23 results about "Pore fluid" patented technology

The invention provides a sodium ion specific fluorescence labeled transparent soil sample as well as a preparation method and application thereof, and belongs to the technical field of rock soil and geological engineering. The method comprises the following steps: firstly, sequentially carrying out hydrophilization treatment, solvent evaporation and dissolution on a sodion combined benzofuran isophthalate probe to obtain a probe mother solution; mixing the probe mother solution, a buffer solution, an inorganic sodium salt solution and a solvent to prepare a fluorescence labeling pore solution; and finally, mixing the sodium polyacrylate particles and the fluorescence labeled pore liquid, and performing vacuum saturation treatment to obtain the transparent soil sample. The transparent soil sample provided by the invention still keeps excellent optical transparency while having sodium ion specific response capability, so that a stable and reliable experimental medium is provided for in-situ, real-time and full-field observation of sodium ion migration.

The invention belongs to the technical field of mineral calculation and reservoir evaluation, and particularly discloses an electric imaging logging mineral component quantitative characterization method based on porosity spectrum correction, which comprises the following steps: preprocessing original electric imaging logging data, and generating a high-density pixel image; performing probability density statistical analysis on the pixel value of each depth point in the high-density pixel image to obtain a pixel waveform spectrum; calculating the apparent porosity of each pixel point in the high-density pixel image to generate a pore spectrum; performing pore fluid influence correction on the original electrical imaging data based on the pore spectrum, performing image enhancement to generate a pure mineral pixel waveform spectrum, and performing equalization processing to obtain an imaging mineral probability map; according to mineral content data obtained through core XRD total rock analysis, an imaging mineral spectrum is subjected to quantitative calibration, and distribution cut-off threshold values and pixel point value ranges corresponding to different minerals are recognized and deduced. The method can effectively solve the calculation error caused by the influence of the traditional imaging mineral calculation fluid on mineral calculation.

The invention discloses an organic matter identification method based on seismic wave dispersion, and relates to the technical field of petroleum geophysical exploration, and the method comprises the steps: obtaining a target pre-stack seismic trace set and matched logging data, building an underground medium initial model based on the kerogen content and elastic response characteristics in the logging data, and obtaining an underground medium initial model; a to-be-inverted parameter matrix and a reflection coefficient weight matrix of an incident angle are calculated through a Shaw reflection coefficient calculation equation, frequency-division seismic wavelets are generated through the high sensitivity of organic matter to transverse wave dispersion, and a positive operator is constructed in combination with the wavelets and the reflection weight matrix. A shear wave velocity dispersion gradient which is highly sensitive to organic matters and weak in response to pore fluid is used as a main control inversion parameter, a combined recognition constraint term is constructed by combining a longitudinal wave velocity dispersion gradient and attenuation spectrum morphological characteristics, and a spatial optimal solution of a forward operator and a seismic trace set is calculated through a minimization objective function. And quantitatively associating the spatial optimal solution with the geophysical response characteristics of the organic matters to generate an organic matter spatial distribution diagram of the target reservoir.

This invention relates to the field of experimental equipment technology, and particularly to an NMR combustion-explosion dynamic load multi-field coupling experimental device and method. The technical solution includes a control module, an impact module, a detection module, and a vibration reduction module; wherein, the control module includes an operating platform, a transmission line, an engine, a fuel tank, an oxygen tank, connecting pipes, a high-temperature resistant fuel nozzle, and a high-temperature and pressure resistant gas sealing pipe; the operating platform is located behind the engine. This invention achieves graded control of dynamic load through combustion-explosion-electromagnetic composite loading, integrates simultaneous detection of multiple physical fields such as nuclear magnetic resonance, acoustic waves, and resistivity, sets up multi-level vibration reduction and dissipation structures to absorb residual kinetic energy, adopts a high-temperature and high-pressure resistant sealing design to ensure safety, simulates ground temperature, ground stress, and pore fluid fields to reproduce the deep in-situ multi-field coupling environment, and is centrally controlled and automatically reset by the operating platform, thereby realizing a laboratory simulation of deep dynamic disasters with flexible and adjustable parameters.

This invention proposes a corrosion-inhibiting polycarboxylate superplasticizer, its preparation method, and its application. The corrosion-inhibiting polycarboxylate superplasticizer is prepared by a ring-opening grafting reaction between an epoxy-containing polycarboxylate superplasticizer and triethanolamine borate. A functionalized framework is constructed using epoxy-containing monomers, and then corrosion-inhibiting groups are stably anchored to the molecular side chains through a nucleophilic ring-opening reaction, achieving molecular-level integration of water-reducing and corrosion-inhibiting functions. Through the directional adsorption of amino groups onto the surface of reinforcing steel to form a film, combined with the anodic passivation inhibition induced by borate, corrosive media are effectively isolated. Simultaneously, the released borate ions react with calcium ions in the pore fluid to form micro-precipitates in situ, filling capillary pores and significantly optimizing pore size distribution. This invention solves the problems of poor component compatibility and performance interference, significantly reducing the chloride ion permeability coefficient even at low dosages, and significantly improving the mechanical strength and durability of concrete. The process of this invention is simple, the reaction conditions are mild, and it is suitable for the protection of reinforced concrete structures in marine engineering and harsh environments.

The application discloses a kind of suitable for deep brackish aquifer seismic reflection wave response high fidelity simulation calculation method, the method includes S10: according to brackish aquifer development characteristics, establish brackish aquifer pore fluid rock physics model, calculate the viscosity, density, longitudinal wave velocity and bulk modulus of brackish aquifer pore fluid;S20: according to brackish aquifer development characteristics, establish brackish aquifer multi-scale rock physics model, obtain brackish aquifer equivalent stiffness matrix;S30: establish geology-seismic forward modeling;S40: utilize propagation matrix method to calculate brackish aquifer reflection and transmission coefficient matrix;S50: calculate brackish aquifer reflection wave seismic response.The application combines seismic rock physics modeling and seismic forward simulation technology, considers the viscoelasticity characteristics and thickness of brackish aquifer, is more in line with actual geological conditions, low in cost, high in accuracy, can quickly and accurately calculate deep brackish aquifer seismic reflection wave response, provides theoretical support for the evaluation and optimization of carbon storage space.

The invention relates to a core pore fluid component identification and quantitative analysis method based on two-dimensional nuclear magnetic resonance, and belongs to the technical field of core analysis. The method comprises the following steps: acquiring core two-dimensional nuclear magnetic resonance spectrogram data; constructing a relaxation time matrix and a signal intensity matrix; calculating a relaxation time ratio matrix; based on a transverse relaxation time boundary and a ratio boundary, mapping the signal to nine fluid components such as clay bound water and adsorbed oil through a classification function; and quantizing the signal intensity of each component by using a Kronecker function, and finally calculating the relative content of each component. According to the method, fluid relaxation characteristic distribution of the T-Tspectrogram is covered by a seamlessly connected polygonal region, so that a signal blind area of a circular plate is eliminated, in-situ quantitative analysis of multi-component fluid in full-scale pores is realized, and high-precision data support is provided for oil and gas reservoir evaluation and development scheme formulation.

This invention discloses a nuclear magnetic resonance (NMR) method for measuring the solid phase deposition of crude oil in porous media, belonging to the field of oil and gas reservoir development technology. By using a single saturation of crude oil in a core sample and leveraging the characteristics of online NMR technology, the method employs a comparison of experimental and NMR measurements, along with a 1:1 standard line reference, to determine the standard echo interval T in the transverse relaxation time T2 measurement acquisition parameters. E This method directly measures the amount of solid phase deposition in pore fluids in situ, solving the technical problems of existing technologies that cannot maintain the original characteristics of the sample, effectively avoid the interference of solid skeleton response and solid phase deposition particles, and are difficult to measure the solid phase deposition content of active oil in situ. It achieves the technical effect of rapid, efficient and accurate measurement of the amount of crude oil solid phase precipitation in cores under specific temperature and pressure conditions. The method is reliable in principle, simple to operate and highly applicable, and the test results are accurate and reliable, making it more suitable for the fine characterization needs of complex oil and gas reservoirs.

The application provides a carbonate fault opening and closing evaluation method based on mechanical analysis, and the evaluation method comprises the following steps: S1, obtaining interpretation results of a target layer and a fault; S2, obtaining a plane distribution map and occurrence information of the fault; S3, obtaining compression stress F y suffered in a vertical fault plane direction; S4, calculating the compression resistance F f of pore fluid in a fault rock fracture; and S5, calculating a fault sealing factor R. The carbonate fault section stress is quantitatively obtained, so that an evaluation index for fault opening and closing evaluation is provided, a more effective basis for carbonate rock oil and gas reservoir exploration evaluation is provided, and the analysis and research on the carbonate rock reservoir accumulation rule are facilitated, so that the drilling success rate is improved and the exploration risk is reduced.

The application discloses a deep high-temperature high-pressure dry hot rock seismic rock physics modeling method and system, relates to the field of seismic exploration, determines the mineral composition and content of the dry hot rock matrix, and calculates the elastic modulus of the dry hot rock matrix; the differential equivalent medium model is adopted to calculate the elastic modulus of the dry hot rock skeleton containing hard pores; the volume modulus of the rock skeleton of a rock sample under different pressure conditions is tested, and the effective pressure constant is estimated; based on the pore space stiffness theory, the elastic modulus of the dry hot rock skeleton containing cracks affected by pressure is calculated; the volume modulus of the pore fluid affected by temperature and pressure is calculated; and the elastic modulus and density of the dry hot rock containing fluid are calculated. The application quantitatively constructs the analytical relationship between the temperature and pressure conditions and the elastic response and the crack content, provides a theoretical model basis for seismic prediction of the physical property parameters of the dry hot rock reservoir, can significantly improve the seismic prediction precision and resource evaluation efficiency of the dry hot rock reservoir, and provides technical support for the exploration and development of the dry hot rock geothermal resources.

The application discloses a shale pore fluid saturation, fluidity and pore wettability measurement method, relates to the technical field of shale oil exploration, and comprises the following steps: obtaining a shale oil sample to be measured, and obtaining a pre-extraction nuclear magnetic resonance spectrum of the shale oil sample to be measured; performing a preset extraction operation on the shale oil sample to be measured to obtain an extracted shale oil sample and a corresponding post-extraction nuclear magnetic resonance spectrum; determining a T1 / T2 change rate of a relaxation peak peak value based on the two nuclear magnetic resonance spectra; determining a hydrogen component of the shale oil sample before and after extraction based on the T1 / T2 change rate, determining a target saturation based on the hydrogen component and a preset saturation calculation method; and determining the fluidity and wettability of the sample based on the target saturation, the T1 / T2 change rate and a preset property measurement method. The application utilizes a theoretical relationship between the calculated T1 / T2 change rate and the saturation of the obtained sample, obtains the fluidity and pore wettability of the sample, losslessly quantitatively represents various rock physical properties of shale, and improves the comprehensiveness and accuracy of the measurement result.

This invention relates to a method and system for judging the fluid preservation effect of sealed frozen cored samples based on nuclear magnetic resonance resaturation comparison, belonging to the field of unconventional oil and gas exploration and development technology. The method includes: First, acquiring and processing sealed samples, performing a first T1-T2 two-dimensional nuclear magnetic resonance test after thawing, followed immediately by resaturation treatment, and then immediately performing a second test after saturation; Second, dividing the fluid into regions and extracting signals for each hydrogen-containing component; Third, calibrating the formation water, crude oil, and dodecane, establishing the conversion relationship between oil-water hydrogen signals and volume, and then calculating the oil-water volume in the sealed and resaturated states; Fourth, comparing the difference between the total fluid volume in the resaturated state and the total fluid volume in the sealed state with the total fluid volume in the resaturated state, and defining the ratio as the resaturation response coefficient, used to quantitatively evaluate the preservation degree of the original pore fluid. This invention ensures the accuracy and reliability of the test results.

Disclosed in the present disclosure are a rock physics modeling method and apparatus based on pore fluid filling. The method comprises: on the basis of elastic information of a mixed mineral matrix, constructing a mixed mineral matrix model; using a differential effective medium method to obtain a mixed mineral matrix containing a pore-saturating fluid, and constructing a mixed mineral rock model containing the pore-saturating fluid; using the differential effective medium method to obtain a mixed mineral matrix containing the pore-saturating fluid and a microfracture-saturating fluid, and constructing a mixed mineral rock model containing the pore-saturating fluid and the microfracture-saturating fluid; adding a fracture-saturating fluid to the mixed mineral matrix containing the pore-saturating fluid and the microfracture-saturating fluid, and calculating corresponding rock elastic characteristics; and obtaining a rock physics model on the basis of the rock elastic characteristics. The present disclosure can overcome difficulties in common rock physics modeling caused by the diversity of pore types.

This application belongs to the field of reservoir logging evaluation technology, and discloses a method, system and equipment for calculating reservoir water saturation. The method includes obtaining the formation P-wave velocity V0. p and transverse wave velocity V s Based on the longitudinal wave velocity V p and transverse wave velocity V s Calculate the bulk modulus K and shear modulus μ of saturated fluid rock; calculate the bulk modulus K of the rock skeleton of saturated fluid rock. m and shear modulus μ m ; Calculate the bulk modulus K of saturated fluid rock without fluid. d and shear modulus μ d Based on K, K m and K d Calculate the bulk modulus K of pore fluid in saturated fluid rocks. f Based on K f A water saturation model is constructed to achieve quantitative calculation of reservoir water saturation. The method in this application considers the different mineral contents and matrix porosity variations in the reservoir, achieving high calculation accuracy and providing a new approach for the quantitative evaluation of water saturation in complex reservoirs with low resistivity and low contrast.

According to the hydrate-containing stratum velocity and attenuation characteristic analysis and model construction method, device and equipment and the storage medium provided by the embodiment of the invention, the influence of the hydrate on elastic parameters, permeability and fluid viscosity coefficients of a rock solid phase and a skeleton is particularly considered, and the depicting precision of the model on an actual hydrate reservoir is improved; according to the method, the relationship between hydrate mineral components, pore fluids and microstructures and the seismic macroscopic velocity and attenuation attributes is established, the seismic attributes of hydrate reservoirs such as different saturability, porosity and lithology can be analyzed, and the method has certain guiding significance for hydrate saturability estimation and occurrence type judgment by utilizing the velocity and attenuation attributes. And on the basis of the modeling method, diverse and practical hydrate models can be constructed, the method can be used for research such as seismic wave forward modeling and imaging of hydrate reservoirs, and a large amount of sample data can be provided for artificial intelligence seismic parameter inversion.

The application discloses a method and device for constructing a formation pore pressure prediction model and a storage medium. The method comprises the following steps: obtaining a target layer pressure structure, core mineral components and pore structure characteristics of a carbonate rock; optimizing an Xu-Payne model according to the target layer pressure structure, the core mineral components and the pore structure characteristics to obtain an optimized Xu-Payne model; determining a bulk modulus of a carbonate rock matrix, a bulk modulus of a rock skeleton and an equivalent bulk modulus of a pore fluid based on the optimized Xu-Payne model; determining a bulk modulus of a saturated rock according to the bulk modulus of the carbonate rock matrix, the bulk modulus of the rock skeleton and the equivalent bulk modulus of the pore fluid; and constructing a formation pore pressure prediction model based on the bulk modulus of the saturated rock. The application can construct a formation pore pressure prediction model suitable for the carbonate rock, thereby improving the accuracy of predicting the formation pore pressure of the carbonate rock.

This invention discloses a unified modeling method for controlled seismic sources and near-surface surfaces based on GLS, relating to the fields of geophysical exploration and controlled seismic sources. It constructs a near-surface porosity-elastic model, improving the simulation accuracy of the interaction between the weight, the base plate, and the pore fluid. The method uses a generalized coordinate system primarily composed of the displacement and velocity of the weight, the ground, and the fluid. Under GLS theory, it establishes an energy structure function constrained by a swept-frequency signal. Substituting this into the Euler-Lagrange equations, it derives dynamic equations considering the characteristics of the near-surface pore structure. Then, the Newmark-Beta method is used to solve the equations to complete simulation experiments of the input and output signals of the controlled seismic source. The model of this invention fully considers the characteristics of the near-surface pore structure and its vibration energy attenuation mechanism, significantly improving the modeling capability of existing controlled seismic source systems for the response of porous media. Its parameter matrix clearly characterizes the mass, stiffness, and damping coupling relationships of the weight, the base plate, the ground skeleton, and the pore fluid.

The present application relates to the technical field of soil monitoring, in particular to a soil real-time sampling detection method for saline-alkali soil treatment, comprising the following steps: obtaining a mechanical compression distribution model by constructing a resistance and crust strength boundary, extracting an impedance coefficient, performing probe penetration matching to quantify deep hydrostatic pressure load, introducing a driving negative pressure and filter membrane hydraulic property differential pressure comparison, positioning a basement expansion origin, setting a soil background interference boundary to extract a charge factor, and obtaining a saline-alkali soil in-situ pH adaptive correction detection value. In the present application, the breaking boundary is extracted by fusing the probe resistance model, the matching accuracy of the in-situ sampling depth is effectively improved, the static water pressure quantitative analysis efficiency is strengthened, the suction flow rate is generated under different pressure difference states, the in-situ pore fluid lossless extraction is optimized, the vertical span is evaluated to enhance the stability of the gel hydration volume determination, the salinity interference boundary is set to extract the migration factor, and the correction ability of the in-situ pH detection value is established.

The invention discloses a fine particle migration numerical simulation method based on a discrete element pore density flow method, which comprises the following steps of: 1) constructing a discrete element accumulation model and a pore network: establishing a three-dimensional gap grading accumulation model based on discrete elements, and dividing particles into coarse particles and fine particles; coarse particles are used as a skeleton structure; 2) calculating pore seepage, namely establishing a function relationship among pressure, density and temperature of fluid in pores according to a fluid state equation, and calculating seepage rate and flow among the pores; 3) fine particle stress and pore parameter calculation: calculating the stress according to the average flow velocity of the pores where the fine particles are located; 4) fluid-structure interaction modeling: the coarse particles and the fine particles interact through contact force, and pore fluid applies hydrostatic pressure to the coarse particles and applies drag force to the fine particles; the coarse particles and the fine particles displace under the action of resultant force; and 5) iterative solution and simulation operation: realizing the whole-process dynamic state of fine particle migration, blockage and seepage evolution under the three-dimensional discrete element fluid-solid coupling framework.

This invention discloses a foamed concrete material for artificial reefs and its preparation method, belonging to the technical field of marine engineering building materials. It uses silicate cement, slag powder, fly ash, and metakaolin as the cementing system, compounded with a grafted dynamic alkalinity regulator, an amphiphilic polymerizable precursor, and ecologically cascaded inducing microcapsules. The precursor forms an organic-inorganic interpenetrating network in situ at the gas-liquid interface to reinforce the pore walls; the alkalinity regulator stabilizes the pore fluid pH for a long time through a two-site buffer; and the microcapsules achieve a gradual release of nutrients through a multi-level gated structure. This material exhibits a compressive strength of 5.4-5.8 MPa at high porosity, low water absorption, a stable pore fluid alkalinity reduction to the weakly alkaline range, slow nutrient release without sudden release, and high benthic diatom attachment. It combines good mechanical durability with ecological compatibility and can be used in marine ranching artificial reef engineering.

The embodiment of the invention discloses a parameter monitoring method and device for rock debris while drilling, equipment and a medium. The method comprises the following steps: for rock debris while drilling, determining mineral components of a rock matrix according to a chart established according to lithology of the rock debris while drilling, and determining effective elastic parameters of the rock matrix according to the mineral components of the rock matrix; establishing a differential equivalent medium model of a rock skeleton according to the mineral components of the rock matrix, and calculating effective elastic parameters of the rock skeleton based on the differential equivalent medium model; according to the effective elastic parameters of the rock matrix, the effective elastic parameters of the rock skeleton and the fluid parameters of the pore fluid, the drillability grade value and the compressive strength of the stratum are determined. According to the scheme, the stratum rock mechanical parameters can be determined in real time according to the rock debris while drilling, the data timeliness is improved, and scientific data support is provided for drilling engineering.

This invention relates to the interdisciplinary field of natural gas hydrate resource exploration and development and digital rock physics, and discloses a conditionally generated digital core construction method for hydrates. The method includes the following steps: performing three-phase segmentation on CT images of hydrate-bearing sediments to obtain labeled data for the skeleton, pore fluid, and hydrates; identifying and labeling the microscopic occurrence types of hydrates based on the spatial characteristics of hydrate clusters and the skeleton, constructing a labeled dataset containing type labels and measured saturation; extracting the microscopic spatial distribution characteristics of hydrates through an encoder to establish a feature database; training to obtain a saturation-type mapping function, constructing a conditional generative adversarial network, and using the target saturation and feature vector as conditional inputs. After training, inputting the target saturation can generate a three-dimensional digital core of hydrates. This invention provides a conditionally generated digital core construction method for hydrates, which can solve the long-standing problem of the disconnect between hydrate characterization and hydrate sediment modeling.

This invention discloses a rapid static and dynamic mixing method for transparent sand pore fluid based on real-time temperature feedback, belonging to the field of geotechnical engineering physical model testing technology. This invention uses an improved transparent soil model box, which consists of a base plate, a transparent box body, and a nozzle. The method includes the following steps: a static mixing step, comprising: A1: obtaining the test environment temperature; A2: calculating the optimal component ratio that matches the refractive index of the pore fluid with the refractive index of the transparent aggregate based on a pre-constructed empirical formula relating the pore fluid refractive index to temperature and component ratio; A3: weighing the component materials according to the optimal ratio and mixing them uniformly to obtain the pore fluid. The advantages are: this invention overcomes the shortcomings of traditional transparent sand preparation methods that rely on repeated trial mixing and cannot adapt to changes in environmental temperature, achieving rapid and accurate mixing of transparent sand at specific temperatures or in variable temperature environments, effectively improving the effective resolution of laser speckle and the measurement accuracy of the displacement field during the test.