442 results about "Stockwork" patented technology

The invention discloses a geothermal development oil shale and CO2 geological storage integrated method, which relates to the field of complex oil and gas reservoir development, and comprises the following steps: designing U-shaped well process parameters, enabling CO2 fluid to flow to a high-temperature geothermal reservoir through a descending section of a U-shaped well, injecting the CO2 fluid into the oil shale reservoir along an ascending section of a shaft after sufficient heat exchange, preheating the oil shale, and storing the CO2 fluid into a high-temperature geothermal reservoir through the descending section of the U-shaped well. Terrestrial heat extraction and utilization are realized; after the temperature of the oil shale layer rises to the target temperature, the oil shale layer is further heated through manual heating, and in-situ conversion development of the oil shale is achieved; after completion, produced CO2 is injected into the oil shale layer again through the U-shaped well, and collaborative development of CO2 geological storage, geothermal extraction and oil shale in-situ conversion is achieved. Geothermal energy is efficiently extracted through CO2 and used for oil shale in-situ pyrolysis, the extra manual heating cost needed by oil shale in-situ conversion is remarkably reduced, and the economic feasibility of a pure storage project and oil shale in-situ conversion development is improved.

This invention discloses a method for indicating the degree of pyrite development in carbonate reservoirs, belonging to the field of geological exploration technology. Its key features include the following steps: a) selecting sensitive parameters to distinguish pyrite development based on the well logging response characteristics of pyrite-developed strata; b) establishing trend lines for the variation of sensitive parameters in formations with no or low pyrite content using these sensitive parameters; c) constructing trend lines for the variation of sensitive parameters with pyrite content based on strata data from key wells with different pyrite contents; d) identifying pyrite-enriched strata in the wells to be identified based on the intersection indications of the sensitive parameters; e) evaluating the degree of pyrite development in the pyrite-enriched strata by assessing the degree of difference in the intersection of sensitive parameters. This invention achieves the identification of pyrite-enriched strata through resistivity and sonic transit time intersection, enabling rapid and accurate identification of the degree of pyrite development in carbonate reservoirs.

The invention discloses a quantitative evaluation method for complexity of shale oil and gas horizontal well reservoir reconstruction cracks, which comprises the following steps: determining a crack development strength factor representing reservoir inherent crack development potential by calculating a mineral heterogeneous coefficient based on rock sample mineral component data at each perforation cluster position in a target fracturing section; determining the optimal fracture length by combining reservoir numerical simulation, determining the total fracturing fluid amount, performing non-uniform distribution according to the heterogeneity of each cluster, and determining a fracture propagation complexity factor representing the dynamic propagation complexity of the hydraulic fracture; weighting the two factors to obtain a crack complexity index for comprehensively evaluating the reservoir transformation effect, and performing grading; according to the method, static geological evaluation and dynamic engineering evaluation are combined, quantification of inter-cluster transformation differences is achieved, the defects that a traditional method is one-sided in evaluation and low in precision are overcome, and a reliable quantitative basis is provided for optimal design of a shale oil and gas reservoir fracturing scheme and accurate evaluation of the transformation effect.

The invention provides a carbon dioxide geological sequestration injection strategy optimization method and device. The method comprises the steps that candidate injection curves of different forms of carbon dioxide injection rates and time change relations of a target sequestration site are obtained; each candidate injection curve represents an injection strategy; inputting the time sequence data and the reservoir state query information corresponding to each candidate injection curve into the trained agent model to obtain a prediction index corresponding to the reservoir state query information; and determining a target injection strategy corresponding to the target candidate injection curve based on the prediction index corresponding to the reservoir state query information and the target index evaluation condition. According to the method, the maximization of the sealing injection efficiency and the accumulative sealing amount is realized on the premise of ensuring the reservoir pressure safety.

A method for simulating cross-seasonal heat storage of a buried pipe well group in a geothermal reservoir is characterized in that hot water and cold water are respectively injected in different seasons by arranging different injection ports in a countercurrent cross injection mode, so that a relatively balanced temperature distribution pattern of a'hot area 'and a'cold area' is formed in a stratum, and the volume structure of a buried pipe is simplified into a line unit model; discretizing the pipeline area by adopting a finite element method; on the basis, initial temperature field distribution of soil and initial parameters of fluid in a buried pipeline unit are set, a proper numerical solution method is selected to solve the pipeline unit model, and the stability of the calculation process and the accuracy of the result are ensured through real-time monitoring; in order to further analyze the influence of underground water seepage on the system performance, an underground water seepage module is introduced, and the difference between summer refrigeration and winter heat supply effects under the seepage condition or not is compared and researched; the invention further comprises a system, equipment and a storage medium for implementing the method.

Systems and methods for determining a diagenesis level in a reservoir for performing hydrocarbon extraction include receiving a set of open hole (OH) log data from one or more wells in the reservoir, the OH log data representing a subsurface of the reservoir; executing a diagenesis model to process the set of OH log data, the diagenesis model trained by thin-section image data correlated to labeled OH log data, the labeling identifying values for a quartz overgrowth rate (QOR), a clay coating rate (CCR), or a thin-section porosity in the subsurface based on a value in the OH log data; determining a prediction of a porosity of the reservoir, a permeability of the reservoir, or both the porosity and the permeability; and generating a control signal representing a recommendation to drill a well at a location in the reservoir.

The invention discloses a simulation test system and method for reservoir fracture network acidification and geothermal injection and production. The system comprises a high-temperature triaxial loading bin, an acidification injection and production device, a high-pressure pumping device and a visualization device, and stress loading equipment is arranged in the high-temperature triaxial loading bin and used for containing a seam network rock mass model and carrying out triaxial stress loading. The acidification injection and production device is used for leading acid liquor and heat-carrying working media into or out of the seam network rock mass model, the high-pressure pumping device is used for providing the acid liquor and the heat-carrying working media for the acidification injection and production device, and the visualization device is used for shooting, recording and displaying images of the seam network rock mass model in reservoir seam network acidification and geothermal injection and production in real time. According to the device and the method, fracture net acidification and geothermal circulation injection and production can be continuously completed on the same system and the same model according to a field sequence, and the whole process is recorded, so that the stability and repeatability of a test result are ensured.

The invention belongs to the technical field of oil and gas reservoir rock data identification, and particularly relates to a three-dimensional multi-mineral digital core modeling method. According to the method, a 2D-3DGAN algorithm is provided, a three-dimensional data volume can be generated only by using a single two-dimensional picture, the advantages of a 2D-3DGAN method and an AMICS method are combined, a modeling method of 'AMICS + 2D-3DGAN' is provided to establish a multi-mineral, high-precision and efficient three-dimensional multi-mineral digital core, the representative two-dimensional ore scanning image is obtained by using the 2D-3DGAN method, and the three-dimensional data volume can be generated only by using a single two-dimensional picture. And generating a three-dimensional multi-mineral digital image by using the obtained two-dimensional mine scanning image as a training image. The built model not only contains multiple minerals, but also gives consideration to accuracy and economical efficiency, can represent reservoir rocks, and provides a firm basis for subsequent diagenesis simulation based on multi-mineral digital cores and research on electrical, acoustic and mechanical properties of reservoirs.

The invention relates to a method for testing the gas content of free gas and adsorbed gas in a deep coal seam. Starting pressure is used as a pressure point for determining the free gas and the adsorbed gas; the method comprises the following steps: reducing a pressure-maintaining coring cylinder placed in a whole section of a rock core to a reservoir temperature-pressure condition, carrying out a pressure-reducing exhaust experiment, reducing the pressure from the reservoir temperature to a starting pressure, and collecting the gas quantity and recording the gas quantity as free gas quantity; continuously reducing the pressure from the starting pressure to the atmospheric pressure, and recording the collected gas amount as the total amount of the free gas and the desorbed gas; after pressure reduction and exhaust are finished, the whole section of rock core is taken out from the pressure-maintaining coring barrel, a rock sample is taken, and the residual gas amount in the rock sample is measured and recorded as the residual gas amount of the rock sample; summing the unit mass free gas volume and the total amount of the unit mass free gas and the desorption gas, and subtracting the unit mass free gas volume to obtain a difference value which is the gas content of the unit adsorption gas. The method has important significance for formulating a targeted development strategy for deep coal rock gas.

The invention discloses a tail water recharge system of a middle-deep geothermal well and a working method, and particularly relates to a recharge well, a vacuum breaker, a flowmeter, a control system, a remote monitoring device, a steady flow tank, an impurity filtering device, a vacuum detection device and a temperature control device. According to the tail water recharge system of the middle-deep geothermal well and the working method, the vacuum breaker is additionally arranged in the recharge well, so that the problem of negative pressure generated in the recharge process is effectively solved, a vacuum column is prevented from being formed in a heating system, the heating effect is improved, the geothermal dynamic monitoring work is simplified, and the working efficiency is improved. The vacuum breaker is arranged so that tail water can be smoothly recharged into a heat storage layer, the situation that air enters a recharge system is avoided, the quality of the tail water is kept, a recharge channel is prevented from being blocked, the recharge efficiency is improved, complex equipment such as a sand remover, a filtering tank and an exhaust tank does not need to be arranged, the system structure is simplified, and the system cost is reduced. And meanwhile, the recharge efficiency is improved.

A method for evaluating contribution of each component to shale oil reservoir resistivity at high temperature and high pressure is applied to the field of oil exploration and development. The method comprises the following steps: (1) analyzing the volume percentage of each clay mineral, the pore water content and the mineralization degree of the shale oil reservoir pressure-maintaining closed core; (2) when the fluid pressure is greater than 23MPa, measuring the resistivity of the pressure-maintaining closed rock core at each temperature point; (3) carrying out water balance treatment on pure clay minerals, namely kaolinite, montmorillonite, illite and chlorite, and measuring the resistivity at each temperature point when the fluid pressure is greater than 23MPa; (4) when the fluid pressure is greater than 23MPa, measuring the resistivity of each temperature point of the solution consistent with the mineralization degree of the pore water; and (5) constructing a resistivity evaluation model, and evaluating the contribution of each component to the resistivity of the shale oil reservoir under the condition of high temperature pressure.

The invention discloses a deep coal rock free gas and adsorption gas volume and pore size distribution quantitative characterization method, and belongs to the field of deep oil and gas development, and the method comprises the following steps: carrying out an online NMR monitoring saturation experiment under representative rock sample reservoir temperature and pressure, and obtaining an adsorption / free gas total saturation volume and an NMR curve; carrying out an isothermal adsorption experiment on the saturated rock sample to determine an adsorbed gas volume; determining a rock sample adsorbed gas / free gas volume ratio (first ratio) by using the total volume and the adsorbed gas volume; determining a first pore size distribution sequence of the rock sample and a corresponding NMR intensity sequence according to an NMR curve of the saturated underwater test of the rock sample and a high-pressure mercury injection experiment; dividing the first aperture distribution sequence into a first interval and a second interval according to a preset aperture value, and calculating an NMR total intensity ratio (a second ratio) of the first interval and the second interval; and determining pore size distribution intervals of the free gas and the adsorbed gas according to the first ratio and the second ratio. According to the invention, fine characterization of the adsorption / free gas volume and pore size distribution of the deep coal rock gas reservoir can be realized.

The invention discloses a hydrothermal type geothermal efficient exploitation and irrigation intelligent operation maintenance system, and the system comprises a data processing module which is used for carrying out the multi-dimensional and multi-physical-field precise digital mapping of a geothermal reservoir to ground equipment, and obtaining the dynamic change process of the geothermal reservoir and the ground equipment under different working conditions; the data processing module comprises a thermal reservoir geologic model, a THMC coupling simulation model and a ground facility system model, the thermal reservoir geologic model is used for representing a three-dimensional space structure and initial physical property parameter distribution of a geothermal reservoir, and the THMC coupling simulation model is constructed based on the geologic model. The ground facility system model simulates fluid flow, heat transfer, rock mechanics and chemical reaction processes and is used for simulating the working state of ground equipment from a wellhead of a production well to a wellhead of a recharge well; and the execution module is used for driving the variable frequency pump to perform stepless speed regulation so as to change the total flow and pressure of the system, and driving the regulating valve to perform opening regulation so as to realize flow distribution and pressure control, thereby forming an intelligent control loop.

The invention provides a carbon dioxide geological sequestration project feasibility analysis method and device. The method comprises the steps that stratum rock mechanical parameters, reservoir geological parameters, cover stratum geological parameters, geological stability data and carbon dioxide injection parameters of a carbon dioxide geological sequestration area are obtained; carrying out sealing feasibility analysis based on the reservoir geological parameters, the cover layer geological parameters and the geological stability data to obtain a sealing feasibility analysis result; performing stratum injectability analysis based on the stratum rock mechanical parameters and the carbon dioxide injection parameters to obtain a stratum injectability analysis result; performing earth surface deformation quantity prediction based on the stratum rock mechanical parameters and the carbon dioxide injection parameters to obtain an earth surface deformation quantity prediction result; and performing carbon dioxide geological sequestration engineering feasibility analysis based on sequestration feasibility analysis results, stratum injectability analysis results and surface deformation quantity prediction results. According to the scheme, the feasibility of the carbon dioxide geological sequestration project can be accurately analyzed and evaluated.

A system for implementing and optimizing the storage potential of subterranean carbon mineralization can include a fluid injection well subsystem having an injection wellbore, a pumping system, and a fluid injection completion system disposed at an injection range along the injection wellbore, where the fluid injection completion system is configured to control an injection rate of pressurized fluid from the injection range into an active storage zone within a subterranean rock formation. The system can also include a fluid production well subsystem having a production wellbore and a fluid production completion system disposed at a production range along the production wellbore, where the fluid production completion system is configured to control an inflow rate of production fluid from the active storage zone into the production range of the production wellbore. The system can further include a monitoring subsystem configured to monitor carbon mineralization in the active storage zone.

The invention relates to the field of deep coal bed gas development and reservoir reconstruction engineering, in particular to a compressibility evaluation method for a deep coal bed gas reservoir containing dirt band. The invention discloses a method for evaluating compressibility of a deep coal bed gas reservoir containing dirt band. The method comprises the following steps: obtaining a normalized coal rock brittleness index, a normalized coal body structure index, a normalized fracture toughness index, a normalized ground stress heterogeneity index, a normalized dirt band and coal rock layer stress difference index, a normalized fracture surface density index and a normalized mechanical specific energy index; converting the data into dimensionless numerical values, and unifying the value range to an interval of [0, 1]; and performing hierarchical weight assignment by using a triangular fuzzy analytic hierarchy process to form a deep coal rock compressibility index, and establishing an evaluation standard according to the deep coal rock compressibility index. According to the method, a theoretical basis is provided for optimal decision-making of the on-site deep composite coal rock reservoir fracturing transformation horizon.

This invention discloses a test site and method for evaluating the geological storage capacity of carbon dioxide. The test site includes a brine pool and a brine layer and caprock structure located within the pool. The caprock structure is vertically positioned below the brine layer, and a brine reservoir structure is located below it. The brine reservoir structure is connected to a brine storage tank via a simulated extraction well pipe. The brine storage tank is connected to the brine layer via a simulated injection well pipe. Carbon dioxide is injected into the brine reservoir structure via a simulated gas injection well pipe. Pressure sensors installed on the inner wall of the brine pool monitor the pressure within the brine layer and the brine reservoir structure. The carbon dioxide injection rate, brine extraction rate, and brine injection rate are adjusted based on the monitored pressure to achieve pressure balance between the brine layer and the brine reservoir structure. This invention provides a test site for evaluating the geological storage capacity of carbon dioxide under actual site conditions.

The invention relates to a thin interbed clay mineral content prediction method based on an RBF neural network, and the method mainly improves the longitudinal resolution through the inversion of the RBF neural network on the basis of multiple attributes, and compared with the conventional research, the method directly uses the seismic attributes, such as amplitude, as the input to learn a target curve, and improves the prediction efficiency. According to the method, the seismic frequency division reconstruction data body and the inversion body are selected as input, so that the longitudinal resolution and the well coincidence rate are greatly improved; in addition, the inversion body is used as input, so that the problem that neural network inversion geological laws are poor in previous research is solved, and an important basis can be provided for reservoir assessment and development; examples prove that the method disclosed by the invention is higher in precision of inverting the clay mineral content compared with a simulation method directly using waveform indication, and is suitable for reservoir parameter prediction of a thin interbed.

The invention discloses a multi-scale analysis-based gas-water seepage field simulation method, which specifically comprises the following steps of: based on a digital rock core reconstructed by a CT (Computed Tomography) scanning image of a typical rock sample of a target reservoir, adopting a microcosmic pore network flow simulation technology; the change rule of the stratum seepage capacity in different stratum pressure gradients and water drive processes, the use degree of a pore network and the water drive process in a pore are calculated, and then a correlation chart with the rock permeability and the pressure gradients is established and used for rapid measurement and calculation of the actual reserve use degree and the recovery degree of the water-invaded sandstone gas reservoir. The method starts from a rock microcosmic pore channel, the scale is amplified to a macroscopic oil reservoir during application, the method has the cross-scale characteristic, and the method is used for rapidly measuring, calculating and evaluating the reserve utilization degree and the recovery degree of the actual water-invaded sandstone gas reservoir and is beneficial to rapid development of the gas reservoir engineering scheme design in a mine field.

The utility model discloses fracturing water injection equipment for drainage and mining of deep geothermal reservoirs, which comprises a fixing frame, the lower end of an inner cavity of the fixing frame is fixedly connected with a supporting transverse plate, the top of the supporting transverse plate is fixedly connected with a filter shell, and the left side of the filter shell is fixedly connected with an input pipe. Through the arrangement of the filter plate, overlarge sand grains in fracturing fluid conveyed into the fracturing pump set through the liquid inlet pipe, the sealing shell, the filter shell and the input pipe can be filtered, and the situation that the fracturing effect in the drainage and mining process of a deep geothermal reservoir is affected due to the fact that the sand grains in the fracturing fluid are overlarge is effectively avoided; meanwhile, through the arrangement of a driving motor, a rotating shaft, a fixed box, a first bevel gear, a second bevel gear, a rotating rod and a grinding roller, sand grains filtered at the top of a filter plate can be effectively ground, and the ground sand grains can be conveyed to a fracturing pump set along with flowing of fracturing fluid; and the filter plate is effectively prevented from being blocked by larger sand grains.

This invention belongs to the field of oil and gas production enhancement and stimulation technology. It provides a FDEM simulation method and system for mineral-scale shale hydration-induced fracturing. The method includes the following steps: obtaining target reservoir stress, rock porosity, and permeability; preparing rock samples from the target stratigraphic layer and obtaining the mineral composition and content through X-ray diffraction experiments; constructing a polycrystalline geometric model of the minerals using random Voronoi mosaic technology; conducting core immersion hydration experiments to obtain the relationship between core water content and time; setting initial and boundary conditions for the model and establishing a numerical model of clay mineral hydration expansion-induced fracturing based on the finite discrete element method; and conducting numerical experiments on shale hydration-induced fracturing to obtain the micro-fracture propagation morphology induced by clay mineral hydration expansion. This invention considers the non-uniform mosaic distribution of multiple minerals in the reservoir rock, simulates the non-uniform stress distribution induced by clay mineral water absorption and expansion, and realizes numerical simulation of the mineral-scale shale hydration-induced fracturing process.

The application provides a method for judging ancient marine water body environment. The method comprises the following steps: obtaining a target shale reservoir core sample in a work area; wherein the target shale reservoir is radiolarian siliceous shale lamina; determining the composition of the shell cavity filling and the filling amount of calcite in the shell cavity in the target shale reservoir based on the target shale reservoir core sample; and determining the ancient marine water body environment during the deposition period of the target shale reservoir in the work area according to the composition of the shell cavity filling and the filling amount of calcite in the shell cavity in the target shale reservoir. The method for judging ancient marine water body environment can effectively combine the oxidation-reduction state of the ancient marine deep water body and the precipitation and dissolution conditions of calcite, so as to better promote the reconstruction of the ancient marine environment.

The invention discloses a clean water carrying air suspension proppant fracturing method for a shallow bottom water reservoir. The clean water carrying air suspension proppant fracturing method comprises the following steps: preparing an air suspension proppant; optimizing an underground fluid system, and selecting clear water as prepad fluid, sand-carrying fluid and displacing fluid; according to the reservoir geologic characteristics and the oil-bearing property, in combination with software, the fracture expansion condition is simulated, the sand amount, the construction displacement, the sand ratio and the prepad fluid proportion parameters are optimized, a construction pump injection program is designed according to the optimized parameters, the fracturing construction process is determined, and a clear water gas suspension sand fracturing technical mode is formed. The surface of the quartz sand is modified, the fracturing propping agent which can generate a large number of bubbles on the surface when encountering water and is fully suspended or flocculent semi-suspended in water is obtained, the fracturing method that clear water carries the air suspension propping agent is adopted, on one hand, the net pressure in a crack can be reduced, the crack height can be controlled, bottom water channeling due to pressure is avoided, and the fracturing propping agent can be recycled; and on the other hand, the sanding profile can be improved to realize effective support of the middle-upper oil layer, so that benefit development of the shallow bottom water reservoir is realized.

The invention provides a hydrothermal geothermal well bore structure and a well completion method, and the structure comprises an intelligent management and control system which comprises a hierarchical control module, a distributed monitoring network and a performance evaluation unit. The hierarchical control module, the distributed monitoring network and the performance evaluation unit form closed-loop control of parameter acquisition, data analysis and regulation and control execution through a preset logic interaction link; the well body structure comprises a main well section, a branch well section and a multi-ring enhanced heat exchange unit, the main well section and the branch well section are in sealed communication through a directional butt joint component, the multi-ring enhanced heat exchange unit is arranged around the tail end of the branch well section, and the tail end of the branch well section is further provided with a functional heat collecting assembly matched with a heat storage layer. According to the invention, a core management and control layer of the hierarchical control module plans a global strategy as a whole, and a partition control layer performs directional regulation and control according to an efficient / balanced / emergency mode and executes a driving layer landing physical action; the whole section of the distributed monitoring network covers three types of monitoring nodes of environment, structure and performance.

The invention relates to the technical field of oil and gas reservoir damage evaluation, in particular to a method and device for calculating irreducible water saturation of a tight sandstone reservoir, electronic equipment, a storable medium and a computer program product. The method comprises the following steps: acquiring a pore distribution curve of a compact sandstone sample; based on the pore distribution curve of the compact sandstone sample, determining the capillary bound water content of different pressure differences of the compact sandstone reservoir; carrying out total rock and clay mineral analysis on the compact sandstone sample to obtain the content of the clay bound water in the compact sandstone reservoir; and obtaining the irreducible water saturation of the tight sandstone reservoir based on the capillary irreducible water content and the clay irreducible water content. According to the method, the relationship between the absolute content, the pore distribution, the stress distribution and the interfacial tension of the clay mineral and the irreducible water saturation is established, so that qualitative and quantitative analysis on the irreducible water saturation is quickly and accurately performed.

The invention relates to the technical field of carbon sequestration and geological sequestration, and particularly discloses a slice CO2 water-rock reaction corrosion identification and pore evaluation method based on machine learning, and the method comprises the steps: firstly collecting multi-focal-plane images of the same view field of a slice before and after a reaction on a scanning electron microscope platform, and carrying out the registration; utilizing the trained U-Net instance segmentation model to automatically identify a corrosion area and extract a contour; generating a relative height map through a depth-of-field reconstruction and calibration technology in combination with a multi-focal-plane sequence, and obtaining the effective corrosion depth of each corrosion area; and carrying out volume normalization calculation based on area-depth information, and directly outputting porosity increment and spatial distribution thereof. According to the method, destructive detection is not needed, quantitative volume characterization of corrosion characteristics is achieved, the analysis efficiency and accuracy are remarkably improved, batch processing and mineral phase layering statistics are supported, and reliable data support is provided for CO2 geological storage reaction mechanism research and reservoir simulation.

The present application relates to the geological exploration technical field, more particularly, to a deep water super shallow layer natural gas reservoir rock physics shear wave velocity prediction method, comprising: calculating equivalent bulk modulus, shear modulus and density of a plurality of mineral mixed matrix according to shale content; then calculating skeleton bulk modulus and shear modulus; then calculating saturated rock bulk modulus and shear modulus through a model, and calculating saturated rock density through rock matrix density; distributing longitudinal and transverse velocities of suspended state and bearing state, and calculating equivalent longitudinal and transverse wave velocities; using equivalent longitudinal wave velocity to construct an inversion objective function with longitudinal wave velocity as a known condition; comparing actual longitudinal wave velocity with calculated longitudinal wave velocity; realizing nonlinear inversion of transverse wave velocity according to an algorithm, and obtaining transverse wave velocity of a to-be-inverted work area. The present application simultaneously considers rock physics models of particle suspended state and bearing state, and realizes transverse wave velocity prediction and deep water super shallow layer natural gas reservoir transverse wave velocity direct inversion.

This invention relates to a method for evaluating the escape rate of shale gas reservoirs with different dip angles, employing the following technical solution: including the following steps: Step (1) Calculate the drilling angle θ of the plunger sample based on the shale bedding type, calculate the length L of the plunger sample based on the plunger diameter d, and drill the plunger sample based on the drilling angle θ and length L; Step (2) Test the minimum starting pressure P0 of the plunger sample using methane gas; Step (3) Calculate the fluid pressure P of the formation where the plunger sample is located. 流 hydrostatic pressure P 水 Minimum starting pressure P0 and static rock pressure P 岩 Calculate the test pressure Δ for permeability testing p and confining pressure P 围 Step (4) is performed according to the test pressure P determined in step (3). 测 and confining pressure P 围 The permeability of the plunger sample is tested to obtain the permeability k; step (5) calculate the gas escape rate R; step (6) evaluate the shale gas escape capacity of the layer where the sample is located based on the gas escape rate R. The larger the escape rate R is, the stronger the shale gas escape capacity is. Then calculate the shallowest burial depth H where the layer where the sample is located can be effectively preserved.

According to the vibration excitation and permeation enhancement method and system for the geothermal in-situ power generation system, the multi-layer piezoelectric vibrator array is implanted into the drill hole of the geothermal reservoir and packaged in the closed container filled with the supercritical working medium, and the phased array technology is used for applying the accurate sweep frequency signal to excite thermo-acoustic resonance; a controllable microcosmic fracture network is generated in the rock mass to enhance the permeability of the rock mass; meanwhile, the system directly utilizes the piezoelectric effect to convert rock mass vibration mechanical energy into electric energy, and monitors and adjusts the crack expansion state in real time by means of the resonance wave self-sensing function. Therefore, the integrated effect of efficient, low-cost and low-environmental-risk geothermal permeation enhancement and in-situ power generation can be achieved without traditional fracturing fluid and large pumping heat exchange equipment, the geothermal exploitation process is simplified fundamentally, and the energy conversion and resource recovery efficiency is improved.

The application discloses a micro-visualization slice for shale bedding flow characteristic analysis and a manufacturing method thereof. The method can comprise the following steps: grinding a shale slice obtained by slicing a shale sample, and grinding the shale slice to a thickness of 30-40 microns; clamping the ground shale slice in the middle by using two pieces of organic glass slices with a thickness of 0.2-0.3 mm, and placing the clamped shale slice in an inlaying machine to perform hot pressing, so that the organic glass slices and the shale slice are pressed into one; drilling a hole in the radial direction of the organic glass slice by using a drill bit with a diameter of 0.7-0.9 mm, so that the hole after drilling is communicated with the shale slice; inserting one end of a quartz micron tube with an inner diameter of 0.5 mm into the hole to fix the quartz micron tube, and connecting the other end of the quartz micron tube with a quartz tube line with an inner diameter of 1.6 mm, so as to manufacture the micro-visualization slice for shale bedding flow characteristic analysis. The micro-visualization slice can lay a foundation for subsequent visualization seepage experiments of different bedding types, pressures and injection media, and clarify different beddings to shale gas reservoir flow patterns and development characteristics.