67 results about "Saline aquifer" patented technology

The invention discloses a land sedimentary basin salt water layer carbon dioxide geological storage site selection method comprising the following steps: carrying out geological exploration in a to-be-stored area, and delineating a storage prospective area; geological exploration is carried out in the sequestration distant view area, a trap structure and geological conditions beneficial to carbon dioxide sequestration are found, and a sequestration target area is delineated through pre-exploration well drilling in combination with important mineral resource exploration development conditions and carbon dioxide sequestration and mineral resource development configuration; geological exploration is carried out in a storage target area, supplementary drilling is carried out under the conditions of shaft corrosion prevention and leakage, carbon dioxide storage and mineral resource development are configured to avoid the risk of carbon dioxide leakage caused by mineral resource development and abandoned drilling by combining important mineral resource exploration and development conditions, and a storage site is delineated; determining a carbon dioxide injection layer; and sealing site selection is completed. According to the method, a proper sealing site can be screened for large-scale safe carbon dioxide sealing for the salt water layer of the sedimentary basin, and the sealing effect is ensured.

It is hereby proposed a computer-implemented method of machine-learning a plurality of predictive basin-wise models. Each predictive basin-wise model is configured for predicting a concentration of an element at a given location in a saline aquifer of a respective basin. The machine-learning method comprises, for each basin and with respect to a predetermined set of one or more geochemical variables, providing a dataset, and learning the predictive basin-wise model based on the dataset. The dataset comprises, for respective saline aquifer locations of the basin, training samples. Each training sample includes a measurement of one or more geochemical variables of the predetermined set. Each training sample further includes a respective ground truth value. The ground truth value represents a concentration of the element at the respective saline aquifer location. Such a method forms an improved solution for analysis of a saline aquifer with respect to a given element of interest.

The invention discloses a carbon dioxide geological sequestration quantity evaluation method considering the influence of sealing performance of a cover layer. The method comprises the following steps: acquiring a structural plane and a thickness distribution map of the cover layer by utilizing a three-dimensional geological model; obtaining the change rule of the cap layer breakthrough pressure along with the depth; the hydraulic fracturing pressure of the cover rock is obtained, and a cover rock damage envelope line and the cover rock breakthrough pressure are drawn; and finally determining and obtaining the maximum allowable reservoir pressure based on the cap stratum breakthrough pressure, the reservoir and the cap stratum fracture pressure. The maximum reservoir pressure after maximum permissible carbon dioxide injection of reservoirs in different regions is utilized to obtain a regional saline water layer carbon dioxide limit sequestration amount distribution map, the limit sequestration potential of the regions is determined, and the problem that an existing carbon dioxide geological sequestration amount evaluation method does not consider the influence of the sealing performance of a cover layer is solved. The method breaks through the basic theory that the current reservoir pressure cannot exceed the overburden breakthrough pressure, provides a new thought for carbon dioxide geological storage potential evaluation, and is suitable for large-scale carbon dioxide geological utilization and storage.

Systems and methods for intensive recirculating aquaculture are provided herein. An example system includes water sourced from a first segment of a saline aquifer, a recirculating aquaculture system receiving the sourced water and producing discharge water, and a water discharge point located within a second segment of the saline aquifer disposed below the first segment of the saline aquifer.

The invention relates to a method and a device for identifying a salt water layer of a carbon dioxide sequestration geologic body. The method comprises the following steps: acquiring longitudinal and transverse wave velocity ratio volume data, fluid activity volume data and salinity volume data of a target geologic body; determining water layer characterization factor volume data according to the longitudinal and transverse wave velocity ratio volume data and the fluid activity volume data of the target geologic body; according to a preset water layer characterization factor range and a preset saline water layer mineralization degree range, target water layer characterization factor volume data and target mineralization degree volume data are selected from the water layer characterization factor volume data and the mineralization degree volume data respectively; and taking volume data formed by overlapping the target water layer characterization factor volume data and the target mineralization degree volume data as saline water layer volume data of a target geologic body, constructing a saline water layer characterization factor through logging and seismic response characteristics, optimizing a mineralization degree quantitative prediction method, realizing saline water layer quantitative characterization based on geophysical parameter prediction, and improving the saline water layer characterization efficiency. The method is used for carbon capture and storage geologic body area selection.

The invention discloses a method for characterizing changes of carbon dioxide salt water layer sealing pore permeability along with time based on a carbon dioxide-water-rock reaction. The method for characterizing the change of the carbon dioxide salt water layer sealing pore permeability along with the time based on the carbon dioxide-water-rock reaction comprises the following steps: carrying out a static CO2-water-rock reaction simulation experiment on a saturated core by adopting experimental formation water to obtain the particle sizes of suspended matters under different pressures; performing dynamic CO2-water-rock reaction experiments in the injection process under different pressures by adopting different research area stratum cores, and performing mercury injection test, porosity test and permeability test on the research area stratum cores before and after the experiments to obtain porosity and permeability change rate charts after CO2-water-rock reaction under different pressures; the long-term CO2-water-rock reaction pore permeability change is simulated through multi-field coupling of the model, and the quantification of the change of the pore permeability along with the time in the whole sealing process of injecting the carbon dioxide into the salt water layer is obtained.

The invention relates to the technical field of carbon dioxide sequestration, in particular to a saline water layer carbon dioxide sequestration evaluation and monitoring integrated method and system. Dynamic injection data are obtained, the deviation degree between the dynamic injection data and the initial injection scheme is calculated to obtain an injection pressure deviation state value, an injection rate deviation state value and a bottom hole pressure deviation state value, and then a comprehensive deviation state value is obtained; on the basis of a comparison result of the comprehensive deviation state value and an expected comprehensive deviation state value, periodic monitoring is determined according to an original plan, or deep analysis is carried out to determine an abnormal source; and adjusting the monitoring scheme and the opening degree of the injection pump or the opening degree of the flow regulating valve in real time based on the abnormal source, and inverting new data obtained according to the new monitoring scheme into the geological numerical model so as to update and correct the numerical simulation process. According to the invention, the injection scheme can be dynamically optimized based on real-time data, and the injection efficiency is improved.

The invention discloses a saline water layer CO2 geological storage salting-out quantitative evaluation device and method. The saline water layer CO2 geological storage salting-out quantitative evaluation device comprises a fluid injection system, a rock core reaction system, a confining pressure system, a back pressure system, a pulse measurement system, a drainage system and a data analysis system. The fluid injection system, the confining pressure system, the back pressure system and the liquid drainage system are respectively communicated with the rock core reaction system, and the pulse measurement system and the data analysis system are respectively and electrically connected with the rock core reaction system. According to the embodiment of the invention, the rock core reaction system provides an experiment environment, the fluid injection system provides scCO2 and saline water required by an experiment, the pulse measurement system provides a sound wave signal for a rock sample, and the data analysis system analyzes various data acquired by the experiment and obtains a saline water layer CO2 geological storage salting-out quantitative evaluation result. And a scientific basis is provided for an injection process and storage safety of geological storage of CO2.

The invention discloses a collaborative simulation device and a collaborative simulation method for saline water layer sequestration and sedimentary organic matter biotransformation, which are characterized in that a gas injection module and a bacterial liquid injection module are connected with a simulation experiment box body, and supercritical carbon dioxide and bacterial liquid are injected into corresponding layers of the simulation experiment box body; the changes of the injection amount and the taking amount are determined through a controller of the monitoring module, and the changes of the dissolution sealing and mineralization sealing amount of the supercritical carbon dioxide in the salt water layer and the mineralization sealing amount and conversion sealing amount of the supercritical carbon dioxide in the mudstone layer are displayed, compared and analyzed on the monitoring module. The simulation device can simulate the interaction among supercritical carbon dioxide, salt water and rocks, and meanwhile, by controlling the change of different injection amounts and displaying corresponding change rules according to an experimental data monitoring system, the accuracy of an experimental result is greatly improved, and the experimental efficiency is improved. The technical problem that an existing traditional device cannot accurately simulate underground high temperature, high pressure and real rock-fluid interaction conditions is effectively solved.

A method for acquiring the storage potential of a saline aquifer. The method comprises: acquiring the area of a research zone, the density of carbon dioxide under a stratum pressure, the thickness of an oil reservoir, the porosity of the oil reservoir, the irreducible water saturation of the oil reservoir, a reservoir fluid volume coefficient, a carbon dioxide storage efficiency factor, and stratum data; on the basis of the stratum data, determining estimated storage areas; on the basis of the area of the research zone and the estimated storage areas, determining a target storage area; and on the basis of said values, calculating a storage potential value of a saline aquifer in a target region. Further disclosed are an apparatus (400) for acquiring the storage potential of a saline aquifer, and an electronic device (500), a storage medium, a computer program product and a computer program.

This invention discloses a test site and method for evaluating the geological storage capacity of carbon dioxide. The test site includes a brine pool and a brine layer and caprock structure located within the pool. The caprock structure is vertically positioned below the brine layer, and a brine reservoir structure is located below it. The brine reservoir structure is connected to a brine storage tank via a simulated extraction well pipe. The brine storage tank is connected to the brine layer via a simulated injection well pipe. Carbon dioxide is injected into the brine reservoir structure via a simulated gas injection well pipe. Pressure sensors installed on the inner wall of the brine pool monitor the pressure within the brine layer and the brine reservoir structure. The carbon dioxide injection rate, brine extraction rate, and brine injection rate are adjusted based on the monitored pressure to achieve pressure balance between the brine layer and the brine reservoir structure. This invention provides a test site for evaluating the geological storage capacity of carbon dioxide under actual site conditions.

A method includes extracting natural gas from a subsurface formation including a conventional gas reservoir via a first wellbore penetrating the subsurface formation, processing the natural gas in a surface processing facility and thereby generating hydrogen and a carbon dioxide (CO2) brine, injecting at least a portion of the hydrogen into the subsurface formation via a second wellbore penetrating the subsurface formation for hydrogen storage, and injecting the CO2 brine into a saline aquifer forming part of the subsurface formation via a third wellbore penetrating the subsurface formation.

The application discloses a kind of based on dimensionless number Ca, Gr and Bo's saltwater layer CO2 storage safety evaluation method, it is related to oil reservoir and underground water numerical simulation technical field, comprising: (1) the establishment of saltwater layer CO2 storage geological model, including target reservoir, interlayer and overlying saltwater layer;(2) crack model and monitoring point are established in interlayer;(3) the geological model is initialized;(4) research CO2 leakage dynamics, calculate force and dimensionless number;(5) calculate storage safety factor;(6) change initialization condition, repeat steps (4)-(5), obtain three groups of dimensionless number and storage safety factor;(7) establish the linear regression model of storage safety factor and dimensionless number, calculate saltwater layer CO2 storage safety factor.The method of the application can adapt to various schemes under different properties reservoir, different pressure gradient, the main driving force and leakage law in the process of CO2 leakage through crack are clarified, with strong adaptability, high calculation efficiency advantage.

Systems, computer-readable storage media, and methods include receiving, from probes, petrophysical data indicative of reservoir conditions within a subterranean region. A water injectivity test executes within the subterranean region using test constants based on the petrophysical data. A water-related variable is generated by using an output of the water injectivity test. A well production potential is determined by using a nodal analysis and the output of the water injectivity test. Carbon dioxide injection rates are predicting by using a carbon dioxide estimation model. The carbon dioxide estimation model processes the water-related variables, the test constants, and a ratio of carbon dioxide density at reservoir condition to carbon dioxide density at standard conditions.

A method includes identifying a wellbore that extends from a terranean surface and to a subterranean formation that includes a saline aquifer; injecting, through the wellbore, a predetermined volume of freshwater into a portion of the saline aquifer adjacent the wellbore to create a freshwater ring about the wellbore in the subterranean formation; and subsequent to injecting the predetermined volume of freshwater, injecting a carbon dioxide fluid, through the wellbore, and into the subterranean formation for sequestration.

The application provides a deep brine layer CO2 dissolution mineralization storage potential evaluation method and device. The method comprises the following steps: calibrating the total volume of a high-temperature and high-pressure reaction kettle and pipelines connected therewith, reacting a CO2-brine-rock system, monitoring CO2 pressure and temperature in real time, calculating CO2 density before and after reaction, and evaluating CO2 dissolution mineralization storage potential. The device comprises a high-temperature and high-pressure reaction kettle, a vacuum pump, a gas buffer tank, a constant-temperature water bath box, a gas pressurizing system, a gas storage tank, a temperature and pressure monitoring system and the like. The evaluation method and device have the advantages of simple operation, safety and reliability, and convenience for practical application, can accurately evaluate the CO2 dissolution mineralization storage potential of the deep brine layer, and further support CO2 geological storage site selection and long-term storage safety evaluation, so as to promote the large-scale development of CO2 geological storage.

A method for storing a greenhouse gas in a subterranean permeable formation 40 positioned beneath a terranean surface 4 and containing a native liquid 42 includes (a) injecting a drainage fluid into t

The present invention provides a method for improving the underground energy recovery efficiency of compressed air energy storage in a saline layer, comprising finding out the deep geological conditions and properties of a target site, determining the position, structure and properties of a target gas storage saline layer, a cap rock and an underlying stratum; using numerical simulation calculations to determine the design scheme of a U-shaped working well, and selecting a U-shaped working well design scheme with high recovery efficiency, wherein the U-shaped working well comprises a U-shaped well outer well and a U-shaped well inner well, the U-shaped well outer well is provided with perforations, the U-shaped well inner well is arranged in the U-shaped well outer well, and the U-shaped well inner well and the U-shaped well outer well both extend to the underlying stratum; according to the selected U-shaped well design scheme, drilling and completion construction of the site are carried out; devices of a surface energy storage system are arranged to form a complete energy storage system; and air is injected or produced. The present invention realizes that the air obtains excess underground supplementary heat to increase the outlet temperature of the air at the wellhead while ensuring that the circulating pressure remains unchanged, thereby increasing the underground energy recovery efficiency.

This invention belongs to the field of carbon dioxide geological storage engineering. It proposes a method for selecting the monitoring location of deformation in fractured saline aquifers used for CO2 storage. The method includes: constructing a thermo-fluid-mechanical multi-field coupled model; building an initial reservoir model based on the target area for CO2 storage, and setting initial and boundary conditions for the initial reservoir model; constructing a discrete fracture network model using a random fracture generation function and setting fracture attributes, adding the fracture attributes to the initial reservoir model, and then meshing the initial reservoir model with added fracture attributes to obtain a fractured reservoir model; inputting the fractured reservoir model into the thermo-fluid-mechanical multi-field coupled model to obtain the formation deformation results over time in different grid regions of the fractured reservoir model, and selecting the grid region with the largest surface deformation as the monitoring location. This invention can select the optimal monitoring location without real-time on-site detection, making it easier to monitor safety issues in carbon dioxide geological storage.

The invention relates to the technical field of oil exploitation, and discloses a compound microbial agent as well as a preparation method and application thereof. The compound microbial agent contains methanogens and bacillus. The methanogens are selected from at least one of methanosarcina martensii, methanobacterium formate and methanobacterium thermophilus; the bacillus is selected from at least one of bacillus megatherium, bacillus cereus and bacillus subtilis; the number of viable bacteria of the methanogens in the compound microbial agent is 1 * 10 < 6 > CFU / mL to 1 * 10 < 9 > CFU / mL; the number of viable bacteria of the bacillus in the compound microbial agent is 5 * 10 < 5 > CFU / mL to 5 * 10 < 8 > CFU / mL. The composite microbial agent has excellent carbon sequestration performance, and is suitable for depleted oil and gas reservoirs, deep saline water layers and other geological sequestration scenes.

The application discloses a method for determining the distribution range of a closed brine formation capable of storing CO2 underground, comprising the following steps: determining the development horizon and thickness of the brine formation according to drilling data; determining the planar distribution range of the brine formation capable of storing CO2 according to the development horizon and thickness in combination with seismic data; determining the distribution range of the open brine formation capable of exchanging with surface water in the denudation area; determining the distribution range of the open brine formation capable of exchanging with surface water in the central fault development area of the basin; and subtracting the distribution range of the two open brine formations from the planar distribution range of the brine formation capable of storing CO2 to obtain the distribution range of the closed brine formation. The method has the beneficial effect that the planar distribution range of the brine formation is determined first, then the interference range is removed, and finally the distribution range of the brine formation capable of storing CO2 is obtained, thereby providing a quick solution for determining the target area of the brine formation when carrying out the CO2 geological storage research in the sedimentary basin, and improving the work efficiency.

The invention provides a method for analyzing formation conditions of a high-pressure brine layer, which relates to the technical field of well drilling and comprises the following steps of: analyzing a relationship between a well drilling track and a fault zone according to a vertical section of an earthquake coherence body, and determining a migration channel for development of the brine layer; analyzing a local structural form and a combination mode of the migration channel by using a seismic coherent body horizontal slice, and determining a crack dense zone; and in combination with the seismic diffracted wave slice and the seismic coherent body horizontal slice, determining a spatial configuration relationship between the fracture dense zone and the migration channel to obtain a salt water layer prediction result. According to the method, by analyzing the vertical communication condition with deep formation water, the local fracture development condition near the fracture zone and the micro-fracture dense zone and fault configuration condition, the problems of a saline migration channel, a fracture development part and the configuration relation between the micro-fracture dense zone and the channel are solved in sequence; the purpose of predicting brine layer distribution based on new knowledge formed by the high-pressure brine layer is achieved.

The invention discloses a freeze crystallisation and separation method including arrangement therefore which includes the steps of selective temperature regulation to foster the growth of water ice and salt crystals, segregated by their density and wherein ice crystals float, while salt / mineral crystals sink after mixed slurry was deposited at the lower end of the tank and internal filtration pipes places to filter brine and Low TDS (total dissolved solids) water preventing crystals entering the flow; and of multi-function tank (MFT) separation incorporating a heat recovery mechanism using compressor discharge gas to melt the ice, optimising energy efficiency and reducing overall power consumption. Inlet brine flow is controlled by measurement of Low TDS water extraction quality to control the Low TDS water floating level and subsequent brine layers. The outlet brine or concentrate and solid slurry discharge is controlled based on the fraction of the Low TDS water outlet volume.

The application discloses a kind of implementation dissolution-precipitation dynamic coupling's saline aquifer CO2 mineralization storage pore scale numerical simulation method, comprising: constructing geometric model under pore scale;The flow velocity distribution and pressure distribution of geometric model in time and space are calculated;Reaction migration model of the CO2 mineralization storage of saline aquifer is constructed;Kinetics reaction rate equation and porosity dynamic evolution equation are established, ion product-solubility product judgment statement is introduced, the reaction migration model is solved, and CO2 deep saline aquifer mineralization storage reaction migration numerical simulation is completed.The application is coupled by DBS equation and ADE equation, realizes the solution reaction migration numerical simulation under pore scale, simplifies the complex reaction migration numerical simulation solving process;In the process of solving reaction migration, dissolution and precipitation process are coupled simultaneously, more close to real situation;It is suitable for operation under a variety of working conditions, extracts solute transport and dissolution-precipitation rule under different conditions, and provides support for experimental research.

A method includes identifying a wellbore that extends from a terranean surface and to a subterranean formation that includes a saline aquifer; injecting, through the wellbore, a predetermined volume of freshwater into a portion of the saline aquifer adjacent the wellbore to create a freshwater ring about the wellbore in the subterranean formation; and subsequent to injecting the predetermined volume of freshwater, injecting a carbon dioxide fluid, through the wellbore, and into the subterranean formation for sequestration.

The invention discloses a heat supply, energy storage and saline water layer CO2 storage combined system for a thermal power plant, and relates to the technical field of energy utilization, in a non-heating season, CO2 is adopted to recover condensation heat of the power plant, intermittent air exhaust is utilized to cope with load change caused by peak regulation and frequency modulation, meanwhile, the CO2 is heated by air exhaust, and the CO2 carrying heat energy is filled into a saline water layer to realize energy storage and geological storage; in the heating season, the thermal power plant exhausts air for heating, and meanwhile the salt water layer releases hot CO2 for heating. CO2 used for energy storage and saline water layer storage is captured from exhaust smoke of a power plant. According to the system, efficient combination of power plant heat energy recycling, salt water layer energy storage and CO2 salt water layer storage is achieved, more importantly, intermittent air exhaust in the non-heating season well deals with peak and frequency regulation load changes of the power plant, and the system is a high-valued operation mode.

The invention provides a saline water layer carbon dioxide structure burying potential determination method and system. The determination method comprises the steps that S1, the effective capillary radius considering the slippage effect and the bound water film thickness is calculated; s2, calculating salt water layer parameters according to the effective capillary radius; and S3, calculating the carbon dioxide structure burying amount of the saline water layer according to the parameters of the saline water layer. By considering the breakthrough pressure and the comprehensive compression coefficient of the salt water layer cover layer and combining the density of carbon dioxide under different temperature and pressure conditions, the accurate calculation of the carbon dioxide structure burying amount of the salt water layer is realized under the condition that the cover layer leakage does not occur.

This invention discloses a device and method for quantitatively assessing CO2 sequestration and salt precipitation in saline aquifers. The device comprises a fluid injection system, a core reaction system, a confining pressure system, a back pressure system, a pulse measurement system, a drainage system, and a data analysis system. The fluid injection system, confining pressure system, back pressure system, and drainage system are all connected to the core reaction system. The pulse measurement system and the data analysis system are electrically connected to the core reaction system. In this embodiment, the core reaction system provides the experimental environment, the fluid injection system provides the required scCO2 and brine, the pulse measurement system provides acoustic signals to the rock sample, and the data analysis system analyzes the collected data to obtain the quantitative assessment results of CO2 sequestration and salt precipitation in saline aquifers, providing a scientific basis for the injection process and sequestration safety of CO2 geological sequestration.

Techniques for simulating carbon dioxide injection into a saline aquifer. The techniques include obtaining geological reference data and establishing carbon dioxide injection parameters. With this data and parameters in mind, a node-based resistance grid may be established that is used to schematically generate flowlines across the saline aquifer. From the flowlines, tessellated partitions may be developed and potentially subdivided into manageable platonic shape portions. Thus, a mathematical manner of estimating flow characteristics for the proposed injection application may be simulated in a fast and reliable manner.

The invention provides a salt water layer carbon dioxide migration range prediction method and device and computer equipment, and relates to the technical field of carbon dioxide geological storage. The method comprises the following steps: simulating a carbon dioxide injection process by using a numerical simulation model; calculating carbon dioxide density distribution by utilizing formation pressure data of the sequestration area; according to the gravity abnormal data of the storage region, the carbon dioxide density distribution and the migration range of the carbon dioxide in the tectonic trap region, determining the proportion of the mass variation, caused by pore constraint, of the carbon dioxide in the migration range of the tectonic trap region in the total mass variation of the carbon dioxide in the migration range of the tectonic trap region; determining the proportion as a first coefficient; and calculating the actual carbon dioxide overflow regional area according to the first coefficient. According to the method, the gravity abnormal data and the ground pressure monitoring data are combined for joint inversion, and low-cost, high-efficiency and high-precision prediction of the carbon dioxide migration range is achieved.