52 results about "Sweep efficiency" patented technology

The invention belongs to the technical field of oil and gas field development, and particularly relates to a CO2 thickening agent for supercritical CO2 oil displacement and a preparation method of the CO2 thickening agent. The preparation method of the CO2 thickening agent for supercritical CO2 oil displacement comprises the following steps: (1) mixing a maleic anhydride compound and a styrene compound, dissolving in water, introducing inert gas, and heating; (2) slowly dropwise adding a mixed solution of a vinyl acetate compound and an initiator, and cooling after the reaction is finished; and (3) filtering, washing a solid phase by using an anhydrous alcohol substance, drying, and grinding to obtain a thickening agent product. The supercritical CO2 thickened by the thickening agent prepared by the invention can effectively slow down the viscous fingering phenomenon in the displacement process and improve the CO2 sweep efficiency, thereby improving the crude oil recovery rate.

The layered water distributor comprises multiple stages of layered water distributors which correspond to water injection layers and are connected between two adjacent oil pipes, packers are arranged between the outer portions of the oil pipes at the upper end and the lower end of each stage of layered water distributor and a sleeve in a sealed mode, and the top end of the oil pipe at the uppermost end is communicated with a ground water injection pipeline. A water injection regulating valve and a flow meter are arranged on the ground water injection pipeline, and the water injection regulating valve and the flow meter are in common electric signal connection with a ground layering controller. The underground layered water injection rate is metered by the ground layered controller and linked with the layered water distributor of the underground target interval, layered alternate pulsating water injection is carried out, interlayer interference factors are overcome, and layered accurate water injection is achieved; additional fluid channeling, gravity fluid channeling and capillary force fluid channeling generated by pulsation type unstable water injection solve the problem of invalid water injection of dominant channels. Oil reservoir pressure field changes generated by layered pulsating water injection expand the water injection sweep efficiency, and the water injection recovery efficiency is greatly improved.

The application provides a low-grade oil reservoir water injection development effect evaluation method, comprising the following steps: S1, collecting core scale limit oil displacement efficiency data; S2, collecting well pattern controlled reserve degree data; S3, calculating sweep efficiency of the low-grade water drive oil reservoir; S4, correcting the sweep efficiency according to the changes of reservoir physical property parameters caused by near-well pollution and reservoir energy decline; and S5, calculating the reference recovery rate and evaluating the development effect. The application can effectively avoid collecting and arranging a large number of cumbersome production dynamic data, fully utilize the flow characteristics and dynamic physical property parameter evolution of the low-grade oil reservoir, accurately evaluate the development effect of the low-grade oil reservoir, and be beneficial to efficient development of the low-grade oil reservoir.

The embodiment of the invention provides a compound system determination method and device, a storage medium and a shale oil development method, and belongs to the technical field of shale oil. The determination method comprises the following steps: performing corresponding oil-gas interface tension and liquid-solid interface wettability measurement on a plurality of obtained initial composite nano systems, and screening out a first composite nano system; based on the first composite nano system, calculating parameter values influencing the pore structure, pore size and asphaltene content of the shale reservoir rock, and screening out a second composite nano system; and determining the micro-fluidic sweep efficiency and the core throughput recovery rate of the second composite system to determine the optimal composite nano system. According to the principle from microcosmic to macroscopic and from experiments to mine fields, the optimal composite nano system is screened out through three-stage screening, and the shale oil reservoir development problems that due to the fact that an existing CO2 and chemical additive system is single in screening standard, a displacement relation cannot be established between wells, and the mine field implementation effect is poor are solved.

Described is a method for evaluating oil recovery. The method includes performing a pre-coreflood process, a coreflood process, and a post-coreflood process. The pre-coreflood process includes preparing heterogenous cores samples with different structural configurations. The coreflood process includes injecting a treatment into the core samples and obtaining nuclear magnetic resonance (NMR) measurements of the treated core samples. NMR measurements are compared to assess performance of the treatment. The post-coreflood process includes conducting an X-ray micro-computerized topography (CT) scan and a Saturate, Aromatic, Resin, and Asphaltene (SARA) analysis on the treated core samples.

The application discloses a kind of well group control reserves chemical flooding sweep efficiency calculation method, comprising the following steps: (1), three-dimensional fine porosity and permeability model is established;(2), well group control reserves chemical flooding sweep efficiency calculation.This method can improve the accuracy of well group control reserves chemical flooding sweep efficiency calculation, so as to provide accurate basis for chemical flooding reservoir engineering design, numerical simulation accuracy, tracking adjustment and post-evaluation of implementation effect of scheme.Compared with the traditional chemical flooding sweep efficiency calculation, the method is more scientific, the concept is clearer, the index is more quantitative, and the chemical flooding sweep efficiency calculation result is more accurate and reliable, which has important significance for guiding oilfield production and development.

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.

The application discloses a simulation device and method for improving the producing degree of a tight reservoir by using inter-fracture displacement and well sealing. The experimental device comprises a temperature and pressure loading module, a first core monitoring module, an automatic control module, a second core monitoring module, a liquid injection module and an inter-fracture displacement simulation module. The experimental method comprises a preparation step before the experiment, a data measurement step, and a real-time control step of the automatic control module, wherein the data measurement step comprises a reservoir environment simulation step, a liquid injection step, a well sealing and displacement step, and a data collection step. The experimental device and method consider actual factors such as the temperature and pressure environment of the reservoir, the flow rate of the fracturing fluid and the well sealing time, can realize the monitoring of the oil displacement amount and the semi-quantitative characterization of the fracturing fluid sweep efficiency, and thus provide a certain basis for the fracturing construction design of an oilfield.

The invention relates to a variable exhaust high-power two-stroke industrial engine, and belongs to the technical field of internal combustion engines. The engine comprises an engine body, an exhaust assembly and an air inlet control unit. The air inlet control unit is composed of a reed valve, an air filter, an electronic control unit and a reed pipe. The reed valves are hinged through an adjustable pin shaft, and a closed-loop feedback control loop is formed by combining non-contact detection of the reed pipes; the electronic control unit dynamically adjusts the opening angle and frequency of the reed valve through a fuzzy algorithm based on the rotating speed signal and the accelerator opening degree, and the scavenging efficiency is optimized; a rotatable baffle driven by a stepping motor is arranged in a three-way catalytic assembly of the exhaust assembly, the opening degree of the rotatable baffle is linked with an air inflow signal, and dynamic matching of exhaust back pressure and catalytic temperature is achieved. The problems that a reed valve of a traditional two-stroke engine is prone to fatigue, the catalytic efficiency is low, and emission exceeds the standard are solved, and the combustion efficiency and the environmental protection performance are remarkably improved.

The application provides a Pickering emulsified solvent profile control agent and a preparation method and application thereof. The Pickering emulsified solvent profile control agent comprises the following raw material components in percentage by mass: 1.0%-3.0% of nano-bentonite particles, 0.005%-0.05% of a surface modifier, 0.0005%-0.001% of a pH regulator, 5%-20% of solvent oil, and the balance of water. The Pickering emulsified solvent profile control agent has high viscosity, strong flow control and good stability. When applied to water flooding of thick oil cold production, the Pickering emulsified solvent profile control agent can effectively reduce the viscosity of thick oil, has high sweep efficiency, and can effectively improve the recovery rate of water flooding of thick oil cold production.

The invention discloses an emulsified particle channeling sealing agent for CO2 flooding as well as a preparation method and application thereof, and belongs to the technical field of CO2 flooding of oil reservoirs. The emulsified particle channeling sealing agent for CO2 flooding comprises the following components in percentage by weight: 20-30% of matrix asphalt, 1.6-2% of latex, 0.8-1.2% of a softening agent, 3-5% of an emulsifier, 0.1-0.5% of a dispersing agent, 0.4-1.3% of a pH regulator and the balance of deionized water. The emulsified particle channeling blocking agent for CO2 flooding can effectively block deep cracks or large pore channels of a reservoir, enlarge the sweep efficiency of CO2 in an oil reservoir and improve the CO2 flooding recovery efficiency, has excellent temperature resistance, acid resistance and salt resistance, and is harmless to a reservoir matrix.

The utility model belongs to the technical field of filtering equipment, and particularly relates to a filtering base plate with a back flushing function, which comprises a base plate and a back flushing device, a plurality of through holes are formed in the supporting disc, the supporting disc is arranged above the chassis, and a collecting cavity is formed between the supporting disc and the collecting plate; the filtering piece is fixed above the supporting disc; a purging pipeline is fixed to the upper surface of the collecting plate, a plurality of purging holes are formed in the purging pipeline, and the lower end of the collecting plate is connected with a conveying pipeline connected with the purging pipeline. The purging structure of the filtering chassis is improved, the purging pipeline is fixed on the upper surface of the collecting plate, the purging holes are formed in the purging pipeline, and the purging pipeline is connected with the conveying pipeline of the purging pipeline, so that a purging medium firstly enters the collecting cavity and then purges a filtering piece through the supporting disc, the maximum purging surface is realized, and the purging efficiency is improved. The purging efficiency is improved, and the purging pipeline is more convenient to connect.

The invention provides active nanoparticles, a fracturing oil-displacing agent and application of the active nanoparticles and the fracturing oil-displacing agent, and belongs to the technical field of oil reservoir exploitation. The active nanoparticles are obtained by reacting a first silane coupling agent containing sulfydryl with hydrogen peroxide and then reacting with a second silane coupling agent containing phenyl, propyl or octyl. The fracturing oil displacement agent comprises active nanoparticles, an anionic or anionic-nonionic surfactant and water. The active nanoparticles provided by the invention are small in particle size, and have good dispersing performance, amphipathy, interfacial activity and capability of reducing oil-water interfacial tension; the fracturing oil-displacing agent constructed based on the active nanoparticles has the advantages of high temperature and high salt resistance, wetting reversal, strong imbibition and oil discharge capability and good drag reduction performance, and can reduce injection pressure, improve sweep efficiency, improve pressure-driven oil displacement effect and improve recovery efficiency.

The invention relates to a method and a device for determining an oil reservoir water flooding sweep efficiency. The method comprises the following steps: acquiring a relative permeability curve of an oil reservoir, geological reserves and cumulative oil production and water content at multiple times, and calculating to obtain a water flooding sweep coefficient at the corresponding time according to the relative permeability curve, the geological reserves and the cumulative oil production at the multiple times, obtaining multiple groups of data of the water content and the water flooding sweep efficiency according to the water content at the multiple times and the water flooding sweep efficiency at the corresponding time, and performing nonlinear fitting according to the multiple groups of data of the water content and the water flooding sweep efficiency to obtain a relational expression between the water flooding sweep efficiency and the water content; and according to the relational expression between the water flooding sweep efficiency and the water content, predicting to obtain the water flooding sweep efficiency corresponding to any water content. The relational expression, obtained through the method, of the water flooding sweep efficiency and the water content conforms to the actual development of oil reservoirs, and the change rule between the water content and the water flooding sweep efficiency can be well analyzed.

In situ combustion can be implemented in a vapour chamber formed by a solvent- or steam-assisted process, where various methods are leveraged. Ignition can be facilitated by heating the well through which an oxygen containing gas is injected using a downhole heater previously used in the context of the solvent- or steam-assisted process. The solvent- or steam-assisted process can be operated until the vapour chambers of adjacent well pairs coalesce in order to enhance combustion sweep efficiency between the well pairs. In addition, the in situ combustion stage can be combined with blowdown or winddown stages to enhance certain aspects of the hydrocarbon recovery operation and solvent recovery.

The application discloses a kind of automatic frequency tracking method and system based on sweep mode, frequency is swept by the way of combination of " rough sweep+fine sweep ", first by " rough sweep " of big step, " rough sweep " is the method of difference of adjacent frequency point reflected voltage to judge sweep direction, determine a smaller frequency range containing inflection point, in this frequency range, small step " fine sweep " is used, compare the size of each frequency point reflected voltage, the frequency point corresponding to the minimum reflected voltage is the resonant frequency point of accelerating tube.The application compared with traditional frequency discrimination type automatic frequency tracking method, on the basis of ensuring sweep precision, improve sweep efficiency, can quickly obtain the actual resonant frequency of accelerating tube.

The invention belongs to the technical field of oilfield exploitation, and particularly relates to a method for determining a conglomerate oil reservoir gel-carbon dioxide alternate displacement critical pressure gradient. The problem that the alternate displacement efficiency and sweep efficiency are low due to the fact that the gel-carbon dioxide alternate displacement pressure gradient of the conglomerate oil reservoir is unreasonable at present is solved. According to the technical scheme, the method comprises the steps that a large-scale physical model is established, gel-carbon dioxide is preferably selected as an alternate displacement medium, well periphery plane oil saturation change values under different displacement pressure gradients are obtained, and alternate displacement efficiency and sweep efficiency under the different displacement pressure gradients are calculated according to the well periphery plane oil saturation change values; displacement pressure gradient, sweep efficiency and alternate displacement efficiency charts are established, and in different stages of actual production, alternate displacement critical pressure gradients of the conglomerate oil reservoir in the first 500 days and the last 500 days can be determined according to the two charts; the new method provided by the invention can provide a scientific basis for practical application, reduce the operation cost and improve the oil reservoir exploitation benefit.

The invention provides a compact low-permeability reservoir fracturing well pattern gas drive effect prediction method and system, and relates to the technical field of gas drive effect prediction. The method comprises the following steps: firstly, determining basic geometric parameters of a rhombic inverted nine-point well pattern of a target block and fracturing design parameters to be optimized; and constructing a well pattern embedded into the main fracture and a fracture parameterized model, and reflecting a coupling relationship between the fracture and matrix flow. A training sample is generated through experimental design, rapid flow simulation is conducted through a parameterized model, and space collaboration quantitative indexes such as a gas shortest breakthrough time index, an effective wave and coefficient correction factor and a displacement pressure gradient strengthening factor are calculated. Performing extended production dynamic simulation on part of samples to obtain key indexes such as accumulative oil production and accumulative gas-oil ratio, and training a machine learning agent model; and with maximization of the cumulative oil production and the gas shortest breakthrough time index and control of the cumulative gas-oil ratio as optimization objectives, a multi-objective optimization algorithm is adopted to obtain a Pareto optimal solution set, and a final recommendation scheme is screened out.

The present application provides a kind of shale oil horizontal well volume fracturing ultimate recoverable reserves prediction method, first based on the reservoir geological parameters of the horizontal well to be measured and adjacent horizontal well in the same block, establish productivity prediction model, calculate effective fracture network sweep efficiency using reservoir numerical simulation method, and establish effective fracture network sweep efficiency and maximum recoverable reserves correlation prediction chart;Secondly, the correlation coefficient between the geology and volume fracturing reconstruction parameters of the horizontal well to be measured and the fracture network sweep volume is calculated using grey relational analysis method, and the key control parameters affecting fracture network sweep volume are determined;Finally, the fracture network sweep volume prediction model coupled with key control parameters is established, the fracture network sweep volume of the horizontal well to be measured is obtained, the effective fracture network sweep efficiency is obtained, and the maximum recoverable reserves of the horizontal well to be measured is obtained using the correlation prediction chart. The method can quickly predict the maximum recoverable reserves of any horizontal well by establishing the correlation chart of effective fracture network sweep efficiency and maximum recoverable reserves.

The invention relates to the technical field of oil and gas field development, and provides a non-Newtonian fluid displacement front calculation method considering a gravity effect and electronic equipment. Establishing a shunt equation considering the non-Newtonian fluid shear rate related viscosity and the gravity number; calculating the shunt equation by using a characteristic line method to obtain a Beckley-Levilt expansion equation, and obtaining an implicit solution of the leading edge position through integral transformation; calculating a nonlinear equation of the front edge position by using a Lanbert W function, performing approximate estimation on the value of the Lanbert W function in combination with a Wenniz analytic solution function, and explicitly calculating the front edge position; and according to the calculation result of the analytical solution, determining the front edge position of non-Newtonian fluid displacement under different apparent viscosities and different reservoir dip angles. The analytical solution has guiding significance for solving the gravity effect problem in the two-phase flow, and the change condition of the front edge position can be predicted through the model, so that a more effective development scheme is formulated, and the sweep efficiency and the crude oil recovery rate are improved.

The invention discloses a multi-channel vibrating wire strain gauge low-voltage sweep frequency detection method, belongs to the technical field of vibrating wire strain gauges, and aims to solve the problems of complex low-voltage sweep frequency control and poor stability and accuracy. According to the method, the frequency value obtained by last frequency sweeping is used as the initial value of current frequency sweeping, so that the frequency sweeping process can start searching from the position closer to the resonant frequency, the unnecessary frequency scanning range is reduced, meanwhile, the relation between the excitation frequency and the resonant frequency can be rapidly judged based on the dynamic adjustment strategy of the phase difference change rate, and the accuracy of frequency sweeping is improved. Compared with a traditional low-voltage frequency sweep method, the method has the advantages that the frequency sweep time is effectively shortened, the frequency sweep efficiency is improved, an accurate frequency measurement result can be obtained more quickly, and the method is suitable for popularization and application. And the validity of the frequency value is judged by adopting a method of taking an intermediate value through sorting and calculating the data stability percentage, so that the stability and the accuracy of a measurement result are further improved.

This invention belongs to the field of oil and gas field reservoir engineering technology, specifically a method for characterizing the impact of clastic reservoir heterogeneity on reservoir efficiency. First, mineral composition, porosity and permeability, mechanical parameters, and spatial configuration of the study area are obtained. Based on the interlayer spatial configuration, flow units are divided to quantitatively evaluate the constraints of interlayers on effective reservoir space. Through creep experiments and alternating load experiments, mechanical property degradation models of different types of interlayers under long-term high pressure and injection-production cycles are established. A dynamic model of interlayer sealing capacity evolution is constructed to quantify its long-term potential to suppress vertical fluid flow. By coupling the interlayer volumetric sweep efficiency, the mechanical degradation model, and the sealing capacity evolution model, a comprehensive reservoir efficiency impact coefficient is established, enabling a quantitative evaluation of reservoir efficiency under different types of interlayer constraints. This invention elevates the impact of interlayer heterogeneity on reservoirs from a static description to a dynamic quantitative evaluation, providing a scientific basis for the site selection optimization and injection-production strategy formulation of underground reservoirs.

The invention discloses a poly-surface salt composite efficient oil displacement system with a specific in-situ emulsification behavior and application of the poly-surface salt composite efficient oil displacement system. In the oil displacement system, the concentration of an associated polymer is 1000-3000 mg / L; the concentration of the surfactant is 0.2 to 0.4 percent; the salt concentration is 1.2 to 1.8 percent; and the balance of water. The poly-surface-salt oil displacement system has the specific emulsification behaviors that high-water-content water forms a strong-emulsification high-viscosity emulsion with an oil phase, low-water-content water forms a low-viscosity weak emulsion and even is not emulsified, and the poly-surface-salt oil displacement system can be emulsified in situ with crude oil in the high-water-content water in a porous medium high-seepage channel to form a stable high-seepage-resistance emulsion; low-viscosity weak emulsion or even non-emulsion is formed in a low-permeability area under high oil content, low seepage resistance under high oil content is formed, higher heterogeneity regulation and control capability is achieved, the low-permeability sweep efficiency and the low-permeability flooding efficiency are higher, and the high and low-permeability recovery ratio is remarkably increased; intelligent in-situ emulsification profile control and displacement are expected to be realized in high-water-content and strong heterogeneous oil reservoirs; and the sweep efficiency and the oil washing efficiency are greatly improved, so that the recovery efficiency is greatly improved.

This invention discloses a method for evaluating the multiphysics coupling relationship in gas-driven oil extraction. The method includes: acquiring reservoir parameters and constructing a discrete topological space based on a graph data structure in memory; inputting the state vector into a physical information neural network surrogate model to perform phase transition dimensionality reduction calculations, outputting solid phase precipitation and viscosity fields; calculating dynamic real porosity by combining mechanical strain and chemical dissolution; generating a dynamic topology trimming operator based on percolation theory, modifying conductivity properties in the underlying memory to sever the mathematical connectivity of physical blockage zones; assembling a fully implicit Jacobian matrix based on the updated conductivity and iteratively solving it; finally, eliminating isolated dead zone volumes and generating an evaluation index containing a tensor of real sweep efficiency and phase blockage damage index. This invention eliminates the matrix singularity divergence problem, significantly improving simulation computing power and gas-driven evaluation fidelity.

The invention discloses a temperature-resistant and salt-resistant nano cross-linking agent, a preparation method and polymer gel, and the preparation method comprises the following steps: step 1, sufficiently and uniformly stirring a coupling agent and nano particles in a solvent to obtain a mixture; carrying out ultrasonic treatment on the mixture and then fully reacting to obtain modified nanoparticles; and 2, fully mixing the modified nano-particles obtained in the step 1 with a reaction monomer, fully reacting, washing, and drying to obtain the required nano cross-linking agent, the nano cross-linking agent obtained by the invention can improve the stability of polymer gel in a high-temperature environment; the salt tolerance of the polymer gel can be improved, so that the polymer gel still keeps good rheological property and structural integrity under high salinity; the method can be used for high-temperature and high-salt oil reservoirs, effectively regulate and control dominant channels of the oil reservoirs, improve the heterogeneity of oil layers, improve the sweep efficiency of low-permeability areas, improve the oil recovery efficiency of the oil reservoirs and achieve water control and oil increase of the oil reservoirs.

The invention provides a method, system, equipment and medium for injecting carbon dioxide into a horizon well section, and the method comprises the following steps: obtaining well control reserve information of a carbon injection well and an affected well, presetting a reserve limit threshold, and if the actual well control reserves of the carbon injection well and the affected well are smaller than the reserve limit threshold, adopting a collection mode of co-injection and co-production; otherwise, presetting an interlayer thickness threshold value, and obtaining the actual interlayer thickness of the carbon injection well and the effective well, if the actual interlayer thickness is smaller than the interlayer thickness threshold value, adopting a collection mode of co-injection and co-production, co-injection and separate production or separate injection and co-production, or adopting a collection mode of separate injection and separate production, otherwise, adopting a collection mode of separate injection and separate production; on the basis of the carbon dioxide miscible phase, aiming at different oil reservoir geologic characteristics, injection layer research is carried out in combination with interlayer development, the sweep efficiency can be improved to the maximum extent by utilizing the gravity-assisted flooding principle, and then the recovery efficiency is improved.

The application discloses a shale oil horizontal well volume fracturing fracture network sweep efficiency comprehensive evaluation method and device, the method comprises the following steps: obtaining shale oil horizontal well volume fracturing mine field data, and obtaining effective fracture network reconstruction volume according to the mine field data; obtaining shale oil horizontal well core data, and obtaining imbibition sweep volume according to the core data; obtaining fracture network sweep efficiency according to effective fracture network reconstruction volume, imbibition sweep volume and shale oil horizontal well volume fracturing mine field data. The application can quantitatively calculate the effective fracture network reconstruction volume of the horizontal well volume fracturing proppant, compared with the current mainstream microseismic monitoring means, the method of the application greatly saves the test cost, the calculation method is simple and feasible, the accuracy is greatly improved, and the volume fracturing reconstruction effect evaluation is effectively supported.

The present application relates to a kind of fracture water breakthrough oil well horizontal well plugging length determination method, plugging method, belong to petroleum and natural gas exploration and development technical field.The determination method includes the following steps:1) determine the main water breakthrough section of oil well horizontal well;2) predict the comprehensive water cut and water drive volume sweep efficiency of reservoir injection-production well group under different plugging schemes;Various plugging schemes are centered on the main water breakthrough section, and the plugging length proportion of well section is different;The plugging section of each plugging scheme includes the main water breakthrough section;3) the comprehensive water cut and water drive volume sweep efficiency of each plugging scheme are weighted and averaged respectively, to obtain evaluation index parameter, and then determine the plugging length of fracture oil reservoir oil well horizontal well.The method can realize the purpose of reducing water and increasing oil, reducing the invalid displacement of injected water, guiding the water plugging measures of fracture reservoir injection-production well group, improving the swept volume of fracture reservoir and effectively supplementing formation energy, and ultimately achieving the purpose of improving the development effect of fracture reservoir.

The embodiment of the invention provides a method, device and equipment for calculating the carbon burying stock of an oil reservoir, and relates to the technical field of oil and gas development and carbon burying, the method comprises the steps that the optimal development simulation scheme in multiple development simulation schemes of the oil reservoir is determined, and each development simulation scheme corresponds to one combination of multiple carbon dioxide composite steam injection parameters; obtaining development dynamic data of the oil reservoir under the optimal development simulation scheme; the development dynamic data at least comprise the sweep efficiency data of the carbon dioxide composite steam and the saturation data of the oil reservoir fluid; according to the development dynamic data, the carbon dioxide burying amount of the oil reservoir is calculated by using the multiphase carbon burying mechanism model; and the multiphase carbon burying model is coupled with the association between the oil reservoir development dynamic state and the multiphase carbon dioxide burying amount. According to the multiphase carbon burying mechanism model, the burying amount is associated with the sweep efficiency and the multiphase fluid saturation, supercomputing resources needed by all-component numerical simulation are abandoned, and low-cost and high-precision carbon dioxide burying amount calculation is achieved.

This utility model discloses an associated gas power generation tail gas reinjection system, including a gas-liquid mixer connected to a tail gas outlet pipe and a liquid-liquid mixer. The liquid-liquid mixer is connected to the bottom of an oil well produced water storage tank and an additive storage tank via pipelines. A compressor and a gas-liquid distribution mechanism are sequentially connected to the outlet of the gas-liquid mixer. The gas-liquid distribution mechanism includes a main distribution pipe connected to the compressor outlet, with multiple branch distribution pipes connected to it. The outlets of the branch distribution pipes are connected to the injection well. This utility model provides an associated gas power generation tail gas reinjection system that can utilize associated gas power generation tail gas to increase production, reduce the gas injection cost for oilfield production enhancement, and achieve synergistic reinjection of power generation tail gas and oil well produced water, thereby improving sweep efficiency.