716 results about "Injection well" patented technology

The invention discloses an injection-production well connectivity modeling and yield prediction method and device, and relates to the technical field of oil reservoir engineering. Comprising the following steps: on the basis of preprocessed time sequence injection-production data, constructing a spatial topological graph structure according to screening conditions; constructing a yield prediction model based on the LSTM-GAT network, taking the spatial topological graph structure as the input of a graph attention mechanism, extracting the time dependence characteristics of the gas injection well and the production well by using the long short-term memory network, and extracting the spatial dependence relationship of the gas injection well and the production well by using the graph attention mechanism so as to output the predicted yield of the production well at the future moment; constructing a fitness function, and introducing a whale optimization algorithm to perform global optimization on the injection-production parameters to obtain an optimal injection-production parameter combination; and outputting the optimal injection-production parameter combination. The problems that when an existing method is used for determining the inter-well communication relation, a large amount of geological data and experiment cost are needed, the analysis process is complex, consumed time is long, and accurate optimization of injection-production parameters is difficult to achieve are solved.

The invention discloses an integrated intelligent management and control method and system for underground water pumping and injection based on the Internet of Things, and the method comprises the steps: carrying out the geological investigation of a target region, constructing a three-dimensional geological model, and planning the layout of a pumping and injection well group and a sensor network according to the three-dimensional geological model; deploying a monitoring network and collecting data based on the layout scheme, and fusing a three-dimensional geologic model to construct a polluted site digital twinborn body; groundwater situation data are extracted through the digital twinborn body, a pollutant migration path and a water level dynamic state are predicted by using an LSTM model, and pollution scene simulation information corrected by geologic features is output; by taking the simulation information as input and coupling geological parameters as constraints, generating a pumping and injection well group cooperative control strategy set by adopting a BLMFO double-layer multi-objective optimization algorithm; and finally, a control instruction is executed, the real-time situation is monitored in the repairing process, strategy change suggestions including the flow adjustment amplitude, the agent optimization scheme and equipment operation parameter correction are judged and pushed, the repairing efficiency is improved, and the method adapts to the complex geological environment.

The invention relates to the technical field of oil-gas field development and geothermal energy utilization. The invention provides an underground high-temperature composite fluid heating system, which comprises a crude oil separation device, a catalysis module, a high-temperature fluid generation module, an injection well pattern module, a target reservoir and a production well, and is characterized in that the crude oil separation device is communicated with the catalysis module through a first gas inlet pipeline and a second gas inlet pipeline; a first gas outlet pipeline and a second gas outlet pipeline are communicated with a high-temperature fluid generation module, the high-temperature fluid generation module is communicated with an injection well pattern module through a third gas outlet pipeline, the injection well pattern module is communicated with a target reservoir, and the target reservoir supplies energy to the outside through a fourth gas outlet pipeline. And the production well conveys the energy-supplied gas to the heat energy recovery device through the first recovery pipeline. In this way, efficient and uniform heating of the underground reservoir is achieved, energy consumption is reduced while the energy recovery efficiency is improved, and the problems of low heat conduction efficiency and high energy consumption in deep oil gas and hot dry rock development are solved.

The invention provides a layout method and system for a carbon dioxide injection well and a pressure control well. The method comprises the steps that the reservoir thickness, porosity, permeability and formation pressure distribution data of a target reservoir are obtained; determining a deployment area according to the reservoir thickness, the porosity, the permeability and the formation pressure distribution data; based on a preset carbon dioxide injection well distance, carbon dioxide injection wells are arranged in the deployment area in an equilateral triangle grid mode; and a pressure control well is laid based on the center of the equilateral triangle grid, and the layout of the carbon dioxide injection well and the pressure control well is obtained. According to the technical scheme, the carbon dioxide injection well and the pressure control well are reasonably arranged, and the safety and economical efficiency of carbon dioxide geological sequestration are improved.

The invention belongs to the technical field of carbon dioxide capture and utilization and geological sequestration, and discloses a numerical simulation method for migration of CO2 in stratum.The method comprises the steps that an actual stratum complex geological model is constructed, and then a numerical simulation model is obtained; finely adjusting the numerical simulation model to limit fluid channeling and external substance and energy exchange, and ensuring rapid convergence of operation; the injection of CO2 in different layers is simulated, and the influence of the injection layers on the migration law is analyzed; cO2 injection at different injection speeds and temperatures is simulated to analyze the influence of the injection speeds and temperatures on the migration law; cO2 is simulated to be injected at different injection temperatures under the condition of consistent initial salt concentration, and the influence of dissolved salt on migration and dissolution rules is analyzed; the injection of CO2 at different positions of the reservoir is simulated, and the influence of the injection well position on CO2 storage is analyzed; and optimizing well position arrangement to obtain an optimal well pattern scheme. According to the method, the results of various influence factors are comprehensively analyzed, and then the migration rule of CO2 in the stratum is accurately obtained.

The invention discloses an oil reservoir water content prediction method based on a graph neural network and Transform, and belongs to the technical field of oil and gas field development, and the method comprises the following steps: S1, converting an oil reservoir injection-production model at each time point into a graph structure, and constructing a connection network from a water injection well to a production well; and S2, constructing a GNT proxy model in combination with the graph neural network and Transform, training the GNT proxy model, and predicting the water content of each production well. According to the constructed GNT proxy model, an oil reservoir injection-production structure is converted into graph data through a GCN module, the information transmission strength between nodes is dynamically adjusted through an edge feature enhanced message transmission mechanism, and inter-well communication features are accurately captured; and the multi-head self-attention mechanism of the Transform encoder module is combined to process the time sequence dependence, so that the long-distance time dynamic relationship is effectively modeled, and an efficient and reliable agent model is provided for the dynamic analysis of the oil reservoir.

The invention provides a safety risk control method for geological storage of carbon dioxide and electronic equipment. A distributed optical fiber sensing system is arranged in at least one injection well of the target sealing and storage area in the axial direction of a shaft and penetrates through a main cover layer and a reservoir; the method comprises the following steps: acquiring background data through a distributed optical fiber sensing system, and establishing a multi-parameter baseline model including a temperature field, a strain field and background noise; temperature, strain and sound wave vibration signals are collected in real time, and key features are extracted; the key features extracted in real time are compared with a preset risk feature library, the types of risk events are identified, and the identified risk events are graded according to the spatial range and intensity of the abnormal signals; and according to the type and the grade of the risk event, generating and executing a corresponding control instruction. According to the embodiment of the invention, the optical fibers are distributed in the whole area along the shaft and the target stratum, a three-dimensional monitoring network covering the sealing body is constructed, and the hysteresis quality of traditional point type measurement and periodic exploration is overcome.

The invention provides a layered water injection well injection profile testing system, electronic equipment and a storage medium, and the system comprises a plurality of visible light communication modules which are respectively installed on eccentric water distributors of all water injection layers and on water injection pipe couplings between any two water injection layers; the plurality of sensing monitoring modules are mounted on the eccentric water distributor and are used for acquiring underground monitoring data of the layered water injection well; and the upper computer terminal is used for processing the underground monitoring data based on the group strategy optimization model to obtain an optimized water injection strategy, further generating a water injection control instruction, and transmitting the water injection control instruction to the eccentric water distributors of the water injection layers through a downlink channel. According to the scheme, the LED is used for transmitting data under the dark well, the problems existing in an existing transmission mode are solved, the original water injection well layout structure is not changed through installation of the hardware module, space is saved, and more stable and reliable light transmission can be achieved.

The utility model discloses a well structure for injecting a suspended state repairing agent. The well structure comprises an injection well, a lower end injection pipeline and an upper end injection pipeline, wherein the lower end injection pipeline downwards penetrates into the injection well from the top of the injection well; the upper end injection pipeline is arranged on the side wall of one side of the top of the injection well; and a Y-shaped tee joint is arranged at the bottom of the lower end injection pipeline. By adopting the well structure, the migration and distribution uniformity of the suspended state repairing agent is remarkably improved, the reaction efficiency with pollutants is enhanced, meanwhile, the repairing cost is reduced, the construction period is shortened, and the repairing quality is ensured. Meanwhile, the problem that in a traditional injection method, when the repair depth exceeds the injection range or the repair medium is bed rock, it is difficult to inject suspended-state repair agents is solved.

The invention discloses a CCUS experimental device and method for carbon dioxide flooding and storage, and relates to the technical field of petroleum engineering. The device comprises a three-dimensional oil reservoir physical model, a fluid injection system, a fluid collecting and metering system, a resistivity monitoring system and a fluid migration observation system. The three-dimensional oil reservoir physical model is used for constructing a simulated stratum, and a development well pattern system is installed on the simulated stratum; the fluid injection system is connected with the injection well; the fluid collecting and metering system is connected with the production well; the resistivity monitoring system is provided with a plurality of monitoring points on the simulated stratum; the fluid migration observation system is used for observing a migration path of supercritical carbon dioxide in the three-dimensional oil reservoir physical model; and the distributed optical fiber monitoring system is arranged in the simulated stratum. According to the device and the method, oil reservoir water injection exploitation and CO2 injection oil displacement and CO2 storage stability simulation experiments in the later development period can be realized.

The invention discloses a carbon dioxide geological sequestration leakage monitoring and early warning system. The system comprises a sensor arrangement module, a data acquisition and processing module, a prediction and early warning module and a linkage control module. The sensor laying module is used for laying pressure sensors, temperature sensors and microseism monitoring equipment on an injection well, a monitoring well and the ground surface, and real-time collection of pressure and temperature of a reservoir and a shaft is achieved by combining distributed optical fiber temperature measurement. And the data acquisition and processing module performs dynamic fitting and trend analysis on the multi-source monitoring data, and calculates to obtain a pressure evolution function. The prediction and early warning module predicts a future pressure state through a threshold value judgment and prediction model and automatically sends out an early warning signal when the future pressure state is close to a critical value, the linkage control module is combined with the injection control unit, the injection rate can be automatically adjusted or adjusted in an auxiliary mode according to an early warning result, risks are reduced, and safety is improved. The system can significantly improve the safety and reliability of carbon dioxide geological sequestration.

The invention discloses a carbon sequestration CO2 multi-layer injection and production collaborative balance system and method.The carbon sequestration CO2 multi-layer injection and production collaborative balance system comprises a multi-layer injection mechanism, a collaborative extraction mechanism and a regulation and control mechanism, the multi-layer injection mechanism comprises an injection well, an injection allocation device and a two-way packer, the injection well vertically penetrates through 2-4 target reservoirs, and the injection allocation device vertically penetrates through the two-way packer; each target reservoir in the injection well is correspondingly provided with an injection allocation device and a two-way packer, each injection allocation device comprises a pressure sensor, a flow controller and a communication module, the collaborative extraction mechanism comprises a plurality of water production wells, the water production wells are arranged on the periphery of the injection well, and the two-way packers are arranged on the periphery of the injection well. Each water production well corresponds to one target reservoir, an adjustable water pumping screen pipe, a pressure feedback valve and a flow metering device are correspondingly arranged in each water production well, the regulation and control mechanism comprises a controller and an optical fiber monitoring device, and the controller is electrically connected with the optical fiber monitoring device, the pressure sensor, the flow metering device and the pressure feedback valve. The carbon sequestration CO2 multi-layer injection-production collaborative balance system provided by the invention has the advantages of high safety and high efficiency.

The invention discloses a coal underground gasification injection-production well pattern determination method, device and equipment and a medium. The method comprises the steps that an injection well site is determined according to a gasification control area of a target reservoir development body, and an injection well bore structure is determined according to injection conditions and coal seam parameters corresponding to the gasification control area; determining a migration path concentration area and an enrichment area of preset generated gas, and determining a production well site according to the migration path concentration area and the enrichment area of the preset generated gas; and according to the injection well site, the injection well body structure and the production well site, coal underground gasification injection-production well pattern distribution of the target reservoir development body is determined. According to the technical scheme, by selecting the proper injection well site, the injection well body structure and the production well site, coal underground gasification injection-production well pattern distribution is determined, coal underground gasification injection-production well pattern deployment is achieved, and the coal seam combustion rate and the preset generated gas recovery rate are increased.

The application discloses an intelligent identification method for dominant seepage channels based on big data, which comprises the following steps: collecting static geological data, dynamic development data and dynamic monitoring data of an oil reservoir and performing data processing; performing data quality analysis on the processed data and establishing a sample database; performing inter-well connectivity analysis and inter-well pressure response analysis in a plane according to the sample database, and identifying dominant channels in the plane; performing interlayer production and absorption law research in a vertical direction according to the sample database, predicting interlayer liquid production and absorption ratios and water cut, and identifying dominant interlayer positions in the vertical direction; and comprehensively identifying dominant seepage channels between each layer of a production well and an injection well based on the identified dominant channels in the plane and the dominant interlayer positions in the vertical direction.

The invention provides a carbon dioxide injection well perforation parameter optimization method and device and electronic equipment, and the method comprises the steps: carrying out the standardization processing of geological and logging data, and constructing a multi-dimensional data set comprising lithology, porosity, permeability, crack parameters and a ground stress field; a three-dimensional digital twinborn model is constructed based on the data set, and reservoir heterogeneity and fracture network distribution are restored; on the basis of the digital twinborn model, performing multi-physics field coupling simulation including carbon dioxide migration simulation, shaft stress distribution simulation and long-term corrosion prediction; based on a multi-objective optimization algorithm, with the effective wave and volume of the carbon dioxide, the integrity coefficient of the shaft and the anti-channeling safety coefficient as objectives, an optimal perforation parameter combination is screened; and outputting a visual report including perforation parameters, simulation results and risk assessment. Digital twinning, multi-physics field simulation and multi-objective optimization are deeply fused, and a set of complete, accurate and efficient perforation parameter optimization solution from data to decision is formed.

The invention discloses an active treatment method for multi-source residual coal gas of a waste mine, which comprises the following steps: firstly, hydraulic fracturing pressure relief permeability improvement and overlying strata separation layer grouting reinforcement are cooperated, the hydraulic fracturing pressure relief permeability improvement establishes a netted fracture network in a coal body to realize permeability improvement, and the overlying strata separation layer grouting reinforcement compacts goaf gangue through grouting and reinforces an overlying strata to form a continuous bearing consolidation body; and therefore, a pressure relief and permeability increasing-strengthening and reinforcing integrated structure is formed, a stable structure and a penetrating seepage network are provided for subsequent displacement and gas extraction, and the subsequent gas extraction efficiency is guaranteed. Then low-temperature liquid CO2 is injected into the coal seam through the injection well, gas displacement and desorption are conducted on gas adsorbed in the coal seam under the action of phase change and competitive adsorption, expansion and development are conducted on fractures to enable permeability to be secondarily enhanced, and meanwhile part of CO2 obtained after displacement is retained and sealed in a coal body and a goaf; on the premise that the gas extraction concentration and efficiency are effectively improved, CO2 can be stored, and the dual effects of resource utilization and carbon storage are achieved.

The invention discloses a gas injection well underground oil pipe leakage monitoring system and method, and the method comprises the steps: placing an optical fiber in an oil pipe, placing the optical fiber in a designated position in the oil pipe, injecting gas into the oil pipe until a pressure difference is generated, stopping gas injection, closing a valve of the oil pipe, and standing for a period of time; amplitude basic noise and phase basic noise in a stable state at the moment are collected; continuing to wait for a period of time to increase the pressure in the well to a specified value, opening a casing valve, collecting corresponding sound wave data, closing the casing valve if the suspected leakage position cannot be found by amplitude data, repeating the previous operation, collecting sound wave data of a plurality of pressures, and determining the leakage position. And performing spectral analysis on the data collected at the highest pressure until the amplitude can distinguish the suspected leakage position or the pressure cannot be continuously increased to find the suspected leakage position, and judging the leakage position and the leakage type according to the amplitude signal intensity and the frequency range of the phase. Therefore, according to the method, the leakage position and the leakage type are judged by monitoring and analyzing the collected data.

Various examples are provided related to airlift pumping of downhole geothermal fluids. In one example, an airlift system includes a compressor; a gas sparger head in a wellbore of a geothermal well, and a pressure head recycle assembly. The sparger head produces artificial lift of the geothermal fluids by injecting a gas resulting in a difference in density downhole. The entrained gas can be extracted by the pressure head recycle assembly, compressed, and reinjected downhole. The geothermal fluid at the well head can be used in direct use applications or in a thermodynamic cycle to make shaft power. The gas sparger head can include a venturi shaped passage extending through the gas sparger head and a bubble orifice including gas orifices radially spaced about a narrow portion of the venturi shaped passage. The gas orifices can have a corresponding resonant chamber through which the gas (e.g., air) is provided.

The invention relates to the technical field of soil and groundwater pollution remediation, in particular to a polluted groundwater source controlling and breaking system suitable for limited space of an industrial accumulation area, which comprises a main well, a gas stripping circulating unit and a groundwater circulating unit. A blocking device composed of a packing rubber structure and a driving device is arranged in the main well, the packing rubber structure is driven by the driving device to move and intermittently inject air to expand, and an air flow channel which is dynamically opened and closed is formed between the inner wall of the main well and the unsaturated area. The vacuum pump device builds negative pressure on the upper portion of the main well, so that purified clean gas enters an unsaturated area in an intermittent pulse mode through the peripheral injection well, and soil gas is induced to flow in an oscillating mode under cooperation of the dynamic gas flow channel. Groundwater extracted by the centrifugal pump is purified by the gas stripping area and the underground activated carbon filtering device and then is discharged into the top of the unsaturated area through the drainage device in an intermittent wave mode, the system is suitable for pollution treatment in the limited space of the industrial accumulation area, and targeted source control and long-acting reduction are achieved.

A monitoring system for monitoring a geological formation includes a casing of an injection well, wherein the casing is configured to extend through an open hole of the geological formation to define an annular space between the casing and the open hole, and wherein the casing includes a mandrel circumscribing at least a portion of the casing, and one or more monitoring lines configured to monitor the geological formation for the presence of carbon dioxide, wherein the one or more monitoring lines are at least partially integrated with the mandrel.

The conveying and injecting system comprises a main pipeline, a cooling device and a supercharging device, the main pipeline is used for receiving supercritical carbon dioxide from a carbon dioxide capturing device, and the other end of the main pipeline is connected with an inlet of the cooling device; the cooling device is used for cooling the supercritical carbon dioxide to a preset temperature, so that the supercritical carbon dioxide is converted into dense-phase carbon dioxide, an outlet of the cooling device is connected with an inlet of the pressurizing device, an outlet of the pressurizing device is used for being connected with an injection well, and the pressurizing device is used for pressurizing the dense-phase carbon dioxide to a preset pressure. According to the conveying and injecting system, carbon dioxide is conveyed to the vicinity of a sealing place in a supercritical phase state in a long distance in the main pipeline and then conveyed to the injecting well after being cooled and pressurized, and the pressure of supercritical carbon dioxide is smaller than that of dense-phase carbon dioxide, so that the risk that the main pipeline is broken can be reduced; and the stability and safety of carbon dioxide conveying are improved.

The invention discloses an intelligent self-adaptive injection flow regulation and control system for geological storage. The system comprises a sensor module, a data processing module, an execution mechanism module and a self-adaptive algorithm module, the sensor modules are distributed in an injection well and a surrounding monitoring well and are used for acquiring pressure, temperature and flow data in real time; the data processing module performs normalization processing on the monitoring data and extracts dynamic characteristics; the adaptive algorithm module integrates a multi-parameter coupling regulation and control model constructed by fuzzy PID and an LSTM neural network, predicts the trend of a seepage field and generates a regulation and control instruction; the execution mechanism module adjusts an electric control valve group and a variable-frequency injection pump according to instructions, so that the error between an actual injection curve and a target parameter curve is smaller than 5%. All the modules form a closed-loop control system through an industrial Internet of Things platform, the LSTM neural network updates weight parameters every 30 minutes, and a fuzzy PID controls an integral time constant to be automatically adjusted. The system is suitable for geological storage of CO2, accurate regulation and control of the injection flow can be achieved, and the leakage risk and the injection energy consumption are reduced.

The invention discloses a quantitative calculation method for analyzing injection-production dynamic response by using time sequence interference. The quantitative calculation method comprises the following steps: S1, acquiring time sequence data of output and water injection rate; s2, taking the change of the water injection rate as an intervention event, and establishing a virtual interference variable; s3, taking the oil well output as a target variable and substituting the target variable and the virtual interference variable in the S2 into an SARMAX time sequence model for fitting; s4, judging the significance degree of the model by using the residual error of the model, and if the residual error is a random time sequence, ending; if the residual sequence of the model is non-white noise, going to S5; s5, determining autoregression and moving average orders by using an ARMA (p, q) model; s6, substituting order information into the model in the S3 for re-fitting; and S7, repeating the steps S3-S6 until the model is significant. The method can quantitatively evaluate the influence degree of the injection well on the output. Quantifiable data are provided for evaluation of production and injection dynamic influences in oil reservoir dynamic management, reasonable injection and production adjustment countermeasures are formulated accordingly, oil reservoir production dynamic management is guided, and the oilfield exploitation effect is guaranteed.

The invention discloses an artificial geothermal reservoir construction and development method based on oil shale reverse oxidation, and belongs to the technical field of resource exploitation, the method comprises the following steps: reservoir well construction: arranging an injection well, an exploitation well and a heat recovery well in a target layer section; an initial high-temperature environment is formed through manual heating, so that the oil shale is pyrolyzed to generate fixed carbon; injecting air to form an oxygen-enriched environment, initiating a fixed carbon oxidation self-heating reaction, and continuously pyrolyzing the oil shale; terrestrial heat is exploited through a circulating working medium, the air flow and components are dynamically controlled, and temperature control and safe operation are achieved; and finally reinjecting and sealing the carbon dioxide. The device can convert low-grade oil shale into clean geothermal energy, and has the advantages of energy conservation and environmental protection.

An in-situ large-area drilling and furnace construction method for coal gasification and co-mining of kerosene and / or coalbed methane is provided, which includes: constructing an injection well to the target coal seam and then constructing a horizontal well to divide the target coal seam into sections of coal; extracting coalbed methane; transforming the horizontal wells on both sides of the coal in the first section of coal into coal gasification production wells, and dividing them into intake and exhaust channels; constructing ventilation boreholes to form a “honeycomb shaped” gasifier, which ignites and gasifies to promote the production of combined gases from combustion; after the combustion of first section of coal is completed, continuing to construct the next section of coal and drill holes between adjacent horizontal wells to achieve continuous coal seam combustion and gasification. The method of the present disclosure can improve combustion efficiency and increase kerosene extraction efficiency.

The invention provides a blowout control method based on wellhead methane adsorption, which comprises the following steps of: compounding a methane adsorption material with other necessary drilling fluid additives to form high-density composite well killing fluid in a key stage (namely when well control dangerous conditions such as overflow or well kick occur) before blowout; and then, at the position 100-200 m below a well mouth, the composite well killing fluid is injected into a shaft through special well killing fluid injection equipment according to preset injection parameters. According to the method, slipping and rising of methane bubbles invading a shaft are effectively restrained through the high density of well killing fluid, meanwhile, methane gas in the shaft is adsorbed in real time through a methane adsorption material compounded in the well killing fluid, gas column expansion and pressure rising are effectively controlled in the early stage of gas invasion through the dual-action mechanism of density suppression and active adsorption, and the gas invasion safety is effectively improved. Therefore, blowout is prevented or development of blowout is restrained.

A method of generating biogas is disclosed, including delivering a feedstock downhole to a coal reservoir, generating biogas within the coal reservoir, and harvesting the biogas. The method comprises delivering a feedstock downhole to a coal reservoir via an injection well, generating biogas within the coal reservoir through microbial action, creating a biogas that is isotopically differentiable from a background gas that is native to the coal reservoir, harvesting the biogas at the injection well and one or more offset wells of the coal reservoir, analyzing the biogas and coal bed methane from the coal reservoir at the injection well and at one or more offset wells within the same coal reservoir, detecting the biogas at the offset wells using isotopic differentiation, and mapping the migration of the biogas from the injection well to the offset wells using the biogas as an isotopic tracer.

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 belongs to the technical field of uranium mining, and particularly relates to a sodium persulfate acid oxidation green in-situ leaching uranium mining method. The method comprises the following steps: (1) exploring and pretreating an ore bed; (2) arranging an injection well and an extraction well; (3) preparing an acidic leaching solution; (4) injecting a leaching solution; (5) in-situ leaching circulation and monitoring; and (6) post-harvest treatment. The novel green acid in-situ leaching uranium mining method is developed, the oxidation rate of tetravalent uranium can be greatly increased, the uranium leaching rate is increased, and compared with an existing acid leaching method, the uranium leaching rate is remarkably increased, and environmental protection is achieved.

The invention discloses a coal bed gas exploitation and separation utilization method based on SCCO2 assistance, and belongs to the technical field of coal bed gas development. Supercritical carbon dioxide is prepared through a high-pressure reaction kettle and stored in a supercritical carbon dioxide storage and collection tank, meanwhile, nitrogen mixed with graphene is introduced, and CO2 / CH4 adsorption selectivity is enhanced by means of the characteristic that the specific surface area of graphene is large. A variable-frequency sound wave diffuser is matched to excite coal seam micro cracks through low-frequency sound waves, and supercritical carbon dioxide and nitrogen mixed gas is injected into a coal seam injection well. In the injection process, the sound wave diffuser synchronously radiates high-frequency sound waves to improve the displacement efficiency, then the gas enters the gas separation tower integrated with the molecular sieve membrane, and the produced gas is divided into upper methane, middle carbon dioxide and other bottom miscellaneous gas. Methane is pressurized by an air compressor and then stored in a methane storage tank, carbon dioxide is purified and pressurized and then recycled for coalbed methane exploitation, and offensive gas is cooled and stored after generating power by a steam turbine. And efficient mining, separation and multi-path utilization of the coal bed gas are realized.