70 results about "Geologic sequestration" patented technology

The invention is applicable to the technical field of coal bed gas development and geological sequestration, and provides a THMC multi-field coupling simulation method and system for a process of displacing CH4 by coal bed CO2, and the method comprises the following steps: collecting multi-source parameter information of a target coal bed; according to the multi-source parameter information, constructing a coal seam structure model comprising a matrix and a crack system; constructing a control equation system based on the coal seam structure model, and introducing a multi-field coupling mechanism to obtain a fully-coupled mathematical model; performing numerical solution on the fully-coupled mathematical model to obtain a spatio-temporal evolution result of the key field variables; and according to the spatio-temporal evolution result of the key field variable, evaluating the index of the target coal seam. According to the invention, a heat-force-gas-chemical multi-physical field full-coupling simulation system is constructed, so that the CH4 recovery rate and the CO2 storage stability can be accurately predicted. The method is suitable for gas injection-storage coupling optimization of a multi-coal-rank and low-permeability coal seam, and has high precision, high adaptability and remarkable engineering guidance value.

The invention discloses a deep coal seam CO2 storage potential calculation method based on coal seam geological characteristics, and belongs to the technical field of CO2 geological storage. The method comprises the following steps: firstly, acquiring excess adsorption quantity of CO2 adsorbed by a coal seam under different time actions, and constructing an adsorption quantity calculation model under different time parameters by utilizing a relationship between the excess adsorption quantity and absolute adsorption quantity; then fitting porosity data under different adsorption times, and constructing a coal quality unit mass CO2 free quantity model; then, according to the CO2 solubility calculation model and the characteristic parameters of the target coal seam, a unit mass CO2 dissolved amount model is constructed; then, data of the relation between the migration distance of CO2 in the coal seam and time is taken, and a time-migration distance formula is fitted; and finally, establishing a unit mass coal sample supercritical CO2 storage capacity calculation model, and constructing a theoretical storage amount and actual storage amount equation of CO2 geological storage. By adopting the calculation method, a theoretical reference can be provided for shut-down coal mine CO2 sequestration development and utilization strategy research and sequestration address selection.

The invention discloses a shaft operation state intelligent prediction method based on a hybrid deep learning framework, and belongs to the field of petroleum engineering oil-gas field development engineering, and the method comprises the following steps: building a geological sequestration shaft transient temperature-pressure coupling mathematical model, and carrying out the numerical solution; constructing a double sequence feature database covering CO2 injection and leakage working conditions; adopting a parallel architecture to process the double sequence features to construct an improved double attention network; the method comprises the following steps: establishing a hybrid deep learning framework DT-DANet by coupling an improved double attention network and a time fusion Transform; and carrying out collaborative optimization training on the hybrid deep learning framework by adopting a composite loss function, wherein the output of the framework is a wellbore pressure profile, a temperature profile and phase state distribution under different time steps. According to the method, high-precision prediction of shaft multi-parameter dynamic evolution in the CO2 geological storage process is realized.

The invention discloses a storage potential prediction method and system based on a mine water depth geological storage technology, and relates to the technical field of mine water treatment.The method comprises the steps that monitoring data of a plunger pump opening in a target reservoir stratum are collected; and inputting the monitoring data into the trained storage potential prediction model, and evaluating the storage potential of the target reservoir based on the long-term pressure change trend of the storage potential prediction model. According to the invention, the storage potential of the reservoir can be effectively estimated.

The invention discloses a zero-carbon method for strengthening coal seam gas recovery and CO2 storage by using flue gas residual heat in the technical field of residual heat utilization, gas extraction and carbon emission reduction. The zero-carbon method comprises the following steps: step 1, collecting high-temperature flue gas in a power plant; step 2, performing high-temperature CO2 concentration-compression; step 3, reservoir evaluation and area selection; 4, designing and constructing a horizontal well; 5, high-temperature CO2 injection and joint control energy increasing are conducted, specifically, high-temperature CO2 is injected into a preset section through a pump, the injection pressure and the injection speed are adjusted through the joint control energy increasing technology, and the diffusion range and the diffusion speed of CO2 are controlled; 4, gas recovery and CO2 storage: high-temperature CO2 is used for providing energy to promote gas desorption on one hand, and the high-temperature CO2 and CH4 in the adsorption state are subjected to competitive adsorption on the other hand. The method is simple and easy to operate, the coal seam gas partial pressure is reduced through CO2 injection, the recovery efficiency is improved, CO2 can be adsorbed by a coal seam and stored in a reservoir, and geological storage of CO2 is achieved.

The invention relates to the technical field of coal mine gas control and CO2 geological storage, and particularly discloses a soft coal seam dynamic fracture self-adaptive CO2 displacement-anti-reflection integrated system which comprises a dynamic fracture monitoring unit, a CO2 collaborative anti-reflection unit, a self-adaptive regulation and control unit and a safety protection unit. The dynamic fracture monitoring unit is used for capturing coal seam fracture development dynamics and gas injection process parameters in real time; the self-adaptive regulation and control unit is in communication connection with the dynamic fracture monitoring unit, and the CO2 synergistic anti-reflection unit is in control connection with the self-adaptive regulation and control unit and is used for realizing CO2 enhanced anti-reflection displacement; the safety protection unit is used for guaranteeing system operation safety. According to the method, real-time adaptation of the coal seam fracture state and the injection-production parameters is achieved, the problems that in a traditional fixed parameter mode, the displacement efficiency attenuation is fast, and the coal body stability is poor are solved, the CH4 recovery rate and the CO2 storage rate are increased, and the safety and high efficiency of soft coal seam gas control operation are guaranteed.

A test system and method for determining migration front based on pulse pressure enhanced distributed strain belong to the technical field of CO2 geological storage and oil and gas resource development. The system includes a CO2 displacement brine unit, an optical fiber sensor, a pulse pressure injection unit, a data acquisition and processing system, etc. By injecting high-pressure gas on the other side of the core, a large pressure difference is generated at the two-phase interface, which in turn causes significant strain changes. The optical fiber sensor monitors these strain changes in real time, and the data acquisition and processing system analyzes and determines the CO2 / saline migration front position. The method has the advantages of high monitoring accuracy, fast response, wide applicability, etc., and can dynamically track the migration of CO2 during the underground storage process, ensuring the safety and effectiveness of the storage.

The invention provides a method and system for directly utilizing and sealing flue gas of a coal-fired power plant, and the method comprises the following steps: carrying out filtering and impurity removal treatment on the flue gas of the coal-fired power plant to obtain treated flue gas; according to user requirements and actual production conditions, a target processing path is determined from multiple processing paths, and the multiple processing paths comprise geological storage, oil reservoir development, gas reservoir development and energy storage system power generation; according to the target treatment path, the treated flue gas is compressed in a corresponding compression mode and stored in a gas storage tank; treating the flue gas in the gas storage tank according to the target treatment path, and sealing and storing the flue gas; according to the system, the energy consumption and the cost of a carbon capture link can be reduced, and multi-treatment-path collaboration and benefit maximization are realized.

The invention discloses a coal rock carbon dioxide sequestration amount estimation method based on a CT image. The method comprises the following steps: S100, sample pretreatment and CO2 injection saturation treatment; s200, performing CT scanning and image processing; s300, reconstructing a three-dimensional model; s400, distinguishing the CO2 in the adsorption state from the CO2 in the free state; s500, the CO2 adsorption amount is calculated; and S600, calculating and verifying the unit assignment amount. The coal rock carbon dioxide adsorption capacity estimation method based on the CT image has the remarkable beneficial effects of improving the experiment efficiency, ensuring the data accuracy, reducing the cost, enhancing the intuition, promoting the environmental friendliness and the like, and provides powerful support for research and application of a coal rock CO2 geological storage technology.

The invention discloses a biological method for improving geological storage of CO2. The biological method comprises the following steps: injecting surfactant-producing microorganisms and CO2 into a geological reservoir; the geological reservoir is used for storing CO2, is a geological space containing formation water, and comprises at least one of a saline water layer and a depleted or abandoned oil and gas reservoir; the surfactant producing microorganisms metabolize to produce a biological surfactant; the biological surfactant is used for reducing the surface tension of formation water and promoting CO2 to be dissolved in the formation water, so that the injected CO2 is sealed in a dissolved state. According to the method disclosed by the invention, the gas-liquid surface tension is reduced and CO2 is promoted to be dispersed into a water phase by utilizing a surface active substance generated by metabolism of surfactant-producing bacteria, so that the dissolution and sealing efficiency of CO2 in a saline water layer is improved. In view of huge carbon emission reduction pressure faced by the industries of cement, steel, petrifaction and the like in China, the technology has a wide application prospect.

The invention provides an evaluation method for improving CO2 geological sequestration site screening and sequestration safety, and the method comprises the steps: obtaining a region plane structure map, a formation pore pressure gradient and a formation temperature gradient of a target layer through the analysis of geological data, and obtaining the pore pressure plane graphs and the formation temperature plane graphs of different target layers through calculation; and calculating a CO2 density plane graph and a CO2 solubility plane graph of different layers in combination with a formation fluid mineralization degree graph. On the basis, a CO2 geological sequestration capacity plane graph and a CO2 geological sequestration dissolution capacity plane graph can be calculated by combining a reservoir physical property plane graph and a CO2 sequestration coefficient. And then, according to the CO2 density map and the reservoir physical property map, a CO2 reinjection formation pressure change map is rapidly calculated. And an element superposition method is adopted to be combined with all the calculated elements, so that the region-level CO2 geological sequestration site comprehensive dessert plane graph can be obtained. According to the analysis method disclosed by the invention, rapid, efficient and quantitative CO2 site screening is ensured, and the limitation and subjectivity of the prior art are changed.

Embodiments of the present application relate to a carbon sequestration basic geology GIS data system platform and equipment. The platform comprises: a resource data layer configured to manage and organize regional spatial data, attribute data and resource data related to carbon sequestration; a technical support layer configured to be based on a preset platform to integrate object-oriented technology, component technology, GIS and Web GIS technology and three-dimensional modeling technology, including a spatial database for organizing the regional spatial data and a relational database for organizing the attribute data; a business application layer configured to provide a preset business according to a received user operation processing platform service function; and a user permission layer configured to manage application permissions of the preset business of a plurality of preset level users. Different users will be provided with source carbon reduction and carbon removal solution options, and scientific basis will be provided for CCUS regional large-scale deployment of geological sequestration site selection and large-scale demonstration of CCUS.

The invention belongs to the technical field of CO2 geological sequestration experiment evaluation in a CCUS-EOR project, and particularly relates to a carbon dioxide reservoir sequestration effect experiment comprehensive evaluation method. The method comprises the following steps: carrying out a carbon dioxide displacement saturated oil-water rock core experiment, simulating an actual oil reservoir CO2 injection and geological storage process, and calculating a storage evaluation index of CO2 in an experiment simulated oil reservoir on a rock core scale in combination with experimental test data; and quantitatively evaluating the carbon dioxide reservoir storage effect of the target reservoir under the corresponding working conditions by using the core scale CO2 storage index. The technical problem that a CO2 storage experiment method and a storage index quantitative evaluation method for oil reservoirs in the later stage of water flooding development are lacked at present is solved.

The invention belongs to the technical field of rock physics and multiphase flow coupling seismic wave propagation simulation, and discloses a wave velocity-attenuation whole-process calculation method based on an Lo two-phase fluid model. According to the method, thermodynamic characteristics of CO2-saline two-phase fluid are obtained by utilizing temperature and pressure conditions of a target reservoir, seepage characteristics are fitted according to experimental data, and a unified medium physical property layer is constructed by combining fluid parameters and rock skeleton parameters; after an elastic matrix, an inertia matrix and a viscosity matrix of a multiphase medium are calculated according to physical property parameters, phase velocity and attenuation characteristics of three types of longitudinal waves and one type of transverse waves are obtained through a Lo two-phase fluid model control equation. According to the method, a complete technical process from physical property construction, control equation solution to sensitivity judgment and mechanism analysis is formed, the method can be used for seismic monitoring, reservoir feature recognition and relevant parameter inversion in the CO2 geological storage process, and the method has good engineering applicability and popularization value.

The invention relates to the field of chain carbon management, discloses a full supply chain carbon management method and system for coupling carbon capture and storage of a coal-fired power plant, and is used for providing reliable technical guarantee for green transformation of the coal-fired power plant. Comprising the following steps: generating a global dynamic geological carbon potential field distribution diagram based on real-time working conditions and pre-evaluated geological attribute data of a storage library; generating a geological priority scheduling instruction for each batch of carbon dioxide according to the distribution map; when the carbon dioxide is injected into the conveying pipe network, creating and binding a globally unique carbon asset digital identifier for the carbon dioxide; and after injecting into the target sequestration library, accounting geological sequestration value data based on geological attributes and logistics information of the target library, and registering all the data to a trusted carbon asset account book to form a permanent carbon removal asset record. According to the method, safe optimal scheduling is realized through the geological carbon potential field, and high-quality and high-price carbon assets are realized by using geological value-added factors.

The invention discloses a coal-fired power plant CO2 geological storage and enhanced geothermal power generation combined site selection design method. The method comprises the following steps: collecting CO2 emission data and geographic position coordinates of each coal-fired power plant in a target area; generating a coal-fired power plant spatial distribution diagram in the ArcGIS platform; collecting geological data of a hot dry rock occurrence prospective area in the same target area; delineating and generating a hot dry rock occurrence prospective area distribution map in the ArcGIS platform; the distance from each coal-fired power plant to the nearest hot dry rock occurrence prospective area is calculated, so that the optimal CO2 storage place is matched for each coal-fired power plant; and calculating the transportation cost of transporting CO2 from each coal-fired power plant to the matched hot dry rock occurrence prospective area, and integrating all information to form a site selection design scheme. The method is suitable for areas where hot dry rock resources are widely distributed, the coal-fired power plant CO2 geological storage and enhanced geothermal power generation combined technology in the areas can be achieved, and the CO2 emission of the areas is reduced.

The utility model discloses a mine water storage well mouth pressure detector capable of self-adaptively adjusting, which relates to the technical field of mine water geological storage and comprises a shell, a fixing cylinder, a fixing lifting lug and a fixing pipe I. An adjusting mechanism is arranged on the inner wall of the bottom of the shell, and a limiting mechanism is connected above the adjusting mechanism. The limiting mechanism penetrates through the outer arc wall of the shell in the radial direction in a sliding mode, the adjusting mechanism comprises an inner gear ring rotationally connected to the inner wall of the bottom of the shell, the inner side of the inner gear ring is in meshed connection with a driven gear, and a fixed gear is coaxially fixed to the top end of the driven gear; according to the utility model, the limiting mechanism can be driven by the adjusting mechanism to stretch out and draw back so as to adapt to drill holes with different sizes, the flexibility and adaptability of installation are improved, and the sensor can be better attached to the inner wall of the drill hole during installation due to the design of the limiting mechanism, so that the measurement accuracy is improved; and the measurement error caused by a gap between the sensor and the inner wall of the drill hole is also reduced.

The invention discloses a system and a method for capturing and utilizing carbon dioxide. The system comprises a thermal power plant flue gas emission system, a CO2 capturing device, a multi-stage compression system, waste heat power generation equipment, a CO2 industrial production system, a CO2 agricultural production system and a geological storage system, the CO2 trapping device is communicated with a flue gas outlet of a flue gas emission system of a thermal power plant, a flue gas outlet of the CO2 trapping device is divided into two paths, one path is communicated with an inlet of the multi-stage compression system, an outlet of the multi-stage compression system is communicated with a carbon dioxide inlet of the waste heat power generation equipment, an inlet of the CO2 industrial production system and an inlet of the CO2 agricultural production system, and the other path is communicated with an outlet of the CO2 industrial production system. By means of the system and the method, coupling of the thermal power plant and a plurality of independent systems can be achieved.

The invention discloses an optimal selection method for a geological storage position of a water depth part of a mine. The optimal selection method comprises the following steps: S1, basic geological exploration; s2, stratum parameters are collected; s3, reservoir physical property analysis; s4, safety and environmental protection comprehensive evaluation. According to the method, the principle is scientific, operation is easy, the sand-mud ratio, the porosity and the permeability are calculated through the well logging calculation model, the sealing target layer with the high sand-mud ratio, the large porosity and the high permeability is optimized according to the sand-mud ratio, the porosity and the permeability, and the method has high safety, saves energy, is environmentally friendly and is high in water storage efficiency.

The invention discloses a coal-series gas carbon dioxide production increasing simulation method based on a low-field nuclear magnetic resonance technology, and belongs to the technical field of coal-series gas development. The method specifically comprises the following steps: (1) simulating gas bearing conditions of different lithologic reservoirs under a waste condition; (2) identifying the occurrence state of polymorphic CH4 in each lithologic reservoir based on a low-field nuclear magnetic resonance technology; (3) CO2 is injected into all the lithologic reservoirs, and the CO2 air inflow in all the lithologic reservoirs is recorded in real time; (4) quantitatively representing the phase change of the multiphase fluid along with the CO2 injection time after the CO2 enters each lithologic reservoir based on the dynamic quantification of the multiphase fluid; and (5) constructing a response surface model, and determining the optimal injection condition of CO2. According to the method, the CO2 injection amount, the multi-state CH4 occurrence state change and the multi-phase fluid phase evolution in different lithologic reservoirs under the waste condition are monitored in real time, data support is provided for optimizing parameters such as CO2 injection pressure, temperature and duration, and the double targets of efficient utilization of coal series gas residual resources and CO2 geological sequestration are achieved.

The invention discloses a carbon dioxide energy-saving reinjection system and method based on geological sequestration, and belongs to the technical field of carbon dioxide reinjection, the system comprises a pressurization-air cooling system, an auxiliary cooling system and a restart auxiliary system, the pressurization-air cooling system is connected with an upstream carbon source and a downstream reinjection pipeline, so that a medium meets the requirement for stable reinjection pressure; the auxiliary cooling system is arranged on the downstream portion of the pressurization-air cooling system and used for conducting secondary temperature adjustment on high-pressure CO2 when the atmospheric temperature is high, and the temperature of CO2 injected into the reinjection system is reasonably reduced. And the restarting auxiliary system is arranged at a reinjection wellhead and is used for additionally injecting low-temperature CO2 into the wellhead for displacement of the wellbore medium after transportation stop, so that the density of the medium in the wellbore is improved, and the injection pressure of the reinjection ground system is reduced. Efficient, economical and safe CO2 energy-saving reinjection can be achieved, and the problems that due to the fact that the temperature of an injected medium is too high, utilization of the static pressure difference of a shaft is insufficient, and reinjection pressure is too high are effectively solved.

The application relates to the technical field of underground energy storage and CO2 geological storage, in particular to a crude oil injection-production storage system and a crude oil injection-production storage method. The crude oil injection-production storage system comprises an oil storage library for storing crude oil, a gas storage library for storing CO2, a first pipeline assembly with a first passage to connect the oil storage library and the gas storage library, and the first pipeline assembly is connected to a surface storage facility; a second pipeline assembly with a second passage to connect the oil storage library and the gas storage library, and the second pipeline assembly is connected to the surface storage facility; a valve assembly arranged in the first pipeline assembly and the second pipeline assembly respectively to control the connection state of the first passage and the second passage; wherein the oil storage library and the gas storage library are both salt cavern spaces formed by water-soluble mining of a salt rock stratum. The CO2 displacement does not cause water resource pollution and crude oil waste, effectively improves the salt cavern utilization rate and economic benefits, and realizes efficient utilization of CO2 and CO2 geological storage.

The utility model discloses a corrosion-resistant water delivery pipeline for geological storage of mine water, which relates to the technical field of water delivery pipelines and comprises a main pipeline, a first mounting frame is mounted on one side of the main pipeline, two second mounting frames are fixedly connected to the outer wall of one side of the first mounting frame, and a threaded rod is rotatably connected to the inner wall of the first mounting frame. The outer wall of the threaded rod is in threaded connection with a moving block, the outer wall of one side of the moving block is fixedly connected with a pushing block, the inner wall of each second mounting frame is provided with a double-pipeline linkage assembly, and the top end and the bottom end of the pushing block abut against the two sets of double-pipeline linkage assemblies correspondingly; according to the utility model, the double-pipeline linkage assembly is utilized to switch the water flow path through the linkage valve, and only the branch to be cleaned is closed under the condition that the main pipeline is not stopped, so that the condition of flow stop caused by cleaning of the branch is avoided, and the continuity of the flow is ensured.

The utility model discloses a multifunctional mine water geology sealing pipeline cleaning device, which relates to the technical field of pipeline cleaning and comprises a mounting shell, a motion adjusting component is mounted in the mounting shell, and the bottom end of the motion adjusting component is fixedly connected with a cleaning component; the motion adjusting assembly comprises a rocker rotationally connected with the inner wall of the mounting shell, one end of the rocker is fixedly connected with a first transmission wheel, and the outer wall of the first transmission wheel is sleeved with a transmission belt. In the utility model, the movement adjusting component is matched with the cleaning component to realize that the mechanical energy is directly converted into the rotation and linear movement of the cleaning brush head by manually rotating the handle, so that the dependence on electric power or compressed air is avoided, and the damage of environmental factors such as high humidity, much dust and electromagnetic interference on a power system is avoided; and the assembly can be immediately put into use without waiting for power supply connection or equipment debugging, so that the response time of emergency repair conditions is shortened.

The application provides an experimental measurement method and device for evaluating deep migration of a foamed formation, and a storage medium, and belongs to the technical field of oil and gas field development engineering and carbon storage engineering. The method comprises the following steps: adopting a variable-diameter core displacement to simulate the flow condition of a sudden drop of a flow rate and a pressure gradient when a formation injection fluid flows radially from a near-wellbore zone to a deep part of the formation, so as to make up for the defect that a conventional equal-diameter core displacement cannot simulate the flow condition; measuring the steady-state pressure gradient of each part of the variable-diameter core under a certain injection flow rate sequence, so as to effectively measure the critical pressure gradient and the critical flow rate condition required for foam generation, transportation and stable maintenance, and to evaluate the influence mechanism and law of each factor on the critical condition; and the method can be used for predicting the migration distance of the deep part of the foamed formation, and evaluating the feasibility and dynamic behavior law of large-scale foam mobility control, and has important significance for guiding and optimizing the engineering application of the foam mobility control technology in the fields of CO2 flooding and geological storage and deep profile control.

This invention belongs to the field of energy storage and carbon sequestration technology, and discloses a method and system for underground space energy storage coupled with abandoned mine CO2 sequestration and utilization. The method includes the core steps of site suitability evaluation and target layer selection, underground cavity sealing and reinforcement and functional zoning, construction of surface energy storage injection and production system, coordinated operation of energy storage and sequestration, and dynamic monitoring and control throughout the entire life cycle. The system consists of an underground energy storage cavity, an integrated surface energy storage injection and production system, and a multi-site coordinated monitoring and intelligent control unit. This invention uses supercritical CO2 as a common medium to simultaneously realize long-term peak-shaving energy storage for the power grid and large-scale geological sequestration of industrial CO2 within the same engineering system. Functional zoning is used to construct energy storage pressure regulating cavities and permanent sequestration cavities to meet dual operating conditions, and a multi-layer seepage-proof sealing structure and a full-cycle intelligent control system are used to prevent leakage risks. This invention solves the pain points of insufficient economic benefits of traditional CO2 sequestration projects and high construction costs of conventional supercritical CO2 energy storage.

The application discloses a CO2 geological storage reservoir parameter inversion method combined with well-seismic multi-source data, relates to the technical field of CO2 geological storage, and obtains multi-source observation data in the CO2 geological storage process; a priori geological model set for representing reservoir heterogeneity is established; an observation error covariance matrix for comprehensively reflecting multi-source observation uncertainty is constructed; forward calculation is performed on the priori geological model to obtain predicted observation data; high-dimensional observation information is processed in a dimension reduction manner; and reservoir model parameters are iteratively updated. The application implements reservoir parameter inversion by combining well time-series data and seismic spatial data, significantly reduces the posterior uncertainty range of key parameters such as reservoir permeability, improves the precision of CO2 plume distribution and storage amount prediction, and enhances the numerical stability and physical rationality of the assimilation process. The TSVD dimension reduction strategy is introduced to effectively solve the ill-conditioned problem and set degeneration phenomenon in high-dimensional data assimilation, and the robustness of the algorithm under the condition of high-dimensional observation data is ensured.

The invention discloses a comprehensive testing device and method suitable for CO2 geological storage cover layer valve pressure and breakthrough pressure. The device comprises a stress application module, an environment simulation module, a fluid control module, a sensing monitoring module, an auxiliary execution module and a control and display module. The environment simulation module constructs a stratum in-situ temperature and pressure environment through a reaction kettle with temperature controlled by a resistance wire and oil-filled confining pressure. The stress applying module reproduces a mining-induced stress path through a mining-induced stress servo press; the fluid control module realizes water-CO2 multiphase flow regulation and control by virtue of a double-phase injection pump and an external tempered glass sleeve, and is matched with a gas-liquid separation structure to guarantee data accuracy; the sensing monitoring module synchronously collects temperature, pressure and strain data. The testing method comprises the steps of sample loading, environment simulation, stress application, hydraulic seepage simulation, valve pressure measurement, breakthrough pressure measurement and sample unloading maintenance. According to the method, the environment reproduction degree and the test precision are improved, the test period is shortened, complex lithology and load scenes are adapted, and reliable support is provided for cover layer sealing capacity evaluation.

The invention relates to the technical field of coalbed methane extraction, in particular to an environment-friendly coalbed methane extraction system for promoting CO2 displacement by utilizing terrestrial heat, which comprises a bottom plate, an extraction pipe and a heat preservation cylinder, and is characterized in that a liquid pump, a second water pump and a first water pump are mounted on the surface of the upper end of the bottom plate, one end of the liquid pump is fixedly connected with a first conveying pipe, and the other end of the liquid pump is fixedly connected with a second conveying pipe; the heating pipe is arranged to wrap the extraction pipe and circularly heat the extraction pipe, on one hand, CO2 is promoted to drive methane, the extraction rate of the methane is increased, and water resources are saved, on the other hand, CO2 geological storage is implemented, the temperature effect is reduced, and the extraction efficiency of the methane is improved. The heating pipe can be well protected and prevented from being damaged by arranging a partition plate, a spring piece and a touch plate in cooperation with an auxiliary mechanism, the direction of the multi-head pipe can be conveniently adjusted, underground water in different directions can be conveniently pumped, and the water pumping efficiency is improved.

The invention discloses a coal expansion strain calculation method based on an optical fiber sensor and gas injection, and belongs to the technical field of monitoring of CO2 geological storage and oil and gas resource development. The method comprises the following steps: firstly, spirally packaging distributed optical fibers on the surface of a coal sample, and simulating formation temperature and pressure conditions through a triaxial stress system; then, compressed gas is injected, and full-field strain distribution is monitored in real time through the Rayleigh scattering optical fiber sensing technology; analyzing an edge effect and a confining pressure inhibition rule in the strain data; and finally, constructing a coal expansion model to quantify strain spatio-temporal evolution characteristics. Compared with a traditional method, the monitoring scheme is higher in resolution and higher in real-time performance, the migration state of the sealed gas can be dynamically tracked, and reliable data support can be provided for deep coal bed gas sealing safety assessment, injection parameter optimization and leakage early warning.