85 results about "Injection point" patented technology

A proportioner comprising one or more proportioner inlets configured to receive a common concentrated proppant fluid comprising a proppant; two or more flow lines fluidly connected to the one or more proportioner inlets; two or more proportioner outlets, each of the two or more proportioner outlets associated with one of the two or more flow lines; one or more fluid inlets, each of the one or more fluid inlets configured to introduce a proppant-free fluid to the proportioner; and a metering system associated with at least one of the two or more flow lines, each at least one metering system upstream of the proportioner outlet of the flow line with which it is associated and each metering system fluidly connected with at least one of the one or more fluid inlets and configured for proportioning one of the proppant-free fluids into the associated flow line at an injection point.

The invention provides a site pollution abatement agent injection method and system, and belongs to the technical field of pollution remediation. The method comprises the following steps: determining an in-situ injection agent; constructing a three-dimensional site model; based on the optimal injection parameters of different soil texture types, injection points are distributed in the three-dimensional site model, and an injection point vector point location map is obtained; according to the three-dimensional pollution space distribution model, the three-dimensional stratum model, the optimal injection parameters of different soil texture types, the injection point vector point location map and the medicament injection associated equation, generating a medicament injection scheme based on three-dimensional site model driving; the medicament injection scheme is guided into an injection equipment control system, and medicament injection is executed; and when the site pollutant remediation result does not reach the preset standard, updating the three-dimensional site model based on the current site, and repeating the steps until the site pollutant remediation result reaches the preset standard. The consistent distribution of the medicament injection space and the pollution space is ensured, the intelligent and accurate control of medicament injection is improved, and the medicament consumption is reduced.

The invention discloses a device for simulating flowing of a corrosion inhibitor in a pipeline and a corrosion inhibitor effect evaluation method, the device comprises a corrosion inhibitor filling cabin, a corrosion inhibitor experiment cabin and acquisition equipment, and is used for experimenting and acquiring data required by the evaluation method, and the evaluation method comprises the following steps: acquiring evaluation index data of a corrosion inhibitor to be tested; inputting the evaluation index data into a preset evaluation model, and obtaining a comprehensive evaluation score output by the preset evaluation model; and determining an evaluation grade corresponding to the comprehensive evaluation score in the target preset score interval, and outputting the comprehensive evaluation score and the evaluation grade of the corrosion inhibitor to be tested. The device adopts a modularly-designed pipe diameter-variable simulation pipeline assembly, and can realize multi-condition simulation such as adjustable injection points and various corrosion inhibitor injection modes. According to the effect evaluation method, a mode of combining an analytic hierarchy process and a fuzzy comprehensive evaluation method is adopted, multi-dimensional and complex data is converted into visual and practical evaluation, and quantitative evaluation of the corrosion inhibition effect is achieved.

The utility model discloses a distributed wind generating set lubricating system which is characterized in that a grease storage unit is close to a corresponding grease injection point, hydraulic oil provided by a pump module is used as driving force, and lubricating grease in the grease storage unit is injected into the grease injection point; the condition that lubricating grease flows in a long pipeline in a traditional centralized lubrication system is changed, the risk of blockage does not exist any more, in addition, a distributed structure is adopted, the grease storage units correspond to the grease injection points one to one, it is guaranteed that grease injection of other grease injection points cannot be affected when any grease injection point is blocked, the defects of traditional centralized lubrication are overcome, and the service life of the system is prolonged. And as long as the main pipeline or the main distributor is blocked, the system cannot operate. And in addition, the lubricating grease is injected into all grease injection points in the mode that the lubricating grease is pushed by hydraulic oil, and the problem that the system cannot operate due to the fact that air exists in the lubricating grease is solved. And the pressure sensors are used for monitoring the pressure of the corresponding pumping units, so that which grease injection point is blocked can be quickly checked.

The invention discloses a method for rapidly detecting and identifying city pipe network mixed and misconnected based on VOCs tracer gas. The method comprises the following steps that S1, the distribution relation of rainwater pipes and sewage pipes in a target area is analyzed; s2, performing gas production analysis on the VOCs in the rainwater pipe and the sewage pipe to obtain spectrum data of the VOCs in the rainwater pipe and the sewage pipe, and selecting gas with unobvious background characteristics as tracer gas according to detection results of the spectrum data of the VOCs in the rainwater pipe and the sewage pipe; s3, selecting a tracer gas blowing point position, and blowing tracer gas into the pipeline; s4, according to the tracer gas blowing-in point position, VOCs in the inspection wells around the blowing-in point position and upstream and downstream are subjected to gas production, and TOF-MS is adopted for tracer gas detection; and S5, the detection condition of the tracer gas in each inspection well is analyzed, and the mixed and misconnected point positions of the rainwater pipe and the sewage pipe are rapidly determined. The method can quickly and accurately check the problem of mixed rain and sewage misconnection, and has the advantages of high economical efficiency, wide application range, high detection efficiency and low detection and identification cost.

The invention discloses a combustion chamber control method for coal seam in-situ gasification mining and application of the combustion chamber control method. The method comprises the steps that whether the injection-production point retreating time is met or not is judged according to the flow of a production well and / or the high calorific value of produced gas; if yes, an injection-production point retreating mode is selected according to the type of a production well pipeline, the retreating distance, a retreating injection point and / or a production point are / is determined according to the thickness of a coal seam and the size of a current combustion cavity, and the injection well and the production well are double horizontal wells for conducting in-situ gasification production on the coal seam. According to the method, stable combustion of the deep coal seam combustion cavity can be achieved, stability of the output gas flow and the heat value is guaranteed, and long-time benefit mining is guaranteed.

The invention discloses a method for determining an optimal gas injection point of gas lift reverse circulation, which comprises the following steps: acquiring underground parameters, and setting a time node t; reasonable grid division is carried out in the drilling tool, divided grid areas (i, j) are obtained, longitudinal i = 1, 2, 3... m, and radial j = 1, 2, 3... n; calculating a Reynolds number and liquid phase velocity distribution of the grid region (i, j); calculating the initial state of the solid phase in the grid region; calculating the parameters by using a unit parameter calculation module; judging whether the time node t is calculated to reach the longitudinal segment m or not; judging whether the solid-phase velocity is smaller than the settling velocity; recording a data output result; according to the method, the limiting position of the gas injection point capable of ensuring that the rock debris is smoothly discharged out of the wellhead is found, and important reference is provided for determining the gas injection point and the gas injection amount.

The invention relates to a goaf foam fixed-point injection air leakage stoppage device and method, the air leakage stoppage device comprises two foam generating devices and a foam injection pipe, the two foam generating devices are arranged in an air inlet roadway and an air return roadway respectively and connected with forepoling hydraulic supports in the air inlet roadway and the air return roadway, and the foam injection pipe is connected with the forepoling hydraulic supports in the air inlet roadway and the air return roadway. The forepoling hydraulic support can drive the foam generating device to move forwards; coal wall pipe grooves extending in the front-back direction are formed in the protective coal pillars on the left side and the right side of the goaf, foam injection pipes are laid in the coal wall pipe grooves, the output end of the foam generation device communicates with the ends, away from the goaf, of the foam injection pipes, and a plurality of foam release openings are formed in the foam injection pipes at equal intervals in the length direction; and an old channel can be automatically closed and a new injection point can be opened along with collapse of overlying strata. According to the air leakage stoppage device, the foam injection pipe is laid on the coal wall of the protection coal pillar, the construction cost is low, the air leakage stoppage device cannot be crushed by fallen rocks, and meanwhile, the released foam can effectively block an air leakage channel in a triangular area.

The invention discloses an ore separation injection control method and system and a medium, and the method comprises the steps: updating the estimated movement time of ore on a belt according to the # imgabs0 # moment, if the ore position # imgabs2 # at the # imgabs1 # moment is greater than or equal to the distance # imgabs3 # from a detector to an injection point, adding 1 to the number of iterations # imgabs4 #, updating the ore position # imgabs6 # at the # imgabs5 # moment, and if the number of iterations # imgabs2 # is greater than or equal to the distance # imgabs3 # from the detector to the injection point, adding 1 to the number of iterations # imgabs4 #; a Kalman filter is adopted to update the predicted value # imgabs9 # of the belt speed of the belt at the # imgabs7 # moment to the # imgabs8 # moment until the condition is met, and finally the estimated movement time # imgabs10 # of the ore on the belt is updated, and the delay time of ore separation blowing control is determined. The uncertainty caused by belt speed fluctuation and sensor feedback delay is effectively reduced on the premise of ensuring the prediction precision of the ore motion trail.

The embodiment of the invention provides a corner tangential coal-fired boiler SCR denitration system and an ammonia injection grid partition control method thereof, and the method comprises the steps that an ammonia injection grid is divided into a plurality of independently-controlled large areas based on the combustion characteristics and flue gas flow characteristics of a coal-fired boiler, and each large area is internally provided with a plurality of ammonia injection grid injection points; a manual valve and an automatic adjusting valve are arranged in each large area, the ammonia spraying amount of a spraying point of a single ammonia spraying grid is adjusted through the manual valve, and the total ammonia spraying amount of the whole large area is dynamically adjusted through the automatic adjusting valve; and the NOx concentration and the ammonia escape concentration corresponding to each large area are monitored in real time, and the ammonia spraying amount of each large area is dynamically optimized through a control algorithm based on the boiler operation load change, so that the ammonia spraying distribution of each large area is matched with the NOx concentration distribution.

The invention discloses a gas lift reverse circulation bottom hole pressure prediction method. The method comprises the steps that regional grid division is carried out; calculating unit parameters; determining an iterative calculation position; and outputting bottom hole pressure. The gas lift reverse circulation drilling technology is one of typical shaft bottom negative pressure drilling technologies, and the technology can greatly reduce shaft circulation pressure consumption, reduce the shaft bottom hold-down effect and effectively reduce the probability of well leakage. The invention aims to deduce a calculation method for predicting the gas injection point pressure and the bottom hole pressure under the gas lift reverse circulation, which provides important reference for predicting the bottom hole pressure and preventing well leakage, and has important significance for the development of the gas lift reverse circulation technology.

A method of producing a gas from a combustible material is provided. The method comprises the steps of loading the combustible material into a containment structure and sealing it therein. An oxidant is fed into the sealed containment structure with a controlled flow rate and a controlled rate of movement such that the combustible material is partly converted, thereby leaving behind thermally affected layers of combustible material after the injection point has passed through the material. At least some of the combustible material is converted into molten slag and or char that accumulates as the bottom-most thermally affected layer and subsequently cools and solidifies. The method is characterised in that it further includes the step of discharging solid slag and or char in the bottom-most thermally affected layer from under material that remains in the containment structure to remove solid slag and or char from the containment structure.

The invention discloses a process for energy conservation and consumption reduction in cement industry, and relates to the technical field of hazardous waste co-processing and flue gas denitration environmental protection, and the process comprises the following steps: step 1, selecting liquid hazardous waste with a heat value within a certain range, and fully atomizing the liquid hazardous waste through compressed air and a special spray gun; step 2, at a calorific value liquid hazardous waste adding point in a denitrification furnace system, spraying the atomized liquid hazardous waste into the denitrification furnace at a high speed; 3, according to the temperature working condition and the NOX concentration in the denitrification furnace system, the pulverized coal injection amount of a coal injection point of the denitrification furnace is reduced, and the ammonia water use amount of the SNCR denitrification system is adjusted; 4, monitoring the concentration, temperature and pressure parameters of gas components such as NOX and CO in the flue gas in real time through a plurality of detection points, and remarkably reducing coal consumption by replacing pulverized coal with liquid dangerous waste heat values; reducing gases such as CO and H2 are supplemented through hazardous waste combustion, so that the self-denitration effect of the denitrification furnace is enhanced, and the consumption of ammonia water is reduced.

The invention provides a chromium-polluted aquifer in-situ layered injection remediation method based on a response curved surface. The method comprises the following steps that a prediction model is constructed based on a response curved surface method, optimal agent parameters are predicted, pilot test verification is conducted based on the predicted optimal agent parameters, and the optimal pilot test agent injection amount is determined; establishing a relational expression between the agent injection concentration and the initial concentration of the underground water Cr (VI) based on the theoretical agent dosage, the adsorption capacity of the water-containing medium to the agent and the model prediction result; the optimal pilot plant test agent injection amount is the total injection amount of all the injection points, and according to the relational expression, the agent injection concentration of all the injection points in the chromium pollution site is determined. The method disclosed by the invention can be used for accurately regulating and controlling medicament parameters in actual engineering application, improving the remediation efficiency, shortening the construction period and saving the capital cost, fully remedying the chromium-polluted aquifer and reducing the risk of'yellowing 'of underground water in the later period, and is suitable for in-situ remediation construction application of the large-scale polluted aquifer.

The utility model discloses a rubber product ozone resistance experiment device, which comprises a case and sliding covers installed on the outer walls of the two sides of the case in a sliding mode, side baffles are fixed on the outer walls of the sides, away from the sliding covers, of the case, a sliding telescopic piece is installed at the top end of the case, and a main tensioning piece is installed at the movable end of the sliding telescopic piece. An auxiliary tensioning piece which is located on the same horizontal datum plane with the main tensioning piece is installed on the top of the side baffle. According to the utility model, the ozone exposure condition of the rubber ring in the actual use environment can be more truly simulated by actively supplying ozone, the performance change of the rubber ring can be more comprehensively evaluated by actively supplying ozone and arranging the injection points, and the ozone can be concentrated in a specific area by arranging the injection points; the performance changes can be observed and evaluated more accurately, and more detailed performance evaluation of the rubber ring can be provided, so that proper materials and designs can be selected.

This invention provides a micro-acidification downhole formation testing device and a micro-acidification method based thereon. The device includes a hydraulic power module, a compartmentalized acid-carrying unit, an acid injection / discharge pump unit, a probe module, a downhole observation chamber for acid-formation reaction, a pipeline system, and a control circuit. The hydraulic module is configured to drive tool movements and control the testing process via hydraulic power. The acid injection / discharge unit is configured to control fluid flow, circulation, and pressure regulation. The injection probe of the probe module is seated at the target acidification or acid fracturing test injection point, connecting the device to the formation. The downhole observation chamber for acid-formation reaction is configured to monitor the physical / chemical parameters during injection / discharge. This invention effectively solves the problems of acid system and acid formulation screening, optimization, and process optimization in real-world acid environments within formations.

To control hydrostatic backpressure of disposal wells connected to a disposal plant surface network, density of water to be injected from a water disposal plant system into disposal wells formed in a subterranean zone, a density of a hydrostatic backpressure-modifying additive to modify a density of the water, a target total injection flow rate of the water, and a vertical depth of a portion of the subterranean zone through which the water is to be injected are identified. Injected water flow rate upstream of an injection point into the multiple disposal wells, wellhead injection pressure needed to achieve the target total injection flow rate and a total injection rate are periodically received. Based on these parameters, dosage rate of the additive to maintain the target total injection flow rate is periodically determined. An additive quantity is injected into the water and periodically modified based on the periodically determined dosage rate.

Provided is a proportioner having one or more proportioner inlets to receive a common concentrated proppant fluid comprising a proppant, two or more flow lines fluidly connected to the one or more proportioner inlets, two or more proportioner outlets, each of the two or more proportioner outlets associated with one of the two or more flow lines, one or more fluid inlets, each of the one or more fluid inlets for introducing a proppant-free fluid to the proportioner, and a metering system associated with at least one of the two or more flow lines. Each metering system is positioned upstream of the proportioner outlet of the flow line with which it is associated and is fluidly connected with at least one of the one or more fluid inlets for proportioning one of the proppant-free fluids into the associated flow line at an injection point.

The utility model relates to the field of thermal insulation pipes, in particular to an anti-corrosion thermal insulation steel pipe. Due to the fact that the glue injection point is fixed and the foaming agent solidifies quickly, a technical problem of uneven foaming density near the injection point and the edge of the thermal insulation pipe is caused. A hole is opened on the flange between the outer pipe and the inner pipe, and glue injection pipes are respectively passed through the holes of the flanges at both ends. The sealing ends of the two glue injection pipes are connected to a supporting disc, and the outer ends of the glue injection pipes can be connected to a glue injection mechanism. When connected, the glue injection pipes are located at the upper part of the thermal insulation pipe. When the glue injection pipes are located at the upper part, the glue outlets on the pipe wall face downward, and a plurality of glue outlets are evenly distributed on the glue injection pipes. The foaming agent is guided by the glue injection pipes to be sprayed from the evenly distributed glue outlets at the same time, so that the gap between the inner and outer pipes is injected with glue synchronously by the plurality of glue outlets, the foaming density in the gap is uniform, and the foaming agent is filled in the connecting hole of the supporting disc, thereby enhancing the thermal insulation effect at the supporting disc.

The utility model relates to the technical field of uniform distribution of tracers, in particular to a tracer mixing and uniform distribution device. The tracer agent mixing and uniform distribution device comprises an equidistant spiral distribution pipe, threaded agent discharging holes are formed in the equidistant spiral distribution pipe, a flow dividing barrel is mounted on each threaded agent discharging hole, and liquid distribution holes are formed in the barrel wall of each flow dividing barrel; and a flexible belt is distributed on the outer cylinder wall of the shunting cylinder. According to the tracer agent mixing and uniform distribution device, the tracer agent is uniformly distributed into the oil well filling pipe in a multi-point injection mode through the liquid distribution holes which are annularly distributed, the injection points can cover the whole section of the filling pipe, the concentration of the tracer agent can be uniformly distributed, the problem of concentration difference of traditional single-point injection is solved, and the tracer agent mixing and uniform distribution device is simple in structure and convenient to operate. The reliability of monitoring data is greatly improved, the dynamic movement of the flexible belt can disturb the mixing area of the tracer agent and the water liquid, the layered flow state is broken, the diffusion range of the tracer agent is further expanded, and the mixing process is completed in a short distance.

The present disclosure relates generally to systems, apparatuses, and processes for preparing a gas-infused additive that is useful within gas-floatation systems configured to separate solids and / or oils from a liquid within a suspension. The gas-infused additive can be injected into systems having a floatation consolidator to provide additional dissolved gas to the system. Advantageously, the processes and apparatuses disclosed herein are compatible with systems and processes having a single injection point for the addition of an additive or gas, without requiring substantial modification or reconfiguration of the system. The inventions described herein additionally teach that the gas-infused additive can be prepared and injected downstream of any pump present within the system, thereby protecting the pump from the damaging effects of cavitation corrosion and similar phenomena.

The present invention provides a method for calculating the turnover change of a natural gas pipeline network, which relates to the technical field related to gas transmission pipelines. The method comprises the following steps: dividing the target area pipeline network by collecting the pipeline network topology structure and the pipeline transmission price, and obtaining several regional distributions; collecting cross-border gas transmission pipelines, gas storage reservoirs within the region, and LNG receiving stations in adjacent regions; collecting the flow direction of natural gas resources in the target area pipeline network, and marking the injection points of the gas transmission pipelines, gas storage reservoirs within the region, and LNG receiving stations by using the flow direction of natural gas resources to obtain the marked injection point distribution; counting the injection resource transportation data of each injection point within a preset time, and calculating the average transportation distance of each injection point; and calculating the turnover change of the target area pipeline network based on the average transportation distance and the change in the transmission volume; and solving the technical problem that it is difficult to objectively and reasonably calculate the impact of a new pipeline project on the turnover of a regional pipeline network or a national pipeline network in the economic evaluation of a new natural gas pipeline project.

According to the deslagging and drainage device and system for the coal seam downward inclined drill hole, high-pressure gas jet flow and powerful mechanical spiral disturbance are cooperated, the deposition state of drilling cuttings and accumulated water at the bottom of the hole is broken, effective bottom cleaning is achieved, formation of a slag water cushion is avoided, and the risk of drill jamming is remarkably reduced; an optimized gas-liquid injection point (gas is in the middle and the lower part, and liquid is in the upper part) is combined with a spiral flow guide structure of the drilling tool, so that uniform and stable low-density gas-liquid-solid three-phase rotational flow is created. The flow state greatly reduces energy needed for overcoming gravity, and efficient and low-energy-consumption improvement of obliquely downward drilling is achieved. The intelligent gas-liquid collaborative deslagging and drainage system for the obliquely downward long drill hole of the coal seam is simple in structure, reasonable in overall structure, high in deslagging and drainage efficiency and high in adaptability. The system can effectively overcome the influence of gravity, prevent slag water at the bottom of the hole from being accumulated, keep the annulus unblocked, and remarkably improve the construction efficiency and safety of the obliquely downward long drill hole.

This invention belongs to the field of spatial location technology for geological defects, and provides a method and system for spatially locating water-conducting fracture zones in coal mines. The method involves establishing a three-dimensional prior geological model of the target area in the coal mine; setting at least one tracer injection point and multiple receiving points in the target area; injecting fluorescent nano-tracers; acquiring tracer concentration-time response data at each receiving point and extracting characteristic parameters; constructing a three-dimensional forward model based on the three-dimensional prior geological model and the extracted characteristic parameters, which includes a groundwater flow model and a tracer transport model; comparing the measured response with the forward model output, constructing a joint objective function, iteratively inverting the parameters to be estimated, obtaining the optimal parameter combination, and obtaining the three-dimensional spatial location, development height, extension direction, connectivity direction, influence range, and uncertainty results of the water-conducting fracture zone. This invention achieves water inrush source identification, water-conducting fracture zone location, and risk quantification assessment.

Disclosed are systems and methods for processing liquefied natural gas (LNG). The method includes directing cooled natural gas to a first column, directing natural gas liquids from the first column into a second column, generating, by the second column, a reflux stream, and directing the reflux stream to a point upstream of the second column, wherein an introduction of the reflux stream enhances a removal of heavy hydrocarbons from a gas in the LNG facility. The method further includes directing an output of the second column to a third column, generating, by the third column, a solvent stream, and directing the solvent stream into an injection point, wherein the introduction of the solvent stream lowers a freezing point of a feed gas in the LNG facility.

Non-electric, automatic fire extinguishing system without pressure storage, characterized in that: it comprises a gas source for temperature sensing (1), a pneumatic pipeline (2), a pneumatic starter (3), a gas generator (4), a reservoir for fire extinguishing agent (5) and a pipeline for spraying (6); the gas source for temperature detection (1), the pneumatic pipeline (2), the pneumatic starter (3) and the gas generator (4) are connected in sequence; the storage container for fire extinguishing agent (5) comprises a first outlet and a second outlet; the gas generator (4) is connected to the first outlet of the storage container for fire extinguishing agent (5) and the pipeline for spraying (6) is connected to the second outlet of the storage container for fire extinguishing agent (5); the gas source for temperature detection (1) is set up to detect the ambient temperature and to generate gas; the pneumatic pipeline (2) is designed to convey the gas generated by the gas source for temperature detection (1) to the pneumatic starter (3) and to trigger the operation of the pneumatic starter (3) by the conveyed gas pressure; the pneumatic starter (3) is designed to ignite the gas generator (4) during operation; the gas generator (4) is designed to generate gas to drive the injection of an extinguishing agent into the storage container for fire extinguishing agent via the pipeline to the injection (6).

This invention discloses a device and method for separating and controlling gas injection points. It mainly consists of a winch system, a sealing system, a power system, and a control system. The gasifying agent is fed into the gasification working face through a continuous tube with a certain degree of flexibility and strength. The first end of the continuous tube is placed inside the gasifier and connected to a nozzle or flamethrower. The second end of the continuous tube passes through the sealing system, exits from the working hole of the gasifier, and connects to the winch system. The second end of the continuous tube is connected to the gasifying agent delivery pipeline. The continuous tube is wound around the winch system. When the gas injection point needs to be retracted, the winch power mechanism drives the continuous tube to move, thereby causing the gas injection point to retract continuously or periodically. During the movement, the sealing system ensures that the outer wall of the continuous tube remains sealed to the wall of the working hole of the gasifier, preventing gas leakage from inside the gasifier.

This specification relates to the field of oil reservoir development technology, and specifically discloses a multi-branch radial well wave injection displacement method and device, wherein the method includes: obtaining reservoir physical property data, injection-production well network data, and production dynamic characteristic data of the target oil reservoir; determining multi-branch radial well network structure data for performing multi-branch radial well transformation on the injection wells in the injection-production well network based on the reservoir physical property data, injection-production well network data, and production dynamic characteristic data of the target oil reservoir; using the production dynamic characteristic data to determine the wave injection parameters for injecting into the transformed multi-branch radial well network; and generating an injection displacement scheme for the target oil reservoir based on the multi-branch radial well network structure data and the wave injection parameters. The above scheme can expand the range of the injected fluid. The multi-branch radial well provides multiple injection points, which can enhance the intensity and range of elastic waves during wave injection, improve the utilization of the remaining oil in the reservoir, and improve the recovery rate.

The invention relates to the technical field of geological exploration, and provides a sedimentary basin strike-slip fracture related oil and gas filling point judgment method, which comprises the following steps: collecting geological information of a target area, obtaining strike-slip fracture segment characteristics, fault properties and strike-slip fracture grids of a hydrocarbon source rock overlying compact layer (such as a gypsum-salt layer) in the target area by adopting qualitative analysis, and determining the strike-slip fracture segment characteristics and fault properties of the target area according to the strike-slip fracture segment characteristics, the fault properties and the strike-slip fracture grids. Determining a rough range of a charging point; calculating the key layer thickness of the hydrocarbon source rock stratum and the compact layer and the conduction coefficient of the top of the compact layer, carrying out normalization processing, and carrying out filling point correction according to quantitative data obtained through calculation and in combination with strike-slip fracture segmentation characteristics; and verifying the corrected charging point according to the fluctuation point of the segmented change of the oil-gas migration index and the crude oil physical property parameter index. According to the method provided by the invention, the accuracy and reliability of the method for judging the strike-slip fracture related oil and gas filling points can be remarkably improved, guiding significance is provided for oil and gas exploration, and exploration benefits are greatly improved.

The invention discloses a CO2 sequestration and gas production collaborative device adaptive to a tight gas horizontal well, and relates to the technical field of gas production and carbon sequestration collaboration.The device comprises a reservoir state sensing module, an intelligent analysis regulation and control module, a CO2 injection regulation and control module, a pressure balance module and a gas production execution module; multi-dimensional data of reservoir stress, concentration and pressure are synchronously collected through the reservoir state sensing module, a multi-field coupling model of the intelligent analysis regulation and control module is combined, the problems that an existing device conducts regulation and control through a single parameter, and stress sensitivity of the tight gas reservoir is not considered are solved, an injection point is accurately adjusted through the CO2 injection regulation and control module, and the reliability of the device is improved. The pressure balance module and the gas production execution module cooperatively adjust the reservoir pressure, the problem of reservoir pressure unbalance is solved, finally, the gas production efficiency of the tight gas horizontal well and the CO2 storage safety are synchronously improved, and it is guaranteed that the cooperative target of energy development and carbon emission reduction is stably achieved.