22 results about "Co2 flooding" patented technology

This application relates to a physical simulation device and method for determining the location of a CO2 flooding front, belonging to the field of physical simulation devices. The device includes a clamp, an imaging device sleeved on the outside of the clamp, an intermediate container filled with CO2 at the inlet end of the clamp, a back pressure assembly at the outlet end of the clamp, a metering assembly between the back pressure assembly and the clamp, and a confining pressure assembly on the clamp. This application has the effect of determining the location of a CO2 flooding front by analyzing changes in oil phase signals in core samples.

The application provides a CO2 oil displacement storage regulation optimization decision method and system, the method obtains a three-dimensional geological model, production dynamic data and monitoring data of a target working area; a component numerical simulation technology is used to fit a CO2 injection production dynamic history of the target working area, so that target operation parameters of a simulation operation model are adjusted and determined to obtain a matched production simulation operation model; a gas-oil ratio is determined according to the production dynamic data, and then a gas channeling index is calculated, and a target well group meeting the conditions of the gas channeling index is selected; a relationship curve distribution between a Peclet number, an oil increment and a component sweep efficiency is determined by simulating different injection speeds to determine an optimized target injection speed; and development parameters corresponding to different injection modes are simulated, and the target injection mode is determined in combination with the gas channeling index, the sweep efficiency and the miscibility degree. The scheme can overcome the defects of the prior art that the parameter optimization is not in place and the precision is insufficient, and can consider the particularity of the CO2 oil displacement mechanism to establish a regulation optimization strategy based on dimensionless parameters.

This invention belongs to the field of CCUS-EOR technology and discloses an interpretable data-driven prediction and optimization method for CO2 enhanced oil recovery and storage. The method includes the following steps: using a CMG-GEM component simulator, numerical simulation is conducted through Monte Carlo sampling to obtain a multimodal data pipeline; a LightUFTrans hybrid model is built to achieve three-dimensional prediction of CO2-EOR and storage performance; LightUFTrans is embedded as a surrogate model into the LA-MONSGA-II optimization framework to obtain the Pareto optimal solution; and the model decision-making mechanism is analyzed from the dimensions of global features, temporal dependence, and spatial distribution by combining SHAP, attention mechanism, and spatiotemporal verification. This invention uses the above method to construct the LightUFTrans multimodal surrogate model, accurately depicting the dynamic evolution of underground spatiotemporal processes, significantly improving computational efficiency, and greatly reducing engineering design and decision-making costs; through multidimensional interpretability analysis, key engineering control parameters are identified, their temporal dynamic characteristics and spatial migration mechanisms are analyzed, overcoming the limitations of black-box models and improving engineering credibility.

This utility model discloses a compressed air device for carbon dioxide-driven oil recovery, belonging to the technical field of carbon dioxide-driven oil recovery equipment. It aims to solve the problems of insufficient self-adjustment performance in existing compressed air devices for carbon dioxide-driven oil recovery, limitations in removing dust and moisture from compressed air, and the need to improve overall working efficiency and stability. The key technical solution includes a first air compressor and a second air compressor. An air storage tank is installed on one side of both the first and second air compressors. Air guide pipes are installed at the outlet ends of both the first and second air compressors, and the other end of the air guide pipes is connected to the inlet end of the air storage tank. This achieves the effect of enabling self-adjustment operation while effectively removing dust and moisture from compressed air, thus improving the efficiency and stability of carbon dioxide-driven oil recovery.

The application belongs to the technical field of oil exploitation, and particularly relates to a dry ice heating and sublimation device for carbon dioxide oil displacement and a use method. The device comprises a cylinder, a sealing assembly, a stacking assembly and a heating assembly. The sealing assembly comprises a round plug, a lower lug, a round rod and a motor. The round plug is in sealing connection with the lower end surface of the cylinder. The output end of the motor drives the round rod to drive the round plug to move up and down. The stacking assembly is located in the cylinder and comprises a support frame and a plurality of round net plates. The heating assembly comprises a peristaltic pump, an electromagnetic heating plate, an external steel pipe connected with the peristaltic pump in sequence, and an internal steel pipe. The internal steel pipe is in a spiral shape and is located between the inner wall of the cylinder and the outer side of the support frame. The outer side of the external steel pipe is provided with the electromagnetic heating plate. The device can concentrate the dry ice and has a circulating flow heating assembly, so that the dry ice can be uniformly heated, sublimated quickly, the water flow speed is fast, and the situation that the water flow speed is slow and the pipe body is blocked by ice can be avoided.

The application provides a bottom water reservoir CO2 oil displacement and storage coordinated development method and system, which collects information of a target work area, and determines a component numerical simulation model matched with the target work area; determines a plurality of deployment positions of a horizontal injection well in a water layer in combination with water injection well conditions, oil layer thickness and oil-water interface positions of the reservoir, and uses the component numerical simulation model to simulate and calculate the deployment positions of the target injection well in order to optimize oil increment and storage capacity; further sets feasible injection parameters, and uses displacement effect and storage effect as optimization targets to simulate and calculate the injection mode of the target parameters; sets feasible injection and production speed combination schemes according to liquid production before gas injection, and simulates and calculates the injection speed and liquid production speed with the optimal oil increment and storage capacity. The scheme can overcome the problem of incomplete optimization effect in the prior art, effectively plays the energy and capacity of edge and bottom water, and realizes the increase of a large oil increment and the increase of CO2 storage capacity.

The application discloses a kind of low permeability reservoir CO2 drive oil storage simulation method and system, the simulation method includes: establishing low permeability reservoir CO2 drive oil storage model;The low permeability reservoir CO2 drive oil storage model is solved, and grid pressure distribution, component concentration distribution and crude oil viscosity distribution result are obtained.Improve the recovery efficiency of low permeability reservoir, while achieving the goal of increasing CO2 storage capacity.The model considers the adsorption of CO2 on the pore surface, the dissolution of crude oil, the dissolution of formation water and the mineralization of aquifer, etc.The model also considers stress sensitivity and threshold pressure gradient to reflect the characteristics of low permeability reservoir.

The application relates to the technical field of oilfield produced gas separation treatment, and particularly discloses a CO2 flooding produced gas pretreatment equipment for oil exploitation, which has the technical features that the pretreatment box body is internally fixedly connected with a flooding produced gas collecting tank at the rear side space, and a gas separation treatment box is arranged at the front side space in the inner cavity of the pretreatment box body. In the scheme, a multistage spraying structure is designed to atomize ammonia water solution, copper ammonia complex solution, sodium sulfite solution and sodium hydroxide solution in sequence, so that the flooding produced gas fully contacts and reacts with the atomized gas, the harmful gas in the flooding produced gas is comprehensively pretreated through a dissolution reaction and adsorption, and the treatment rate of the harmful gas is improved. In addition, the pretreatment station is loaded into a container frame structure, the pretreatment station can be moved along with the replacement of the oil flooding site, and the container frame structure can protect the mechanism for treating the harmful gas and the tank body for storing the flooding produced gas.

The application belongs to the technical field of CO2 flooding, and discloses a method for testing low-permeability sandstone core saturation for CO2 flooding, which comprises the following steps: selecting a rock sample; treating the rock sample; measuring the effective porosity and density of the rock sample; selecting divinylbenzene and styrene as a carrier; using phthalate as a stationary phase, coating the stationary phase on the surface of the carrier to prepare a special saturation analysis chromatographic column, and selecting a chromatographic column with an inner diameter of 4 mm and a length of 2.2 m made of stainless steel; using an organic solvent cleaning method + a hot cleaning method to treat and maintain the contaminated detector; and using a combination of a standard curve method and a normalization method to calculate the instantaneous peak area and the total peak area. After the application of the new method, the measurement accuracy is higher, the various deviation calculations and mathematical statistics values are smaller, the relative standard deviation of the new method is less than or equal to 2.5%, the recovery rate is more than 97.5%, the technical quality and the measurement accuracy are doubled, the dosage of the medicament and the emission of toxic substances are reduced, and the work efficiency and the analysis efficiency are improved.

This invention relates to a method for predicting the miscibility of carbon dioxide flooding, belonging to the field of oilfield development technology. The method of this invention, from a microscopic perspective of component changes, directly and quantitatively characterizes the reservoir miscibility after CO2 flooding. After CO2 injection into the reservoir, the miscibility coefficient is used to characterize the changes of various components in the crude oil within the affected area, thereby calculating the CO2 flooding miscibility within that area. This allows for the evaluation of the CO2 flooding effect in the target block. This method improves the prediction accuracy of carbon dioxide flooding miscibility, provides a basis and technical support for evaluating the effect of injected gas blocks, and can also guide the preparation of CO2 flooding reservoir engineering plans.

The invention provides an injection-production control method, device and equipment and a storage medium, and the method comprises the steps that a control parameter set meeting the crude oil production requirement is determined from a plurality of injection pressure given values and a plurality of injection rate given values based on an injection-production prediction model; taking a preset injection pressure given value and a preset injection rate given value in the control parameter group as an injection pressure control value and an injection rate control value of carbon dioxide to control the carbon dioxide to be injected into the injection well, and monitoring an actual production value of crude oil produced from the production well; and in the carbon dioxide oil displacement production process, whether abnormal well conditions exist in the production well or not is recognized according to the actual production value and the predicted production value, and the predicted production value is obtained based on the injection-production prediction model. By optimizing the injection pressure and the injection rate in carbon dioxide oil displacement and monitoring the well condition of the production well in real time, the crude oil recovery rate can be increased.

The present application belongs to the field of oil and gas field development, and particularly relates to a multi-scale CO2 flooding oil component migration monitoring device and method. The present application sets a long and thin tube variable diameter assembly to build a displacement path with a length of meters or more. Compared with a conventional short core experiment, the present application can carry out displacement experiments on a longer migration scale, thereby being more conducive to characterizing the long-range migration process of CO2 in a porous medium and the formation and evolution characteristics of a miscible phase transition zone. By sequentially setting a matrix pore section, a micro-fracture channel section and a fault blocking section in the device, fluid migration behaviors in different types of seepage channels, including matrix seepage, fracture dominant channel migration and local blocking effect, can be simulated in the same experimental system, thereby improving the adaptability of experimental results to complex reservoir seepage characteristics. By arranging multi-point sampling units along the displacement direction and combining with gas phase component analysis means, dynamic monitoring of CO2 and hydrocarbon components inside the device is realized.

The application discloses a low interfacial tension high-stable foam system for controlling the mobility of CO2 flooding of thick oil, which comprises 0.05-0.5% of a foaming agent, 0.01-1% of a thick oil active inducer and the rest of water in percentage by mass; the foaming agent is compounded by a non-ionic surfactant and an ionic surfactant at a mass ratio of 5:1-1:5; and the thick oil active inducer is one or more of sodium carbonate, ammonium carbonate, potassium carbonate, sodium hydroxide, sodium tert-butoxide, sodium tetraborate, sodium ethoxide, ethylenediamine, diisopropyl alcohol amine and triethylamine. The application can form high-stable foam in the CO2 channeling channel of the thick oil reservoir containing residual oil, effectively inhibit CO2 channeling and expand the CO2 sweeping efficiency; the application can reduce the interfacial tension between the foam system and the thick oil, and further improve the oil washing efficiency of the thick oil reservoir; and the application can use the thick oil active inducer to enhance the foam system to improve the recovery efficiency and reduce the system cost.

The application belongs to the technical field of CO2 flooding well corrosion inhibitor, and discloses a kind of corrosion inhibitor and preparation method thereof applied to CO2 flooding well under complex environment. It is a kind of integrated corrosion inhibitor, which is suitable for corrosion inhibition and sterilization under complex environment of CO2 flooding well. It comprises imidazoline quaternary ammonium salt main agent, dodecyl dimethyl ammonium chloride and methanol. The molar ratio of imidazoline quaternary ammonium salt main agent, dodecyl dimethyl ammonium chloride and methanol is 5-3:1-2:3-6. The corrosion inhibitor can solve the problems existing under the conditions of high CO2, high SRB content, high H2S, high salinity, high temperature and high pressure in CO2 flooding wellbore. It has good corrosion inhibition, sterilization and desulfurization effect.

The application discloses a CO2 flooding oil pumping machine well production operation optimization method and system, relates to the oil and gas field development technical field, and comprises the following steps: a CO2 flooding oil pumping machine well lifting system mechanism simulation model is constructed in advance, and basic sample data is output; taking oilfield measured data as a core sample set, supplementary data is generated in combination with the mechanism simulation model, missing value filling is realized through variance weight correction, scene deviation optimization mechanism model data is introduced, and a training sample set covering overall and balanced distribution is constructed. The XGBoost-PSO collaborative optimization framework is constructed, the quantitative guidance provided by the prediction model is taken as support, the global optimization capability of the PSO algorithm is used, real-time adaptive collaborative optimization of stroke, frequency and casing pressure is realized, the adverse effects of high gas-liquid ratio on the lifting system in the gas breakthrough stage of the CO2 flooding oil pumping machine well can be effectively relieved, pump efficiency and productivity are improved, and efficient and stable operation of the lifting system is ensured.

The application relates to the technical field of oil development, and particularly discloses a carbon dioxide injection-production parameter multi-target optimization method based on Spark distribution, which aims at the problems of large calculation amount of injection-production parameter optimization, target function conflict and the like in the carbon dioxide flooding and storage process, and builds a multi-target optimization model containing cumulative oil production, CO2 storage amount and net present value. By using an Apache Spark distributed computing framework, population individuals are mapped into elastic distributed datasets, and a high-time-consuming oil reservoir numerical simulation task is distributed to cluster computing nodes for execution through a parallel scheduling mechanism; a multi-target aggregation strategy is provided, global non-dominated sorting and congestion calculation are performed on fitness results returned by each node at the Driver end, so that a Pareto optimal solution set is generated. The application can effectively shorten the optimization period, provides diversified injection-production parameter configuration schemes for decision makers on the premise of giving consideration to economic benefits and environmental benefits.

The application discloses a kind of carbon dioxide oil displacement simulation methods based on digital core model, it is related to oil and gas exploration and development field, solve the problem that existing technology adopts real core model has long test cycle, observation measurement parameter exists deviation insufficient etc..The application creates digital core model using real core pore structure characteristics, combines machine learning and artificial intelligence algorithm, fully couples different physical processes, according to different crude oil properties (density, dynamic viscosity), different CO2 injection rate and other parameters, to simulate the dynamic distribution characteristics of remaining oil in the process of CO2 displacement in underground reservoir with single variable.The application method is suitable for low-permeability-low-permeability reservoirs, medium-high permeability sandstone heavy oil reservoirs (CO2 assisted huff and puff) and fractured oil and gas reservoirs for CO2 displacement, and has important significance for evaluating the development effect of CO2 injection in oilfield.The application method avoids the tedious process of repeated oil washing of real core, and improves work efficiency.

The application discloses a CO2 flooding wellbore plugging risk prediction method, device, medium and product, relates to the oil and gas exploration and development risk prevention and control technical field, and the method comprises the following steps: obtaining CO2 flooding wellbore structure data and CO2 flooding wellbore state data; constructing a wellbore model based on the CO2 flooding wellbore structure data; constructing an energy model based on the wellbore model and the law of conservation of energy; constructing a pressure model based on the wellbore model and the law of conservation of momentum; iteratively solving based on the CO2 flooding wellbore state data by using the energy model and the pressure model respectively to obtain wellbore temperature and pressure distribution; performing phase state analysis on the wellbore temperature and pressure distribution to obtain a phase state analysis result; and determining a wellbore plugging risk prediction result based on the phase state analysis result. The application can accurately predict the plugging risk area in the wellbore.

This application discloses a method, apparatus, equipment, and medium for assessing the multiphase production capacity of oil and gas wells. The method preprocesses the raw data of the oil and gas well to obtain dimensionless data. Then, it uses natural gas wellhead instruments to collect the gas phase flow rate, oil phase flow rate, and water phase flow rate after separation by the wellhead splitter in real time to determine the wellhead production gas-liquid ratio, thereby calculating the bottom-hole liquid water cut. Combining the dimensionless data, productivity index coefficient, and wellhead production gas-liquid ratio, the productivity index of the oil and gas well is calculated. Finally, the production capacity of the oil and gas well is assessed based on the productivity index, enabling the assessment of production capacity under high gas-liquid ratio conditions caused by CO2 flooding. This improves the accuracy of the assessment, provides assessment results for production reduction caused by liquid accumulation in oil and gas wells, and extends the lifespan of oil and gas wells.

The utility model discloses an injection device for carbon dioxide oil displacement, including chassis, pressure tank, carbon dioxide inlet pipe and two groups of compensation column cavity shell, the pressure tank fixed mounting is to the chassis, two groups the one end of compensation column cavity shell all is connected to the pressure tank through one -way compensation exhaust pipe, the pressure tank is connected with injection pump head through pipeline, the outside installation of pressure tank has controller, the end of carbon dioxide inlet pipe is equipped with the four -way pipe head, one pipe head of four -way pipe head is connected to the pressure tank through pipe one -way inlet pipe, two pipe heads of four -way pipe head are connected to two compensation column cavity shell respectively through one -way compensation inlet pipe, and the sliding plug in the compensation column cavity of compensation column cavity shell is equipped with the compensation plug. Advantageous effect lies in the stability of carbon dioxide whole injection oil displacement process is realized through the compensation power structure cooperation pressure tank, reduces the unstable flow and the injection instability situation caused by the storage tank storage capacity change.

This invention is an oil well production fluid heating system utilizing photovoltaic-assisted power generation. The PLCs in the blowout heating control device and the gathering and transportation heating control device are electrically connected via wires to the explosion-proof blowout heating body and the temperature sensors in the gathering and transportation heating body. The two-phase high-frequency AC power generated by the blowout heating control device and the gathering and transportation heating control device is electrically connected via cables to the electromagnetic coils in the blowout heating body and the gathering and transportation heating body. The two-phase DC power generated by the photovoltaic panel is connected to an inverter, which sequentially supplies the inverted 0.4kV three-phase AC power to the multi-functional electricity meter and automatic circuit breaker in the ring network control cabinet. The blowout valve can be connected to the blowout heating body to heat the gas and liquid before blowout. The gathering and transportation heating body is connected between the production valve and the gathering and transportation process to heat the oil well production fluid for external transportation. This invention is applicable to carbon dioxide flooded oil wells and production wells, solving the problems of blowout freezing and blockage in oil wells and the need for heated gathering and transportation of oil well production fluids.