1021 results about "Coalbed methane" patented technology

The invention provides a coal bed gas productivity prediction method and system combined with artificial intelligence, and the method comprises the steps: firstly obtaining a multi-source coal bed gas productivity data set, which comprises geological structure data, reservoir physical property data and historical production dynamic data, of a target block, and then carrying out the time-space alignment processing of the multi-source coal bed gas productivity data set, the method comprises the following steps: obtaining a standardized coal bed gas productivity characteristic set, then performing characteristic extraction on the standardized coal bed gas productivity characteristic set to generate a prediction characteristic set containing geological attribute characteristic and dynamic attribute characteristic dual codes, and then performing iterative prediction on the prediction characteristic set based on a reinforcement learning strategy network. Finally, an optimization strategy set is generated according to the target coalbed methane productivity prediction result and error distribution of historical production dynamic data and fed back to a coalbed methane production control system to trigger parameter adjustment operation, and therefore the accuracy of coalbed methane productivity prediction can be improved, and optimization control over the production process is achieved.

The invention provides a method and device for determining the horizontal stress difference ratio of a deep coalbed methane reservoir, and relates to the technical field of deep coalbed methane exploration, and the method comprises the steps: obtaining the logging data and azimuth seismic observation data of the deep coalbed methane reservoir, building a reservoir parameter initial model of the deep coalbed methane reservoir based on the logging data, and obtaining the horizontal stress difference ratio of the deep coalbed methane reservoir; constructing a target functional for inverting deep coal bed gas reservoir parameters on the basis of azimuth seismic observation data and an azimuth seismic reflection coefficient equation, and solving the target functional on the basis of a generalized linear inversion theory and an iterative reweighted least square joint algorithm under the constraint of the initial model to obtain a reservoir parameter target model; and calculating the horizontal stress difference ratio of each sampling point in the deep coal bed gas reservoir according to the target model. According to the method, under the constraint of the accurate initial model, accurate estimation of the horizontal stress difference ratio of the deep coal bed gas reservoir is achieved, and the technical problem that an existing horizontal stress difference estimation method is low in accuracy is solved.

The invention provides a coal-bed gas well production dynamic analysis method and system based on AI time sequence prediction, and the method comprises the steps: firstly collecting a production dynamic data sequence of a coal-bed gas well, a corresponding well position geological condition data sequence and a surrounding environment data sequence, and constructing a ternary time sequence dynamic association network comprising node dynamic time sequence segments and a connection line real-time association relationship; and then calling a pre-trained AI time sequence coupling deviation evolution mining model to process the ternary time sequence dynamic association network to obtain a ternary time sequence coupling deviation result. And a deviation conduction closed-loop path is determined according to a ternary time sequence coupling deviation result in combination with forward conduction positioning and reverse tracing verification, and a deviation conduction analysis report is generated. And finally, generating a dynamic regulation strategy based on the deviation conduction analysis report in combination with a production dynamic prediction threshold value, outputting the dynamic regulation strategy to a production control terminal, and meanwhile, feeding back regulation data to update a network node association relationship, thereby realizing accurate analysis and regulation of the production dynamic state of the coal-bed gas well.

The invention relates to a horizontal well jet flow axial slotting pressure relief coal and coal bed gas co-mining method. The method comprises the steps of horizontal well building, axial continuous hydraulic slotting, coal bed drainage pressure relief and coal and coal bed gas co-mining. The axial continuous hydraulic slotting comprises the steps that a casing pipe is put into a horizontal well; a plurality of slots are formed in the sleeve, and a directional structure is arranged in the sleeve; the water jet tool pipe column is tripped into the casing pipe, and the lateral nozzle is kept to move directionally along the directional structure; when the lateral nozzle is aligned with the foremost slot, high-pressure water sprayed by the lateral nozzle penetrates through the foremost slot to impact the coal seam, and high-pressure water sprayed by the axial nozzle pushes the oil pipe to retreat; when coal seam slotting at each slot is completed, water injection is stopped, and the oil pipe is pulled backwards; when the lateral nozzle is aligned with the next slot, the high-pressure water sprayed out of the lateral nozzle penetrates through the next slot to impact the coal seam, and the high-pressure water sprayed out of the axial nozzle still pushes the oil pipe to retreat; and the steps are repeated till coal seam slotting at the last seam groove is completed.

The invention provides a cement paste system with high strength, elasticity and toughness and application of the cement paste system in deep coal bed gas horizontal well cementation, and the cement paste system is prepared from the following raw materials in parts by mass: 40-70 parts of oil well cement, 13-40 parts of fly ash, 15-45 parts of slag, 5.0-20.0 parts of water-based organic silicon resin, 0.1-0.5 part of ultra-high performance polyethylene fiber, 3.0-8.0 parts of calcium oxide and 2.0-5.0 parts of calcium sulfate whisker. 1.0-8.0 parts of nano silicon dioxide, 1.0-6.0 parts of a fluid loss agent, 0.5-2.0 parts of a drag reducer, 0.2-1 part of a defoaming agent and 50-80 parts of water. The cement paste system disclosed by the invention has the characteristics of remarkable low-temperature quick setting and high early strength, also has the advantages of low water loss, controllable thickening, simple preparation operation and the like, and set cement is high in compressive strength, high in breaking strength and very excellent in elastic and tough mechanical properties.

The invention provides a deep coalbed methane reservoir double-pore structure parameter prediction method and device, relates to the technical field of coalbed methane reservoir development, and solves the technical problem of low precision of a prediction result of pores of a deep coalbed methane reservoir. The method comprises the steps that based on the initial organic matter content, the clay content and the brittle mineral content, an equivalent medium theoretical model is used for establishing a coal bed gas reservoir double-pore coal rock physical model; calculating matrix porosity, fracture porosity and fracture aspect ratio according to logging observation longitudinal wave and transverse wave velocities in the logging data, and taking well-side matrix porosity, fracture porosity and fracture aspect ratio as pore parameter prior information of the coal bed gas reservoir double-pore coal rock physical model; and based on the specified three-dimensional seismic horizon data and the pore parameter prior information, pre-stack seismic inversion is carried out by using a pre-stack Bayesian inversion method through the coal bed gas reservoir double-pore coal rock physical model, and a coal bed gas reservoir double-pore reservoir prediction result is obtained.

The invention relates to a deep coal underground gasification method which comprises the following steps: drilling a plurality of gasification wells in a land parcel, sequentially arranging the plurality of gasification wells into three rows from the edge of the land parcel, and fracturing a bottommost coal seam; the first row of gasification wells are injection wells, the second row of gasification wells are production wells, and the bottommost coal seam between the first row of gasification wells and the second row of gasification wells is gasified; when the gasification high-temperature area of the gasified coal seam is expanded to the front edge of the gas cooling area, the second gas gasification well is closed, the third gas gasification well serves as a production well, and the coal seam continues to be gasified; meanwhile, a fourth row of gasification wells are drilled; after the coal bed is gasified, the bottommost coal bed between the second row of gasification wells and the third row of gasification wells is gasified, and so on, the bottommost coal bed between all the rows of gasification wells is gasified; meanwhile, cement paste is injected into the first exhaust gasification well to fill the gasified goaf; and so on, filling the goaf between each row of gasification wells; sequentially gasifying and refilling each coal seam from bottom to top according to the method.

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 high-strength low-density proppant as well as a preparation method and an in-situ generation method thereof. The proppant is prepared by compounding recycled glass fiber reinforced plastic powder or glass fiber powder with different meshes and recycled glass fiber reinforced plastic powder in different proportions and blending a styrene system / unsaturated polyester resin system in different proportions. The glass fiber reinforced plastic powder as the filler can improve the mechanical properties of the proppant, such as strength and toughness. The matrix is made of polystyrene or unsaturated polyester or other high polymer materials and is low in density. Therefore, the proppant has the characteristics of high strength and low density. The invention discloses a preparation method of a high-strength and low-density proppant, which can produce the high-strength and low-density proppant with uniform particle size distribution on a large scale by adopting a suspension polymerization method, and can efficiently recover a large amount of glass fiber reinforced plastic wastes. The suspension polymerization method is simple to operate, the produced proppant is high in roundness and sphericity, the mining cost of a coal-bed gas well can be reduced, and the yield of coal-bed gas can be increased.

The invention provides a deep coal seam fracture density azimuth seismic inversion method and device, and relates to the technical field of seismic exploration, and the method comprises the steps: obtaining pre-stack seismic trace set data and logging data of a research work area; constructing an elastic stiffness matrix of which each stratum is a VTI medium based on the logging data; processing the porosity of the coalbed methane reservoir in the logging data and an elastic stiffness matrix of the coalbed methane reservoir as a VTI medium according to a linear slip theory to obtain an elastic stiffness matrix of the coalbed methane reservoir as an orthotropic medium so as to determine an initial model parameter vector; combining a reflection coefficient approximation formula based on pre-stack seismic trace set data and orthoanisotropy to construct an objective function used for inverting model parameters; solving the target function to obtain a target model parameter vector of the research work area; and the target model parameters of the coal bed gas reservoir are processed by using the target prediction model to obtain the fracture density of the coal bed gas reservoir, so that an effective technical means is provided for inversion of the fracture density of the deep coal bed.

The invention belongs to the technical field of oil-gas field development, and particularly relates to a method for testing the content of adsorbed gas in a coal bed gas diffusion process. The problem that the desorption degree of coal bed gas cannot be clearly known at present is solved. According to the technical scheme, high-temperature and high-pressure isothermal adsorption experiments under the condition of different gas proportions are carried out, methane adsorption-desorption capacity of mixed gas of different proportions under different partial pressures is determined, gas diffusion experiments are carried out to evaluate gas migration capacity in the diffusion process and methane gas partial pressure distribution in a sample, and different experiment results are synthesized to determine the methane gas content of the sample. The desorbed gas content in the coal bed gas diffusion process can be calculated; according to the new method, the proportion of the methane desorption gas amount in the coal bed gas development process can be calculated, and the desorption degree of the adsorbed gas of the coal bed reservoir is evaluated.

The invention discloses a multielement multiphase fluid displacement coalbed methane 4D visual simulation experiment system and a multielement multiphase fluid displacement coalbed methane 4D visual simulation experiment method. The system comprises a gas-liquid mixed injection system, a Kr adsorption system, a visual triaxial core holder system, a CT scanning system and a tail gas analysis and treatment system. According to the experimental method, Kr similar to CH4 in dynamic diameter and other parameters is selected as a CT tracer to replace CH4, and 4D visualization of coal body internal pore and fracture structure evolution and Kr concentration field displacement migration process can be realized through three-dimensional reconstruction of CT images at different displacement moments and registration, gray correction and normalized concentration calculation of the images. The problem that the gas migration rule in the coal body in the displacement experiment is not clear is solved; the dynamic diffusion process inversion of the coal bed gas in the coal bed difficult to extract is realized by utilizing the distribution characteristic evolution of the Kr gas in the coal body, so that the in-situ coal body fissure structure in the coal sample and the dynamic migration law of methane in the displacement process are obtained, and the method has great significance for revealing the displacement development mechanism of unconventional natural gas such as the coal bed gas.

The invention belongs to the technical field of deep coal bed gas development, and particularly relates to a visual simulation device and method for gas and water flow behaviors in deep coal reservoir microfracture.The device comprises a transparent high-temperature and high-pressure experiment cavity used for containing a sample; the outlet end of the gas-water injection-output system is communicated with the inlet end of the transparent high-temperature and high-pressure experiment cavity, and the inlet end of the gas-water injection-output system is communicated with the outlet end of the transparent high-temperature and high-pressure experiment cavity; the temperature and pressure control system is arranged in the transparent high-temperature and high-pressure experiment cavity and used for controlling the temperature and pressure of the transparent high-temperature and high-pressure experiment cavity; and the external visual equipment is positioned on the outer side of the transparent high-temperature and high-pressure experiment cavity, faces the sample, and is used for observing and recording the flowing behavior of gas and water in the sample. The invention further discloses a using method of the device. According to the invention, the real migration process of gas and water in the microfissure can be observed and monitored in real time.

The invention discloses a biological hydrogen production method for coupling a coal seam microbial community and beet pulp waste. The biological hydrogen production method comprises the following steps: step 1, collecting coal seam microorganisms; step 2, sample pretreatment; 3, preparing a culture solution; step 4, flora enrichment culture; and 5, constructing a biological hydrogen production system to obtain hydrogen-rich gas. Microorganisms adopted in the method are original microorganisms in underground in-situ coal seam or ground coal-bed gas well drainage and mining water, sugar industry waste beet pulp is adopted as a hydrogen production substrate, and aiming at the bottlenecks of high strain cost, limited substrate applicability and the like in an existing biological hydrogen production technology, the coal seam microorganisms and sugar industry waste residues are coupled, so that the yield of hydrogen is increased. A low-cost hydrogen production system is constructed, so that the economic cost in the microbial hydrogen production process is reduced, and the beet pulp has the advantages of being safe, easy to obtain, low in cost and high in gas production rate, has the advantages of being easy and convenient to operate, economical, efficient, environmentally friendly and the like, and has a good industrial application prospect.

The invention relates to the technical field of coal bed gas development and gas extraction, in particular to an electrodialysis-liquid CO2 time sequence synergistic anti-reflection method and system. Comprising an electrodialysis pretreatment stage, a CO2 synergetic permeability increasing stage and a process regulation and energy recovery stage, a mixed solution is injected into a coal seam in a pulse injection mode, and energy recovery is conducted through pipeline fluid pressure in the injection stopping period. According to the technical scheme, through multi-stage cooperation of electrodialysis pretreatment, CO2 phase change fracturing and pulse consolidation and regulation, accurate transformation of the coal seam low-permeability area is achieved. According to the scheme, electrodialysis is utilized to drive an acidic working solution to target and migrate to a difficult-to-permeate area, mineral substances are dissolved, and pores are expanded; then, high-energy expansion stress is generated through liquid CO2 phase change, and a through fracture network is formed; and finally, a pulse injection and energy recovery mechanism is adopted, fracture closing is restrained, system energy consumption is reduced, and therefore the coal seam breathability and the gas extraction efficiency are integrally improved.

The invention belongs to the technical field of coal seam mining, and discloses a preparation method of a nano alkenyl desorption promoting agent and application of the nano alkenyl desorption promoting agent in coal seam gas fracturing, and the preparation method comprises the following steps: mixing a mixed dispersion liquid with a grafting agent for reaction to obtain polymerized graphene, modifying an MOF material with octadecyl phosphonic acid to obtain a modified MOF material, and adding the modified MOF material into a reaction kettle for reaction to obtain the nano alkenyl desorption promoting agent. Carrying out high-energy ball milling compounding on the modified MOF material and polymerized graphene to obtain a nano filler, dissolving aminated silicone oil in a mixed solvent, and compounding the aminated silicone oil with the nano filler to obtain a nano alkenyl desorption promoting agent; the prepared nano alkenyl promoting desorption agent has hydrophilcity and hydrophobicity, desorption of coal bed gas is promoted through the nano filler, the nano alkenyl promoting desorption agent has excellent mechanical strength and methane desorption promoting capacity in coal bed gas fracturing application, the hydrophobicity of the pore wall surface of the coal bed is improved, methane desorption in the coal bed is facilitated, and the coal bed gas fracturing efficiency is improved. The water pressure resistance in the coal seam is high, the desorption action promoting time is long, and the effect is good.

The invention relates to the technical field of coal bed gas dewatering and drying equipment, and discloses coal bed gas dewatering and drying equipment and method, the coal bed gas dewatering and drying equipment comprises an equipment cylinder, the bottom of the equipment cylinder is fixedly connected with a plurality of supporting legs, and the side wall of the top of the equipment cylinder is fixedly connected with a gas inlet pipe. A positive and negative rotation motor at one end of a connecting plate drives an output rotating shaft to periodically rotate forwards and backwards, when the output rotating shaft rotates clockwise, the output rotating shaft drives condensation blades to rotate clockwise, the condensation blades rotate clockwise to drive cleaning rods to slide along the surfaces of the condensation blades, and at the moment, the cleaning rods rapidly scrape off condensed water drops on the condensation blades; thus, the contact area of the surfaces of the condensing blades and coal bed gas is increased, so that water vapor in the coal bed gas is condensed on the surfaces of the condensing blades, and the working efficiency of the device is improved; on the other hand, the phenomenon that water in the coal bed gas rapidly passing through the spiral cavity cannot make contact with the surfaces of the condensation blades in time, and consequently water removal of the coal bed gas is not thorough is avoided.

The invention discloses a method for rapidly and efficiently extracting coal mine gas in a broken and soft coal seam, and belongs to the technical field of coal seam gas development and coal mine gas prevention and control. According to the method, geological features of a coal mining planning area are determined, a ground U-shaped well and underground bottom-pumped rock drift layer-crossing drilling combined treatment system is deployed, and regional large-scale treatment is achieved in a well factory mode; the fracturing transformation range and the fracturing fluid distribution characteristics are detected by using a ground and underground combined micro-seismic monitoring and underground transient electromagnetic method, and the arrangement of layer-crossing drill holes is optimized; dividing the cross-layer drill holes into drainage holes and air exhaust holes, and formulating a collaborative extraction system in combination with different drainage and extraction stages; the method solves the problems that broken soft coal seam gas extraction is low in efficiency and long in period, and treatment blind areas exist, treatment time is remarkably shortened, cost is reduced, and safe and efficient production of a coal mine is guaranteed.

The utility model discloses a broken soft coal bed pneumatic airtight coring device which comprises a coring outer cylinder, a coring drill bit and an adapter. A pressing ball seat is arranged in the adapter, a locking mechanism core pipe is arranged in the lower end of the pressing ball seat in a sleeved mode, and the locking mechanism core pipe is further sleeved with a force storage mechanism body pipe capable of moving in the axial direction. The lower end of the power storage mechanism main body pipe is connected with the coring inner cylinder through a power storage mechanism main body pipe extension section capable of axially moving; a limiting step is arranged on the outer wall of the force storage mechanism body pipe, a locking sliding sleeve is further arranged outside the force storage mechanism body pipe in a sleeving mode, and a force storage spring is further arranged between the limiting step and the locking sliding sleeve in an abutting mode. A locking ball is embedded in the pipe wall of the lower end of the force storage mechanism body pipe and can axially limit the locking sliding sleeve. A sealing ball valve is arranged in the coring inner cylinder, and the pushing cylinder can be pushed by the locking sliding sleeve to move in the axial direction to close the sealing ball valve. The closed coring device solves the problems of hole spraying, hole collapse and the like when an existing closed coring device is used in a broken soft coal seam.

The invention provides a tight gas and deep coal bed gas collaborative exploitation simulation experiment device. The tight gas and deep coal bed gas collaborative exploitation simulation experiment device is composed of a shaft simulation device, a reservoir simulation device, a gas-liquid two-phase flow supply device and a control system. The casing pipe is provided with a plurality of transparent converging sections, and the oil pipe can be downwards inserted to different layers. And the gas-liquid two-phase flow supply device is provided with a plurality of groups of independent gas-liquid conveying manifolds which are respectively connected with each convergence section of the sleeve through the reservoir simulation device, so that the independent regulation and control of seepage parameters and production pressure difference of each layer are realized. The control system integrates pressure and flow acquisition and image recording functions, monitors and analyzes data in real time, is used for simulating an interlayer coupling relationship, a mutual interference mechanism and dynamic productivity response during multi-layer commingling production, and provides an experimental basis for collaborative production layer strategy optimization.

The invention discloses a stress demarcation-based deep coalbed methane compressible dessert evaluation method for a complex structure area. The method comprises the following steps: calculating the maximum horizontal stress, the minimum horizontal stress and the vertical stress of a single well; the single well stress type is judged based on the three-stress magnitude relation, and complex area partitioning is conducted by combining the structural boundary; geological conditions of compressibility of deep coal bed gas in different partitions are defined, and first-level and second-level index systems for compressibility evaluation of different partitions are established; a quantitative characterization method for secondary evaluation index parameters is provided; based on the type of the stress field, determining the weight of the index parameter by adopting a subjective weighting method; establishing a membership function for different evaluation index parameters; calculating the evaluation comprehensive values of the compressible desserts of the coal bed gas single well in different subareas, and carrying out the classification and classification of compressible dessert areas. According to the method, difference setting and unified comparison of compressible dessert evaluation parameter systems of coalbed methane at different depths in the same block are realized, and the existing dessert evaluation index is optimized.

The invention relates to a coal-bed gas horizontal well bottom hole flowing pressure control method and device and a storage medium. The method comprises the steps that data of a coal-bed gas well in a first time period when production starts are obtained; drawing a first curve according to the data; calculating quasi-steady-state water production parameters according to the data and the first curve; gradually reducing the flowing bottomhole pressure to the critical desorption pressure of the reservoir; recording the second-day water yield of each day; reducing the flowing bottomhole pressure day by day; the pressure value in the sleeve is adjusted; and calculating the daily gas-water relative permeability ratio. According to the method, the defect of a template scheme with the static parameters of the reservoir as the system basis in an existing method is overcome, the heterogeneity of the coal-bed gas well is fully considered, the flexible indexed parameter determination method is adopted according to the actual gas-water flow characteristics of the single well, the optimal underground seepage state of the single well can be achieved, and the underground seepage rate of the single well is increased. And stratum supply and ground production achieve supply and production balance, single well long-term stable production is achieved, and reference is provided for coal-bed gas well drainage and production control refinement.

The invention belongs to the technical field of drilling fluid processing, and particularly relates to a special silicate water-based drilling fluid for a coal-bed gas well as well as a processing method and a processing device of the special silicate water-based drilling fluid. The top end of the stirring tank is communicated with a first feeding hole and a second feeding hole, and the bottom end of the stirring tank is communicated with a discharging pipe; a rotating shaft is rotationally connected to the top surface of the inner wall of the stirring tank, and a sliding groove is formed in the bottom surface of the rotating shaft; a rotating shaft is driven by a first motor to rotate, and the rotating shaft drives a connecting shaft to rotate, so that fresh water and additives in a stirring tank are stirred and mixed by stirring blades, and a first screw rod can be driven by the first motor to positively and negatively rotate in a reciprocating manner in the mixing process; the first screw rod drives the connecting shaft to move up and down in the sliding groove, so that the stirring blades move up and down, the stirring blades stir and mix the water and the additive while moving, and the mixing efficiency and uniformity of the additive and the water are improved.

The invention relates to the technical field of coal bed gas development, and particularly discloses a numerical simulation method for multi-field coupling and microwave enhanced drainage and mining of a deep coal bed, which realizes accurate simulation of the whole process of drainage and mining of deep coal bed gas through six key steps: firstly, obtaining a coal bed parameter system; establishing a temperature coupling adsorption and desorption model, and quantifying the influence of the high ground temperature environment on the gas occurrence by correcting a Langmuir equation; constructing a dual-medium heat-gas-liquid-solid full-coupling control equation set which covers coal deformation, gas-water two-phase seepage, heat transfer and electromagnetic field equations; a microwave heat effect model is defined, and electromagnetic energy-heat energy conversion is calculated through a dielectric constant mixing model; deducing a porosity / permeability dynamic evolution equation, and coupling effective stress, matrix shrinkage and a thermal expansion effect; and finally, a COMSOL Multiphysics platform is adopted to realize multi-field coupling solution, and a productivity index is calculated through well circumference integration. According to the method, the inherent limitation of a static parameter model is overcome, and the precision and efficiency of numerical simulation are remarkably improved.

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

The invention provides a deep coalbed methane reservoir pore parameter prediction method based on geologic feature constraint, and relates to the technical field of coalbed methane reservoir development, and the method comprises the steps: building a deep coalbed methane reservoir rock physical model of which a crack is filled with calcite by using a DEM model based on the calcite content of the filled crack and calcite elastic parameters; elastic parameters of the deep coal bed gas reservoir rock physical model are obtained; based on the elastic parameters of the rock physical model of the deep coalbed methane reservoir, simulating and generating a seismic record of the target coalbed methane reservoir by using a response relationship between seismic wave propagation and the elastic parameters of the rock physical model of the deep coalbed methane reservoir; and based on the simulated seismic record, the actual seismic record and the prior data of the pore parameters, performing Bayesian iteration inversion by using a pre-constructed inversion objective function to obtain a prediction result of the pore parameters corresponding to the target coalbed methane reservoir. The prediction accuracy of the pore parameters is improved.

The invention discloses a coal bed gas biological yield increase effect dynamic monitoring and evaluation method which comprises the following steps: arranging a multi-parameter sensor in a target coal bed gas well site, and collecting background data before bacterium injection; injecting a microbial bacterial solution and a nutrient solution into the coal seam according to the experimental design, and recording parameter information in the injection process; periodically collecting a gas production sample, and analyzing gas components; analyzing microbial community structure and abundance change in the water sample; combining the gas generation rate, the isotope characteristics and the microflora analysis result to identify a gas production path and calibrate a key functional flora; and constructing a mathematical model containing microbial activity, coal quality conversion and gas production efficiency, forming an evaluation index system, and outputting field process optimization suggestions based on the model. According to the method, a scientific basis is provided for dynamic optimization of the yield increasing process, and compared with a traditional laboratory method, the method can achieve systematic analysis of the in-situ microorganism process and quantitative evaluation of the gas production effect, and has good field adaptability and popularization value.

A drainage and gas production device for a horizontal well for coalbed methane of a coal mine area, the device comprising a surface horizontal well and a downhole borehole section (6), wherein a horizontal section (4) of the surface horizontal well is in communication with the downhole borehole section (6), a communication point (7) of the horizontal section (4) of the surface horizontal well and the downhole borehole section (6) is located at an end A or a middle or an end B of the horizontal section (4) of the surface horizontal well; and the other end of the downhole borehole section (6) is connected to a gas-water-slag separation device (15) located in a downhole drill site (5).

The invention relates to the technical field of automatic control of drilling parameters, in particular to a coal bed gas underground drilling construction parameter optimization method and system.The method comprises the following steps that sound wave response signals are obtained, propagation characteristics are calculated, bit pressure data are aligned, abnormal fluctuation is recognized, pumping pressure information is extracted, and the change trend is analyzed; and comparing the consistency of the regulation and control points and organizing regulation and control actions to finally form a coal-bed gas well drilling parameter optimization control flow. According to the method, accurate calibration of an abnormal state is achieved by constructing a sound wave propagation delay sequence and synchronizing bit pressure response, key regulation and control fragments are recognized in combination with a pumping pressure change trend, a time sequence coupling relation between bit pressure and pumping pressure is established, regulation and control action combinations meeting response consistency are extracted, and sequential organization is conducted; a control instruction set with continuity and pertinence is formed, collaborative recognition and linkage regulation and control of multi-parameter change trends are achieved, and stability and response coordination in the construction process are improved.

The embodiments of the present specification provide a coal bed gas well history matching method, an apparatus and a device, which are applied to the field of geological exploration and development. The method comprises: constructing a plurality of simulation schemes on the basis of at least one impact factor corresponding to a target coal bed gas well, wherein in different simulation schemes, the impact factors are set as corresponding simulation parameter values; separately calculating cumulative production parameters of the different simulation schemes, the cumulative production parameters comprising a cumulative gas production and a cumulative water production; determining a scheme deviation type on the basis of a comparison result between the cumulative production parameters and actual measured parameters; and performing history matching on the target coal bed gas well on the basis of a parameter adjustment strategy corresponding to the scheme deviation type.