125 results about "Coalbed methane" patented technology

The application discloses a deep coal seam no-roadway gas extraction and deep geothermal resource exploitation integrated method, which comprises the following steps: S1, constructing a U-shaped well; S2, arranging a double-layer casing assembly in the U-shaped well; S3, arranging a plurality of annular packers on the double-layer casing assembly in the horizontal well section, and then connecting the double-layer casing assemblies in sections into an integrated whole; S4, performing hydraulic fracturing on the horizontal well section through the double-layer casing assembly; and S5, extracting gas through the double-layer casing assembly, and injecting cold water through the double-layer casing assembly, so that the high-temperature gas exchanges heat with the cold water, and the cold water is heated to become hot water. The application realizes deep coal seam no-roadway gas extraction and deep geothermal resource exploitation, solves the problem that deep coal seam gas is difficult to extract when shallow coal seams are exploited, reasonably exploits coal seam gas resources, reduces the gas extraction engineering quantity, and utilizes geothermal resources, thereby bringing more benefits to coal mines.

The application provides a kind of microbial population evolution monitoring method and device based on magnetic field intensity regulation, related to microbial monitoring field, through multi-source sensor real-time collection microbial community, methane production, magnetic field parameter and environmental working condition data, construct supervision data set, establish dynamics model containing magnetic field influence function, and adopt supervision learning to carry out parameter online identification and rolling prediction, finally through optimization algorithm real-time adjustment magnetic field parameter, realize the closed-loop optimization control of microbial permeability process.The application adopts the above-mentioned microbial population evolution monitoring method and device based on magnetic field intensity regulation, has the advantages of strong real-time, high interpretability, good engineering implementability, etc., is suitable for coal seam microbial permeability, coalbed gas production optimization and mine ecological process evaluation and other application scenarios.

The utility model discloses a water -cooled coal bed gas hydraulic fracturing system, this system passes through integrated high -efficient water -cooling unit, effectively solved traditional coal bed gas hydraulic fracturing system in air -cooled heat dissipation efficiency low, energy consumption is high, loud and frequent maintenance technical problem. System adopts plate heat exchanger and circulating cooling water system, has realized the accurate control of hydraulic oil temperature, has improved system energy efficiency and operating stability significantly, especially suitable for coal mine underground limited space and high dust environment. The system has heat dissipation efficiency high, compact structure, energy consumption is low and maintenance cycle long etc. advantage, provides strong support for the efficient exploitation of coal bed gas.

The present application belongs to the technical field of natural gas preparation, and relates to a system and method for preparing natural gas by super-high-temperature steam accelerated coal metamorphic evolution hydrocarbon generation. The system comprises: a feeding device for pneumatically feeding coal powder; an accelerated coal metamorphic evolution hydrocarbon generation reactor, which is provided with a material steam inlet, a coal powder inlet and a product outlet, the material steam inlet is connected with a material steam supply device for inputting material steam, and the coal powder inlet is connected with the feeding device; and a heating component for heating the accelerated coal metamorphic evolution hydrocarbon generation reactor. The natural gas preparation system and method of the present application is a derivative technology based on the study of coalbed methane genesis mechanism, has the characteristics of not adding oxygen to participate in coal gasification and not adding hydrogen to participate in carbon reaction, overturns the traditional coal-to-natural gas technology concept, has high energy efficiency, low energy consumption, high methane output rate and remarkable energy-saving effect, and is an advanced energy conversion technology for realizing efficient and clean cascade utilization of coal.

The application discloses a kind of complex coal measures strata double horizontal well cyclic injection CO2 vertical displacement coalbed gas mining method, belong to coalbed gas development technical field.Deep coal measures strata is selected as purpose layer, and two single branch horizontal wells are drilled in the same well group.One horizontal section is located at the top of purpose layer for coalbed gas extraction and fracturing;Another horizontal section is located at the bottom of purpose layer for injecting liquid CO2.Before extraction, by continuously injecting liquid CO2 into the bottom of purpose layer, the displacement and displacement effect of CO2 on CH4 are used to improve the recovery of deep coalbed gas;During extraction, part of CO2 is extracted with CH4, and the extracted CO2 is liquefied and recycled into the bottom of purpose layer through CO2 separation device;At the end of extraction, most of CH4 has been extracted, and the horizontal well is sealed to prevent CO2 from leaking, achieving the purpose of CO2 storage.The method is simple and easy to implement, and can be used for complex structure of purpose layer.

This invention relates to the field of collaborative well testing technology for coal reservoirs, specifically disclosing a constant flow rate-limited pressure collaborative control method and system for coal reservoir well testing. The method includes: collecting cluster-single-well dual-dimensional parameters; constructing a regional reservoir pressure field coupling model based on the dual-dimensional parameters, wherein the regional reservoir pressure field coupling model embeds fluid-structure interaction equations and a pulverized coal critical velocity model; configuring a cluster-single-well dual-level priority dynamic allocation rule based on the dual-dimensional parameters; and configuring a cluster-level multi-objective optimization algorithm with single-well flow deviation, single-well pressure, regional pressure field uniformity, and cluster pulverized coal blockage risk as constraint indicators. This invention successfully resolves the contradiction between rapid pressure relief and prevention of pulverized coal explosions, minimizing reservoir damage and wellbore blockage risks while ensuring well control safety, and significantly improving the success rate and data quality of coalbed methane well cluster testing operations.

The application discloses a kind of deep coal seam CO2 foam fracturing parameter optimization methods based on phase state regulation, first, build the wellbore flow heat absorption model fusing fluid residence time, mixed heat capacity and formation heat transfer characteristics, accurately calculate well fluid temperature and pressure, according to the calculation result, using Span-Wagner state equation, in combination with carbon dioxide phase diagram determines well fluid real phase state, and carry out indoor true triaxial equivalent simulation experiment and sand-carrying performance experiment with this as boundary condition, according to the result fed back by experiment, by adjusting ground injection displacement and foam quality and other parameters, actively control well fluid phase state, to realize the fine regulation and control of reservoir reconstruction effect.The application can effectively eliminate phase state prediction deviation, realize the active regulation and control of well fluid phase state, significantly improve the fracturing reconstruction volume of deep coalbed gas and single well production.

This invention discloses a synergistic hydraulic permeability enhancement and semi-permeable membrane-enhanced gas extraction system and method, belonging to the field of low-permeability coal seam gas extraction technology. The system comprises a dual-casing structure, hydraulic permeability enhancement drive, semi-permeable membrane negative pressure gradient extraction, and recovery circulation systems. The dual-casing structure mainly consists of a main water injection pipe and multiple outer casings, a main extraction pipe and multiple inner casings. The outer casings are equipped with jet nozzles, and the inner casings have gas extraction holes covered by a polytetrafluoroethylene (PTFE) semi-permeable membrane. The dual-casing structure system combines permeability enhancement and extraction functions. Precise hydraulic permeability enhancement is achieved through the outer casings, while the inner casings utilize the selective permeability characteristics of the semi-permeable membrane to enhance gas extraction, thus solving the problems of short permeability enhancement efficiency, low extraction efficiency, and poor sealing performance in traditional technologies. This invention is suitable for efficient gas extraction and coal seam permeability enhancement in high-stress, low-permeability coal seams, ensuring safe coal mine production and improving coalbed methane resource utilization.

The utility model discloses a coal bed gas sampling equipment for coal bed gas exploration, including the sampling equipment body that one end is equipped with the coal bed gas entrance, rotates and is installed with the rotating protective cover on the sampling equipment body, and the rotating protective cover can do the reciprocating rotation action of opening and closing the sampling equipment body to keep away or contain the sampling equipment body, and the sealing slide cover that can do reciprocating pulling action is slidably connected on the rotating protective cover, and the sealing slide cover is arranged coaxially with the coal bed gas entrance, and the coal bed gas entrance is located on the movement path of the sealing slide cover, so that the sealing slide cover contains the coal bed gas entrance after the sampling equipment body is contained to the rotating protective cover inside, the utility model discloses a rotating protective cover and sealing slide cover cooperate, and the sampling equipment body is contained in the rotating protective cover inside in the non - sampling stage, realizes the physical isolation protection of equipment body, and simultaneously, the sealing slide cover carries out axial dynamic sealing to the coal bed gas entrance, and the path of dust invading the coal bed gas entrance is effectively blocked.

The application discloses a coalbed methane sweet spot identification method based on geological constraint collaborative evaluation, and comprises the following steps: S1, selecting multiple different type wells as training samples, and constructing a training sample original data table according to evaluation indexes of the training samples; S2, performing index homodirection and standardization processing on each evaluation index in the training sample original data table to obtain a standardized training sample table; S3, performing key variable screening on the standardized training sample table under the geological constraint collaborative evaluation to obtain an optimal variable combination; S4, establishing a discriminant function of different type wells according to the optimal variable combination, and combining with a corresponding standardized value of a to-be-judged well sample to calculate discriminant scores of the to-be-judged well sample on different type wells; and S5, calculating a competitive discriminant index according to the discriminant scores, and a type well corresponding to a maximum value of the competitive discriminant index is a type of the to-be-judged well sample. The application can more accurately identify a coalbed methane sweet spot, and provides technical support for coalbed methane exploration and development.

The application discloses a reservoir reconstruction method and system cooperating with low-frequency vibration and high-pressure air blasting, relates to the technical field of coalbed methane penetration and low-permeability reservoir reconstruction technology, and specifically relates to a reservoir reconstruction system cooperating with low-frequency vibration and high-pressure air blasting. The reservoir reconstruction system cooperating with low-frequency vibration and high-pressure air blasting comprises a ground control unit and a downhole operation unit connected with the ground control unit through a wellhead device, and the downhole operation unit is connected with the ground control unit through a power cable, a signal cable and a high-pressure transportation pipeline. The yield and penetration effect is stable and remarkable: the reservoir permeability can be increased by more than 2 times after the cooperative reconstruction, and the production capacity is greatly and stably improved. The whole process is green and environmentally-friendly: compressed air is used as the only working medium, and water, chemical additives and proppants are not needed, so that the water resource consumption and the stratum damage problem are eliminated.

The utility model discloses a kind of gob coalbed methane rapid plugging devices, it is related to gas layer plugging technical field, including directional drilling rig and mixing box, mixing box is used to store filling material, support frame carries out stirring to filling material in mixing box, improve the injection efficiency of filling material, improve the plugging speed to gas layer, and support frame quantitative injection retarder or accelerator in mixing box changes the coagulation speed of filling material, improve the plugging effect to gas layer, while the filling material in mixing box is stirred, the inside wall of mixing box is scraped, avoid that filling material sticks in the inside wall of mixing box, the utility model improves the speed and efficiency of plugging to gas layer.

This invention discloses a multi-dimensional geological steering method for horizontal wells in medium-deep coalbed methane formations, comprising the following steps: S1 establishing a three-dimensional seismic-geological model of the marker layer and the target coal seam; S2 determining the well inclination angle of each marker layer encountered; S3 predicting the depth, thickness, dip angle, and spatial distribution characteristics of the target coal seam; S4 using a layer-by-layer approximation method to ensure accurate target entry of the horizontal well; S5 comprehensively analyzing horizontal section data to ensure a high drilling success rate; S6 adjusting and optimizing the model. This invention is applicable to the field of coalbed methane development technology. It adopts a layer-by-layer approximation control technique for the well inclination angle of the marker layer to quantitatively determine the optimal well inclination angle for each marker layer. During actual drilling, geological steering personnel only need to determine whether the well inclination angle meets the design when each marker layer is encountered, simplifying the analysis content and steps, saving analysis time when there is a large deviation from the designed marker layer depth, and improving drilling efficiency.

The utility model belongs to the technical field of coal-bed gas development, and discloses a coal-bed gas shaft pulverized coal migration and settlement test system which comprises a simulation shaft which comprises an inner-layer pipe column and an outer-layer pipe column, an annular space part is arranged between the inner-layer pipe column and the outer-layer pipe column, and the annular space part is communicated with the inner-layer pipe column. The simulation shaft can rotate and incline around the center of the simulation shaft within a preset angle; the liquid injection system is connected with the first end of the annulus part and used for inputting pulverized coal slurry into the annulus part; the gas injection system is connected with the second end of the annulus part and used for inputting simulation gas into the annulus part, and the simulation gas and the pulverized coal slurry can flow to the inner-layer pipe column from the annulus part and return to the liquid injection system; the tuning fork resonance sensor is arranged in the simulation shaft in a penetrating mode, and a fork body is located in the inner-layer pipe column and used for detecting the vibration frequency when the pulverized coal slurry and the simulation gas flow in the inner-layer pipe column. The device can simulate the migration and settlement of pulverized coal in wellbores of different well types.

This invention discloses a method for determining the production capacity of a coalbed methane (CBM) well without shutting it in. The method includes: acquiring basic data of the CBM well; determining a relationship table between pressure and CBM deviation factor, and a relationship table between pressure and apparent pressure, based on CBM PVT experimental data; recording the daily gas production, bottom hole pressure, and cumulative gas production of the CBM well at each stable flowing pressure test moment during three or more different production stages; determining the formation pressure corresponding to each stable flowing pressure test moment using a mass balance equation; determining the coefficients of the CBM well's production capacity equation based on the formation pressure, bottom hole pressure, and production at each stable flowing pressure test moment, thereby obtaining the CBM well's production capacity equation; and substituting the formation pressure and bottom hole pressure values ​​into the production capacity equation and solving for the corresponding CBM well production capacity. This invention effectively overcomes the shortcomings of traditional well testing methods that require shutting in the well to test formation pressure, and avoids the problem that the applicable conditions of existing non-shutdown methods for determining gas well production capacity equations are difficult to meet.

The utility model discloses a kind of drainage oil filter tank for coalbed methane surface extraction well, it is related to oil filter tank technical field, including settling chamber, the top of the settling chamber is equipped with liquid inlet pipe, and the lower part of side wall is equipped with drain valve, the top of the settling chamber is equipped with openable and closable opening and closing assembly, detachable filter assembly is arranged in the settling chamber, the bottom of the settling chamber is equipped with inclined plate for accelerating oil-water separation, the bottom of the settling chamber is equipped with oil collection tank. The utility model is by being equipped with inclined plate and filter assembly, oil drop only needs the vertical spacing between two inclined plates to reach the lower surface of inclined plate, then slide up along inclined plate and gather, and oil drop in water is actively adsorbed by oil absorption bar, while not absorbing moisture, by woven mesh structure, can maximize the contact opportunity with oil drop, and the internal complex pore is also conducive to capturing and locking oil drop.

This invention belongs to the field of numerical simulation technology for oil and gas reservoir development, specifically relating to a numerical simulation method for enhanced oil recovery (EOR) through carbon dioxide injection into coalbed methane. The method includes: establishing a three-dimensional geological model, a three-dimensional geomechanical model, and a fracture network model using Petrel; establishing a numerical simulation model of coalbed methane components including fractures using the Intersect simulator, and performing historical data fitting based on historical production data; importing the geological attribute field, pressure field, and saturation field at the end of the historical data fitting into the CMG-GEM simulator to conduct thermal simulation of carbon dioxide injection into coalbed methane; importing the simulated pressure and temperature fields back into Petrel, and then using the Intersect simulator to complete the dynamic prediction of thermal drive production. This invention can consider the influence of temperature on CH4 and CO2 adsorption / desorption, improving model accuracy and significantly enhancing the accuracy of production prediction.

The coal bed gas well composite fracturing and permeability improvement construction method comprises a carbon dioxide injection pipe, a nitrogen injection pipe, two blocking and sealing devices, a fracturing fluid preparation device, a power generation assembly and a PLC controller, the nitrogen injection pipe is coaxially sleeved outside the carbon dioxide injection pipe, the nitrogen injection pipe and the carbon dioxide injection pipe are coaxially lowered into the coal bed gas well, the two blocking and sealing devices are coaxially sleeved and fixed on the nitrogen injection pipe at intervals, the fracturing fluid preparation device is coaxially sleeved and fixed on the nitrogen injection pipe and located between the two blocking and sealing devices, the bottom of the fracturing fluid preparation device is provided with a liquid booster pump, the top of the fracturing fluid preparation device is provided with a gas booster pump, and the liquid inlet of the liquid booster pump is connected with the fracturing fluid outlet of the fracturing fluid preparation device. The present application has the advantages of scientific design, reasonable structure, good composite fracturing and permeability improvement effect, low requirement on equipment performance and energy saving and consumption reduction.

This invention belongs to the field of digital core spiral CT scanning analysis technology, and relates to a method, device, and storage medium for characterizing coal seam intercalation. The method includes the following steps: acquiring a CT grayscale image of the coal seam; classifying the inorganic minerals in the CT grayscale image; establishing an inorganic mineral classification and identification chart for the coal seam; acquiring the inorganic mineral content of each CT scan cross-section corresponding to the coal seam; calculating the brittleness parameter of each CT scan cross-section; and generating characterization results based on the CT grayscale image, the inorganic mineral content, and the brittleness parameter. The coal seam intercalation characterization method, device, and storage medium provided in this application utilize a coal reservoir mineral content and brittleness parameter evaluation method based on full-diameter CT, achieving for the first time a quantitative evaluation of the inorganic mineral content and brittleness parameter of the entire well section of a coal reservoir at the millimeter level, providing valuable data support for the next step of coalbed methane development engineering fracturing.

This utility model relates to a loading rotary head, specifically a loading and pressurizing rotary head for shallow coalbed methane wells. It includes a hydraulic pressure head and a fixed base. A support plate is rotatably mounted on the top of the fixed base, and the pressure head of the hydraulic pressure head abuts against the top of the support plate. A tubing string connector is located at the bottom of the fixed base, and the cross-section of the tubing string connector is an inverted trapezoid. An external thread adapted to the internal thread of the tubing string is provided on the outer wall of the tubing string connector. This utility model can simultaneously meet the pressure-driven rotation requirements of well workover operations in shallow coalbed methane wells, such as thread making and cement plug drilling, reducing manual labor intensity while improving work efficiency.

The application provides a coal rock permeability improvement effect test and system by microwave heating, and relates to the technical field of coal rock testing. A group of microwave emission parameters are selected by the central control, and N microwave emission modules in M microwave emission modules are controlled to emit microwaves. The first inlet flow collected by the inlet flow meter is recorded, and the first outlet flow collected by the outlet flow meter is recorded. The central control determines the permeability improvement degree of the industrial microwave oven under the set microwave emission parameters according to the first inlet flow, the first outlet flow and the preset initial fissure degree of the coal rock. The next group of microwave emission parameters are selected from the preset emission parameter set. The step of controlling N microwave emission modules in M microwave emission modules to emit microwaves according to the selected microwave emission parameters is returned to be executed until all the microwave emission parameters in the preset emission parameter set are selected. The microwave emission parameter with the highest permeability improvement degree is selected from the permeability improvement degrees under the groups of microwave emission parameters, and is configured to the industrial microwave oven, so that the microwave emission parameter with the highest permeability improvement degree can be obtained, and the extraction efficiency of the coalbed methane is improved.

The utility model relates to the technical field of coal bed gas, and disclose a monitoring device for fracturing, including first support plate, still including the steady pole of setting at first support plate bottom, the utility model discloses through setting mobile subassembly convenient control cleaning brush's removal, and the cleaning effect of enhancing to threaded rod, through mobile groove, moving block, support frame and positioning rack etc.

The present invention relates to a coalbed methane decarbonization and hydrogen production process and an automatic control system. A decarbonization and hydrogen production unit comprises: a reactor (1) comprising a reaction zone (9), wherein a reaction tank (2) is provided in the reaction zone (9), the reaction tank (2) is provided with a plurality of natural gas inlets evenly distributed on the reaction tank (2), the natural gas inlets are in communication with an external coalbed methane source (23), a first valve (26) for controlling the opening and closing of each natural gas inlet is provided at the natural gas inlet, and the first valves (26) are arranged independently of one another; a regulating assembly configured to regulate reaction conditions inside the reaction tank (2); and a controller in signal connection with the first valves (26) and the regulating assembly.

The present application relates to coal chemical technology field, disclose a kind of method for preparing synthesis gas by multi-stage self-heating catalytic deoxidation conversion of oxygen-containing coal seam gas, comprising the following steps: step (1), after preheating oxygen-containing coal seam gas is divided into multiple streams;Step (2), first oxygen-containing coal seam gas is mixed with steam first, into the first self-heating catalytic deoxidation conversion reactor and carries out self-heating catalytic deoxidation and methane steam reforming reaction;Step (3), the outlet gas of first self-heating catalytic deoxidation conversion reactor is mixed with second oxygen-containing coal seam gas after entering second self-heating catalytic deoxidation conversion reactor and carries out self-heating catalytic deoxidation and methane steam reforming reaction, in turn;Step (4), the outlet gas of last self-heating catalytic deoxidation conversion reactor is re-entered into pure oxygen conversion reactor or air conversion reactor and carries out conversion reaction.The method of the present application is controllable in reaction temperature, only needs to supplement steam once, steam addition amount is less, heat utilization efficiency is high, energy and investment are saved.

The application provides a coal bed gas well monitoring device, which comprises a cable, a sensor assembly, a ground data conversion transmission device and a hose. The hose is a hollow structure with an open end. The open end of the hose is sealingly connected with an air pressure adjusting device capable of adjusting the air pressure in the hose. The hose is connected with an air pressure expansion structure capable of simultaneously pressing the oil pipe and the casing of the coal bed gas well. After the air pressure in the hose is increased, the air pressure expansion structure is elongated. After the air pressure in the hose is reduced, the air pressure expansion structure is shortened. The sensor assembly is fixed to the lower part of the hose. The cable is located in the interior of the hose and the interior of the air pressure adjusting device. One end of the cable extends out of the hose and is connected with the sensor assembly. The other end of the cable extends out of the air pressure adjusting device and is connected with the ground data conversion transmission device. When the sensor assembly is maintained, the oil pipe column does not need to be lifted, and the hose only needs to be pulled out. The operation is convenient, time and labor are saved, and the maintenance cost is reduced.

This application discloses a method for evaluating the original geological reserves of undersaturated coalbed methane, comprising: determining the reservoir physical properties, fluid physical properties, and fracturing fluid injection and flowback data of the undersaturated coalbed methane reservoir; obtaining the average formation pressure, cumulative gas production, cumulative water production, and average deviation coefficient of the coal reservoir during the production process of the undersaturated coalbed methane well; calculating the corrected apparent pressure of the undersaturated coalbed methane reservoir based on the reservoir physical properties, fluid physical properties, average formation pressure, and average deviation coefficient; calculating the equivalent cumulative gas production of the coalbed methane well based on the reservoir physical properties, fluid physical properties, total fracturing fluid injection, cumulative flowback of fracturing fluid during the flowback stage, cumulative gas production, cumulative water production, average formation pressure, and average deviation coefficient; and calculating the original geological reserves of undersaturated coalbed methane based on the corrected apparent pressure and the equivalent cumulative gas production of the coalbed methane well. The method is simple and clear, and easy to promote and apply.