, a rock core homing module, a lithology identification module, a mineral composition identification module, a porosity calculation module and a fracturing performance evaluation module. A continental facies shale gas logging comprehensive evaluation technical system is innovatively constructed through the technical means of logging curve standardization processing, core depth homing, multi-parameter lithology identification, nonlinear mineral component fitting, porosity model establishment, rock mechanical brittleness evaluation and the like. According to the method, the well logging interpretation coincidence rate is remarkably increased, shale gas exploration and development are effectively guided, key technical support is provided for well drilling fracturing and gas testing operation of a field test well, and remarkable economic benefits and application value are achieved.

The invention relates to the technical field of shale gas development, and provides a shale reservoir permeability determination method and device based on a sequential inversion algorithm. The method comprises the following steps: acquiring geological engineering data of a target well and historical shale gas well production data; according to the geological engineering data, establishing a shale gas well fracturing model corresponding to the target well; establishing a gas reservoir fitting model corresponding to the target well by using historical shale gas well production data; carrying out production simulation on the shale gas well fracturing model by utilizing the gas reservoir fitting model under preset initial parameter conditions and constraint conditions to obtain production simulation data; based on the production simulation data, establishing a pressure-saturation nonlinear partial differential equation of the two-dimensional two-phase gas reservoir; and performing iterative inversion on the pressure-saturation nonlinear partial differential equation in a numerical discretization manner by using a sequential inversion algorithm to obtain the permeability of the target shale reservoir. According to the embodiment of the invention, the permeability of the shale reservoir can be efficiently and accurately calculated.

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 molecular simulation-based method for estimating CO2 / CH4 adsorption capacity in a shale reservoir, which comprises the following steps of: firstly, selecting different mineral components from the shale reservoir, and determining reservoir temperature and pressure corresponding to each mineral component; the method comprises the following steps: constructing molecular models of different mineral components in a shale reservoir and a to-be-detected gas molecular model by using molecular simulation software, and carrying out geometric optimization; setting temperature and pressure conditions conforming to the actual reservoir in the simulation environment, and introducing gas molecules to perform molecular dynamics simulation so as to research the competitive adsorption behavior and obtain adsorption quantity data; based on simulation data, an adsorption capacity calculation expression comprehensively considering the coupling influence of multiple factors such as temperature and pressure is established, and the actual shale reservoir gas adsorption capacity is rapidly and accurately estimated. Through molecular simulation, the limitation that a traditional experiment is long in period, high in cost and difficult to separate multi-factor influences is overcome, and an efficient and reliable theoretical tool is provided for shale gas reserve prediction and carbon dioxide geological storage benefit evaluation.

The utility model relates to an anti-blocking well drilling sleeve joint, and belongs to the technical field of well drilling sleeve joints. The anti-blocking drilling casing joint comprises a first pipeline, a threaded lantern ring, a first joint, a second joint and a second pipeline, one side of the first pipeline is in meshed connection with the first connector through threads, the connection strength and the sealing performance are guaranteed, the end face of the first connector is machined through a mirror face machining technology, the flatness of the attaching face of the first connector and the second connector is high, and detention of rock debris is effectively reduced, and right-handed spiral flow guide lines are formed in the inner walls of the first pipeline, the second pipeline and the connectors. The thread sleeve ring is made of a duplex stainless steel material, trapezoidal threads matched with external threads of the second connector are machined on the inner wall of the thread sleeve ring, pre-tightening force is applied through rotary meshing, the compression amount of the sealing ring is accurately increased, and the self-cleaning sealing ring is particularly suitable for a shale gas horizontal well. And the rock debris passing efficiency is greatly improved compared with that of a traditional connector.

The present disclosure relates to a method and apparatus for long-term productivity forecasting of a shale gas well, and a device. The method comprises: on the basis of target fracturing treatment pumping parameters and formation parameters of a formation where a non-producing well is located, performing fracturing simulation on the non-producing well to obtain fracture parameters of the non-producing well; on the basis of well parameters and the fracture parameters of the non-producing well, calculating a shale gas reservoir reserve of the non-producing well; on the basis of actual long-term productivity values of multiple producing wells within the formation, respectively calculating a single-well utilization ratio of each producing well, constructing posterior distribution of the single-well utilization ratios, and on the basis of the Markov chain Monte Carlo sampling method, determining a target single-well utilization ratio value; and on the basis of the shale gas reservoir reserve of the non-producing well and the target single-well utilization ratio value, calculating a long-term productivity prediction value of the non-producing well, such that workers can develop the non-producing well on the basis of the long-term productivity prediction value, thereby fully developing formation resources, and improving the overall efficiency of shale gas development.

The application provides a method and device for establishing a fine choke system in a middle-deep shale gas horizontal well flowback stage, and the method comprises the following steps: S100, collecting original data of a research area; S200, calculating a production pressure difference corresponding to different choke sizes; S300, obtaining a stress sensitivity curve of the production pressure difference corresponding to different choke sizes; S400, obtaining artificial fracture parameters through history matching; S500, establishing a flowback model; S600, establishing a flowback numerical model; and S700, analyzing based on a numerical simulation result of the flowback numerical model. The application solves the problem that a field horizontal well flowback system lacks theoretical support and technical guidance, can reduce the influence of stress sensitivity damage, support agent backflow and embedding, and ground process erosion or blockage in the flowback process, and lays a foundation for maximizing the productivity of a shale gas well.

The invention discloses a deep shale gas production system optimization method based on a multistage splitting optimization strategy. The method comprises the following steps: S1, collecting and sorting geological parameters and engineering parameters of a target block; s2, establishing a deep shale gas reservoir numerical simulation model according to the basic parameters, and correcting the numerical simulation model by using historical production data; s3, a production system optimization objective function is constructed, constraint conditions in the objective function comprise a daily gas production threshold value, and an optimization variable is the flowing bottomhole pressure; s4, the shale gas production system mathematical model is solved through a coupling optimization algorithm and an oil reservoir numerical simulator, and the optimal production system of first-generation regulation and control is obtained; and S5, based on the optimal production system of the first generation of regulation and control, generating an optimal production system of the next generation of regulation and control by using a multi-stage splitting optimization strategy, and carrying out dynamic regulation and control optimization of the production system in the whole life cycle. According to the method, a multi-stage splitting optimization strategy is adopted, and a scientific and efficient optimization method is provided for optimization of a shale gas production system.

The application discloses a platform circulating gas lifting intelligent optimization and edge control coordination method, which comprises the following steps: step one, single-well gas lifting dynamic curve drawing; step two, multi-target optimization model establishment; step three, gas injection parameter optimization and dynamic adjustment; and step four, circulating gas lifting intelligent control. Through the construction of an integrated technical system of "single-well dynamic modeling-multi-well coordinated optimization-edge intelligent control", the global optimal distribution of the gas injection amount is realized through a two-stage optimization framework and a particle swarm algorithm, the coupling interference problem existing in the multi-well platform is solved, real-time response is realized through edge control, and the production reduction and shutdown caused by liquid accumulation are avoided. The application can realize the accurate control of the circulating gas lifting process and the maximum yield target, and provides a reliable technical path for intelligent drainage gas production of shale gas fields.

The present application relates to the technical field of shale gas sampling, in particular to a shale gas exploitation sampling device and method, the device comprises a box body and an inspection door, a filter box is arranged in the upper middle part of the box body, a low-temperature box is arranged in the lower middle part of the box body, an adsorption box is arranged in one end of the box body, a shunt pipe is arranged on the inner wall of the bottom end of the low-temperature box, a cooling mechanism for low-temperature water removal is arranged in the low-temperature box, a filtering mechanism for automatic filtering and automatic cleaning is arranged in the filter box, an adsorption mechanism for adsorption is arranged in the adsorption box, and a connecting mechanism for connecting a sampling pipeline is arranged in one end of the box body. The device can be suitable for sampling pipelines of different sizes and shapes, can ensure the firmness and sealing property of the connection, can automatically sample and purify different shale gases comprehensively, and can ensure the accuracy and sufficient amount of sampling.

The invention relates to the technical field of shale gas exploitation, in particular to a multifunctional system for water removal, sand removal and cooling of shale gas. According to the technical scheme, the device comprises a baffle separation device, a flow collection bin, a water removal bin, a sand setting chamber and a water storage bin; a sand discharging bin and a sand removing bin are arranged in the baffle separation device, a movable bin door is arranged between the sand discharging bin and the sand removing bin, the sand discharging bin is connected with the flow collecting bin through a first exhaust pipe, and the sand discharging bin is connected with the sand settling chamber through a first drainage pipe; one side of the collecting bin is connected with the water removal bin through a second exhaust pipe, and the bottom of the collecting bin is communicated with the sand setting chamber through a second drainage pipe; a molecular sieve is arranged at the top of the dewatering bin which is connected with the sand setting chamber through a second air inlet pipe. Water removal, sand removal and cooling treatment of the shale gas can be efficiently achieved at the same time, the situation that only one problem can be solved in the past is changed, and the shale gas treatment efficiency and quality are greatly improved.