1046 results about "Shale gas" patented technology

The invention relates to the technical field of data acquisition and data analysis, in particular to a hydraulic fracturing test crack propagation monitoring system which comprises a monitoring system and is used for monitoring crack propagation behaviors in the hydraulic fracturing process in real time. Constant or dynamically changing confining pressure and axial pressure are provided; the pore pressure dynamic regulation and control unit is used for accurately controlling the injection pressure, flow and saturation of fracturing fluid and simulating fracture propagation behaviors under different seepage conditions; the multi-physics field sensing monitoring network unit is used for collecting strain, sound wave signals and a surface displacement field in the crack expansion process in real time; full-scale monitoring of rock fracture propagation is realized, an influence mechanism of pore pressure and time effect on fracture evolution is disclosed, an accurate prediction means is provided for shale gas development and deep engineering, and the fracturing effect and engineering safety are remarkably improved.

The invention relates to the technical field of fracture network fracture water channel identification, and discloses an identification method for analyzing a dominant flow channel in a three-dimensional fracture network based on a topological network. According to the method, probability distribution parameters such as geometric occurrence, gap width and density of a rock mass multi-scale fracture system in a target area are obtained through field surveying and mapping and three-dimensional scanning, and a spatial topological structure of the three-dimensional fracture system is reconstructed by adopting Monte Carlo method simulation and discrete fracture network modeling technology; secondly, abstracting the fracture network into a three-dimensional topological graph model based on a graph theory principle, defining fracture center points and cross points as graph nodes, and converting fracture sections into weighted edges; the method breaks through the continuous medium hypothesis limitation of traditional seepage analysis, and has important engineering application value in the fields of deep geological energy storage reservoir seepage risk assessment, shale gas fracture network optimization design, rock slope stability analysis and the like; compared with a traditional numerical simulation method, the method has the technical advantages of being high in calculation efficiency, good in prediction precision, high in multi-scale applicability and the like.

The invention discloses a geological modeling, crack propagation and fluid-solid coupling production prediction integrated evaluation method, and relates to the field of multiple technologies, and the method comprises the steps: constructing a three-dimensional geological model of a deep shale gas reservoir; according to the construction model, the attribute model, the three-dimensional ground stress model and the rock mechanical parameter model, a hydraulic fracture model is constructed; based on the hydraulic fracture model and the three-dimensional geological model of the deep shale gas reservoir, establishing a fluid-solid coupling productivity simulation mathematical model of the deep shale gas reservoir; according to the fluid-solid coupling productivity simulation mathematical model of the deep shale gas reservoir, the fractured horizontal well yield of the shale gas reservoir is predicted, and a prediction result is comprehensively evaluated and optimized. According to the method, multiple links of geological modeling, fracture propagation simulation, fluid-solid coupling production prediction and the like are integrated, and the geological characteristics of the gas reservoir, the fracture propagation rule and the interaction between fluid flow and solid deformation are comprehensively considered, so that comprehensive evaluation and optimal development of the deep shale gas reservoir are realized.

The invention discloses a shale gas well middle and later period effusion intelligent diagnosis method based on LSTM and TCN models. The method comprises the following steps: S1, collecting and preprocessing multi-source time sequence data, performing sliding window segmentation, and generating a standardized data set; s2, manually marking an effusion starting point, a critical point and a process intervention point, and generating a training sample set with a label; s3, performing multi-layer expansion causal convolution on the time sequence convolutional network, and extracting multi-scale local features; s4, the modeling of the long-short-term memory network is globally dependent, and output diagnosis and early warning are discriminated; and S5, regularly collecting newly added data and diagnosis results, dynamically updating the sample set, and retraining and optimizing the model. According to the method, intelligent, efficient and real-time diagnosis and early warning of the liquid accumulation state in the middle and later periods of the shale gas well are achieved.

The invention discloses a construction parameter optimization method and device based on dessert prediction, a medium and equipment, and the method comprises the steps: obtaining a data set of a shale gas well production process, and determining a dessert indication factor; training a network model by taking the data set as input and the dessert indication factor as output to obtain a dessert indication factor prediction model; optimizing the dessert indicator factor prediction model by using a Bayesian hyper-parameter optimization algorithm, and inputting a data set obtained in real time into the optimized dessert indicator factor prediction model to obtain a prediction result; inverting a prediction result into three-dimensional space distribution characteristics of desserts in the shale reservoir; and determining contribution values and partial dependency relationships of the plurality of geological parameters and the plurality of engineering parameters to a prediction result based on the three-dimensional space distribution characteristics, deploying construction parameters according to the contribution values and the partial dependency relationships, and synchronously updating a sweet spot indication factor prediction result to realize spatial dynamic optimization and adjustment of the construction scheme. Through the scheme, the construction parameters can be scientifically optimized.

The invention discloses a water injection induced earthquake monitoring and fault activation detection system, and belongs to the field of earthquake monitoring and fault activation detection. The earthquake observation module is used for obtaining earthquake monitoring data; the seismic phase data extraction module is used for carrying out micro-seismic identification according to the seismic monitoring data to obtain seismic phase data; the earthquake initial positioning module is used for obtaining an earthquake directory of initial positioning; the earthquake fine positioning module is used for carrying out secondary positioning to obtain an earthquake directory of fine positioning; the fault and structure modeling module is used for integrating the finely positioned seismic catalog into a three-dimensional geologic structure model and carrying out spatial positioning and visualization of seismic activities; and the fault activation and earthquake risk analysis module is used for analyzing the earthquake activity time change trend, b value change, fault activation and earthquake risk according to the three-dimensional geologic structure model. The method solves the problem that an existing method lacks monitoring of fault activation and weakening of the shale gas development area and water injection induced earthquakes.

The invention provides a high and low temperature true triaxial fracturing, seepage and microscopic monitoring experiment system and method. The system comprises a three-dimensional model and a reaction kettle module, the triaxial stress loading module is arranged at the bottom and the periphery of the cavity of the three-dimensional model and reaction kettle module; a fracturing module; a temperature control module; and a crack monitoring module. Through internal and external integral temperature control, large-range temperature adjustment and stable control of-15 DEG C to 130 DEG C are realized; monitoring points such as acoustic emission, resistivity and the like are carried to explain and analyze the dynamic change rule of the crack in real time; through the innovative structural design of the device, the functions of kettle body sealing, high-stress-difference triaxial synchronous loading, radial uniform seepage and the like are achieved, the experimental requirements of hydrate in-situ generation and decomposition, large-size rock sample saturation, high-stress-difference fracturing experiments and the like are met, the true-triaxial large-physical-model experimental application scene is expanded, and the experimental efficiency is improved. And technical support is provided for fracturing transformation process optimization, scheme design and the like of unconventional oil and gas resources such as deep shale gas and hydrates.

The invention relates to the technical field of carbon dioxide sequestration and shale gas development, and particularly discloses a shale micro-nano pore multiphase multicomponent competitive adsorption data determination method and device, and the method comprises the steps: obtaining a shale core sample of a target area, and determining the type and relative content change characteristics of surface functional groups of the shale core sample; key structures and force field parameters of shale clay minerals in a target block are collected, and a shale clay mineral molecular model is established; establishing a plurality of fluid molecular models; establishing slit models, and establishing a multiphase fluid system model between the slit models to obtain a stable configuration; applying an external electric field to the stable configuration, and performing molecular dynamics calculation to obtain molecular trajectory coordinates and dynamics information of the multi-phase multi-component fluid; and calculating competitive adsorption data of the shale micro-nano pore multi-phase multi-component fluid under the action of the electric field. According to the scheme, the occurrence state and the competitive adsorption behavior of the shale micro-nano pore multi-phase multi-component fluid under the action of the electric field can be disclosed from the molecular scale.

Embodiments of the present invention relate to the technical field of shale gas development, and provide a method and system for predicting the maximum horizontal principal stress of shale gas reservoirs. The method comprises: performing cross-arranged gather extraction on acquired original shot gathers to obtain corresponding OVT gathers, and preprocessing the OVT gathers; acquiring well logging data, performing well-to-seismic calibration and seismic horizon interpretation on the basis of the well logging data, and obtaining an interpreted horizon of the current reservoir that meets in-situ stress prediction as a target horizon; constructing a low-frequency model on the basis of the well logging data and the target horizon, and calculating a Poisson's ratio and a fracture density on the basis of the low-frequency model; calculating a vertical principal stress of the target horizon on the basis of a velocity field, a formation density and a density inversion body; and calculating the maximum horizontal principal stress of the current reservoir on the basis of the Poisson's ratio, the fracture density, the vertical principal stress and a preset principal stress solving model. The solution of the present invention solves the problem of low accuracy in existing solutions for predicting the maximum horizontal principal stress of shale gas reservoirs.

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 utility model provides a cable tensile strength testing device, and relates to the technical field of deep shale gas horizontal well fracturing. The first clamping and fixing mechanism is used for clamping and fixing a ferrule structure of the tested cable, and the ferrule structure is formed by bending one end of the cable into an arc-shaped closed loop; the rope sleeving column is transversely connected to the base in a sliding mode, and the loop structure can be connected to the rope sleeving column in a sleeving mode; the tension detection mechanism comprises a tension detector, one end of the tension detector is connected with the rope sleeving column, and the other end of the tension detector is connected with the base; the winding mechanism comprises a winding roller and a driving motor which are in transmission connection, the winding roller is installed on the base, and a containing groove is formed in the side wall of the winding roller; and the second clamping mechanism is arranged in the accommodating groove and is used for clamping and fixing the other end of the cable. And through the arrangement of the winding roller, the cable can be pulled, and the device can adapt to cables with different lengths.

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 discloses a shale gas full life cycle yield prediction method, and relates to the field of shale gas development. According to the shale gas full life cycle yield prediction method, the production stage of a shale gas well is divided into six stages of stable yield, continuous decreasing, intermittent production, pressurization decreasing, pressurization intermittent opening and fracturing effect receiving; in the stable production stage, the gas production rate is predicted by adopting a productivity coefficient method based on unstable linear flow, in the continuous decline stage, the gas production rate is predicted according to the ARPS decline model analogy partition decline rate, and in the intermittent production stage, the gas production rate is predicted by combining the ARPS decline model and the intermittent efficiency; in the pressurization decline stage, the gas production rate is predicted according to the gas well decline rate of the corresponding decline stage by adopting monthly production data; the gas production rate is predicted in combination with a decline model and the intermittent opening efficiency in the pressurizing intermittent opening stage; and predicting the gas production rate by using the effected ARPS model in the fracturing effected stage. According to the shale gas full life cycle yield prediction method, the corresponding yield prediction method is established according to the production rules of different development stages of the shale gas full life cycle, and the yield prediction efficiency and accuracy are improved.

The invention provides a composite synergistic system for a shale gas old well and an immovable string production increasing process. The composite synergistic system mainly comprises the following substances: 10-12% of a wetting improver; 4%-6% of a scale remover; 2%-3% of a scale inhibition dispersant; 5%-10% of a resistance-reducing discharge aiding agent; 15%-20% of a synergistic accelerant; the wetting improver is a mixture of alkyl polyglucoside, an anionic surfactant sodium dodecyl benzene sulfonate and deionized water, the content of the alkyl polyglucoside in the wetting improver is 5%-10%, and the content of the anionic surfactant sodium dodecyl benzene sulfonate is 15%-18%; the descaling agent is a mixture of sodium alpha-olefin sulfonate and nonylphenol polyoxyethylene ether ammonium sulfate, and the mass ratio of the sodium alpha-olefin sulfonate to the nonylphenol polyoxyethylene ether ammonium sulfate in the descaling agent is (2: 1)-(3: 1). According to the composite synergistic system, through combination and reuse of different materials and different doses, the multifunctional composite synergistic system integrating vibration, permeation and dispersion effects is researched and developed, and therefore immovable tubular column yield increase construction of a shale gas old well is achieved.

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 provides a method for determining the residual yield of shale gas based on methane carbon isotope change in desorption gas. The method comprises the following steps: S1, putting a shale sample into a desorption tank filled with saturated salt water, and sealing; s2, placing the desorption tank in water, recording the volume of desorption gas according to the desorption time by using a drainage method, and collecting the desorption gas; s3, according to the analytic gas collected in each analytic time period, calculating accumulated total analytic gas, and calculating the proportion of the analytic gas in each analytic time period to the total analytic gas to obtain a stage accumulated analytic rate; s4, measuring the ratio of methane carbon isotope delta 13C in the desorption gas when the desorption rate is accumulated in each stage; and S5, establishing a change curve of the stage cumulative analysis rate of the shale gas and the methane carbon isotope delta13C so as to obtain a model for predicting the shale gas productivity stage. The invention provides a non-destructive and direct gas potential measurement means, which is high in accuracy and can be well adapted to shale gas prediction.

The invention discloses a shale gas gathering and transportation station yard blockage and high-low pressure gathering and transportation interference diagnosis optimization method, and belongs to the field of natural gas mine field gathering and transportation. According to the method, the judgment method of the blockage site of the pipeline in the station and the calculation method of the blockage degree are determined by checking the friction resistance of the whole-station pipe fitting of the shale gas station and calculating the pressure drop of the pipeline in the station, and a solution is provided for the problem of gathering and transportation interference in the high-pressure well mine field and the low-pressure well mine field. The method is suitable for shale gas gathering and transportation stations in the middle and later periods of development, can assist in making of equipment overhaul and production parameter optimization schemes, further improves the operation efficiency of a pipe network, and has wide application prospects.

The invention belongs to the field of high-salinity organic wastewater treatment, and particularly relates to a shale gas high-salinity wastewater electrochemical catalysis coupling membrane separation low-carbon treatment method which comprises the steps of pretreatment, electrocatalytic oxidation, membrane separation, salt recycling and product recovery, intelligent management and control, energy coupling and the like. Through cooperation of an electrochemical catalysis coupling membrane separation technology and mass transfer strengthening, anti-pollution design and intelligent optimization of an intelligent energy system, the treatment efficiency and the recycling level of the shale gas high-salinity wastewater can be remarkably improved, and low-carbon, economical and efficient treatment of the shale gas high-salinity wastewater is achieved; and the method can also be used for treating similar high-salt organic wastewater generated by conventional oil and gas resource development, and has good popularization and application prospects.

The invention discloses a metal-doped modified zeolite molecular sieve adsorbent as well as a preparation method and application thereof. The metal-doped modified zeolite molecular sieve adsorbent comprises a carrier and an active metal component loaded on the carrier, the carrier is a mordenite molecular sieve; the active metal components comprise at least two of Ca, Mg, Ti, Fe, Ni, Co, Cu, Zn, Na and Ag; in the adsorbent, the loading capacity of the active metal component is 0.1%-15%. The adsorbent provided by the invention has good separation performance on CH4 / CO2, CH4 / N2, CO2 / N2 and CH4 / CO2 / N2 mixed gas separation systems, has the advantages of simple synthesis method, strong hydrothermal stability, high selectivity and the like, and can meet the requirements of CH4 purification in unconventional natural gas such as landfill gas, sewage treatment methane gas, agricultural and breeding biogas, coal bed gas, shale gas and shallow biogas, and the like. And the requirements of high-concentration natural gas denitrification, CO2 capture and other scenes can be met.

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 relates to a true triaxial fracturing test magnetofluid monitoring system and method, and belongs to the field of coal bed gas exploration and development. The system comprises a magnetic fluid mixing device, an injection device, a 4 * 4 magnetic induction sensor array, a data acquisition device, a high-pressure water pump device and a true triaxial experiment device. The method comprises the following steps: mixing magnetic fluid and adjusting viscosity; injecting a test piece; applying three-dimensional stress; monitoring magnetic field change in real time; millimeter-level positioning and three-dimensional visualization of crack expansion are achieved through magnetofluid dynamic response and data collected by a magnetic induction sensor array in combination with differential analysis, edge detection and a finite element inversion algorithm, and the magnetofluid recovery rate is larger than 95%. The method solves the problems that traditional monitoring is low in precision and poor in real-time performance, and is suitable for dynamic analysis of coal bed gas and shale gas fracturing cracks.

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 discloses a shale reservoir fracturing casing deformation calculation method, and relates to the technical field of shale oil and gas development. The method comprises the following steps: fusing microseism, logging, rock core and drilling and logging data, and constructing a fracture network-geomechanics coupling model; calculating a direction cosine matrix according to the fracture three-dimensional stress and the inclination angle, evaluating an activation risk, and screening out high-risk fractures; the triangular mesh boundary element solves the slippage as a displacement boundary, and an eight-node hexahedron elastic-plastic casing mesh is utilized to iteratively calculate a casing variable and draw a cloud picture; and a micro-seismic data real-time iteration model is newly added along with construction, and the perforation cluster distance, the fracturing scale, the displacement and the well spacing are dynamically optimized. According to the method, a large amount of on-site microseismic data is fully utilized, reservoir fracture fine description and slippage risk analysis are achieved, shaft multi-point casing variable prediction is completed, and key technical support is provided for deep shale gas development fracturing scheme decision and risk avoidance.

The invention belongs to the technical field of oil and gas field yield prediction, and relates to a multi-granularity shale gas well production dynamic prediction method and system based on a large model, and the method comprises the steps: S1, collecting historical production data and environmental data of a shale gas well, carrying out the data preprocessing, and dividing a training set, a verification set and a test set, the production data comprises daily gas yield, oil pressure, casing pressure, oil casing pressure difference and water yield, and the environment data comprises temperature; s2, constructing a production dynamic prediction model based on a Transform model architecture; s3, performing model training and evaluation, and continuously optimizing the prediction model until the prediction model meets requirements; s4, evaluating the production dynamic prediction model meeting the requirements by using the test set; and S5, predicting the production dynamic state of the shale gas well. The problems of high cost and low accuracy of shale gas well yield prediction are solved.

The invention discloses a high-gas-liquid-ratio gas-liquid two-phase flow and liquid holdup measurement method and device based on three-dimensional differential pressure, and the method comprises the steps: applying a centrifugal force to a gas-liquid two-phase flow through a centrifuge, and generating a stable gas nucleus-liquid ring separation structure; measuring radial differential pressure, axial differential pressure, temperature and pressure values of the centrifuge in real time; establishing a liquid holdup calculation model based on the differential pressure ratio of the radial differential pressure and the axial differential pressure, and obtaining the liquid holdup according to the liquid holdup calculation model; calculating a friction coefficient and corrected gas phase density according to the temperature and pressure values; and based on the mapping relation between the axial differential pressure and the gas phase apparent velocity and the gas state equation, the gas-liquid two-phase flow is calculated according to the liquid holdup, the friction coefficient and the corrected gas phase density. According to the invention, a high-precision, separation-free and fast-response industrial-grade solution is realized, and a new-generation measuring tool is provided for the key fields of shale gas exploitation, submarine oil and gas pipeline transportation and the like.

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.