180 results about "Formation water" patented technology

The invention provides a dynamic visual simulation system and method for carbon dioxide formation water reaction precipitation, and belongs to the technical field of geological sequestration. The dynamic visual simulation system and method for the carbon dioxide formation water reaction precipitation comprise a microcosmic etching chip model; a piston container; the pressure-making injection system is connected with the piston container; a carbon dioxide liquefaction module; the carbon dioxide quantitative injection system is connected with the carbon dioxide liquefaction module; the supercritical generator is connected to the downstream of the carbon dioxide quantitative injection system; a microscopic etching chip model is arranged in the visual reaction kettle, and the visual reaction kettle is connected with the supercritical generator; the back pressure loading system is connected to the outlet end of the visual reaction kettle; the microscopic image visual acquisition module is arranged above the visual reaction kettle; an annular pressure tracking pump; the control terminal computer is connected with all the modules, and the problems that the influence rule of sediment on reservoir seepage in carbon dioxide geological sequestration is unclear, and sequestration risks are difficult to predict are solved.

The invention relates to a surfactant oil displacement composition suitable for a high-temperature and high-salt oil reservoir and application of the surfactant oil displacement composition. The surfactant oil displacement composition comprises the following components in percentage by mass: 0.10-0.50 wt% of a nitrogen-containing surfactant, less than 0.12 wt% of a sulfur-containing surfactant or hydrophobic salt and the balance of water. The surfactant oil displacement composition stably exists under the conditions that the temperature is 70-130 DEG C, the total mineralization degree of formation water is (10-25) * 10 < 4 > mg / L, and the concentration of calcium and magnesium ions is (1-2.5) * 10 < 4 > mg / L, and is kept clear without forming precipitates. The interfacial tension of the surfactant oil displacement composition can reach 10 <-2 > mN / m order of magnitude under high-temperature and high-salt conditions, the oil washing efficiency can reach 80% or above, and the surfactant oil displacement composition is suitable for improving the recovery efficiency of a high-temperature and high-salt oil reservoir in tertiary oil recovery.

The invention discloses a method for analyzing diagenesis of clay minerals by combining physical simulation and numerical simulation, which comprises the following steps: selecting clay single minerals, and preparing a formation water solution; respectively filling the clay single mineral and the stratum water solution into a plurality of reaction kettles, and carrying out diagenesis physical simulation; establishing a numerical simulation model with the same physical simulation experiment condition, and outputting mineral and ion data; according to mineral and ion data, fitting a physical simulation experiment result and a numerical simulation result, and determining a mineral corrosion rate; and establishing a geologic model by taking the mineral dissolution rate as a reference, and performing clay single mineral diagenesis simulation within a geological time scale. According to the method, numerical simulation parameters are constrained by physical simulation experiment results, and comparison and verification of numerical simulation and physical simulation results are realized by adjusting mineral corrosion kinetic parameters in real time, so that the numerical simulation experiment results are close to actual conditions.

The invention discloses a grouting splitting pressure simulation device under high-ground and high-water-pressure conditions, and relates to the technical field of tunnel and underground engineering model tests. A first water permeable unit controlled by the water injection unit and a second water permeable unit controlled by the confining pressure unit are respectively arranged at two ends in the length direction, so that water pressure and stratum confining pressure are independently applied. The integrated grouting unit of the device is used for grouting soil in the box and is provided with a comprehensive detection unit, the comprehensive detection unit monitors various parameters such as grouting pressure, water pressure, confining pressure, flow, soil resistance and wave velocity in real time, and independent loading and accurate dynamic control of the grouting pressure, formation water pressure and formation stress can be achieved; therefore, the grouting process of the deep-buried tunnel under the conditions of different burial depths, high water head differences and complex grout characteristics can be simulated in a laboratory with high precision, and the technical bottleneck that the complex environment of high ground stress and high water pressure coupling is difficult to reproduce in a traditional test method is effectively solved.

A system may include a lower completion disposed in a main bore of a multilateral well in a position downhole from a junction of the multilateral well. The system may also include a fluid separator configured to receive formation fluid, which includes oil and water, flowing from the lower completion. The fluid separator may be configured to at least partially separate the formation fluid into formation oil and formation water. The fluid separator may also be configured to output the formation oil, via a separator oil outlet, to flow uphole, and output the formation water, via a separator water outlet, to flow toward a lateral bore of the multilateral well. Further, the system may include a water cut sensor disposed uphole from the fluid separator. The water cut sensor may be configured to measure the percentage of water in the formation oil.

The invention relates to the technical field of shale exploitation, and discloses a shale reservoir wettability dynamic determination method, which comprises: S1, selecting a shale plunger core, carrying out supercritical CO2 cleaning and vacuum drying, and carrying out high pressure saturation by using simulated crude oil to obtain an initial oil saturation; and S2, the saturated rock core is loaded into a high-temperature and high-pressure rock core holder, and under the simulated formation temperature and pressure condition, simulated formation water containing the paramagnetic contrast agent is injected at the constant flow speed for displacement till the water content of the outlet end reaches 98%. According to the invention, dynamic and three-dimensional space representation of wettability is realized: three modal data of nuclear magnetic resonance, resistivity and sound wave are synchronously acquired in the displacement process, so that the limitation of a traditional static method is overcome, and the dynamic process of the wettability changing along with the fluid saturation state can be captured in real time; and finally, a high-resolution three-dimensional wettability distribution map is generated, and non-uniform distribution of wettability in the core is visually revealed.

A method for passively producing hydrogen from a geological formation includes drilling a plurality of lateral wellbores into an iron-rich geological formation from a mother wellbore extending from a surface location. Each of the plurality of lateral wellbores has an inclination along its length of less than 90 degrees. A biocide configured to inactivate hydrogen-consuming microbes is placed into the plurality of lateral wellbores and thereby into formation water that is flowed from the geological formation into the plurality of wellbores. Hydrogen gas effervesced from the formation water in the plurality of lateral wellbores is collected via the mother wellbore. The hydrogen gas is generated at least in part from a water reduction reaction of minerals of the geological formation with the formation water and risen through the plurality of lateral wellbores passively by buoyancy effects without pumping.

The invention discloses a method, a system, equipment and a medium for detecting an oil-water two-phase relative permeability curve, and belongs to the technical field of oil-gas field development technologies. The detection method of the oil-water two-phase relative permeability curve comprises the following steps: washing oil and drying a rock core sample, vacuumizing the rock core sample, and injecting formation water into the rock core sample, so that the rock core sample reaches a saturated water state; injecting crude oil into the core sample at a preset oil reservoir temperature to enable the core sample to reach a saturated oil state; performing water-displacing oil operation on the rock core sample at a preset flow rate, and scanning the rock core sample at a plurality of scanning nodes by using a CT (Computed Tomography) scanning device; oil saturation and water saturation are calculated according to an actually measured rock core CT value, and parameter fitting is performed on the Corey model according to the oil saturation and the water saturation to obtain an oil-water two-phase relative permeability curve. The method can accurately detect the oil-water two-phase relative permeability curve of the rock core.

The application discloses a method and system for predicting water inrush of sandified dolomite stratum under water-rich conditions, comprising: obtaining first detection data and second detection data; extracting first cross-section data and second cross-section data; the cross-section data is position data of a cross-section with discontinuity; comparing the first cross-section data and the second cross-section data, and taking a region with a difference greater than a preset value between the first cross-section data and the second cross-section data as a target drilling region; obtaining third cross-section data; forming cross-section fitting data of the target cross-section; and predicting construction water inrush risk. The method and system for predicting water inrush of sandified dolomite stratum under water-rich conditions effectively improve the advanced detection capability of sandified dolomite tunnel construction, improve construction safety and reduce construction risk by data fusion on the detection data in front of a tunnel face and accurate data acquisition and completion in combination with the advanced drilling technology.

The invention relates to a water-rock reaction mechanism in-situ measurement device and method, and belongs to the field of carbon dioxide geological sequestration experiment determination. The device comprises a formation water tank, a Raman probe, a reaction kettle, a vacuum pump, a gas tank, a formation water pipeline, a liquid circulating pump, a vacuum pipeline, a gas pipeline, a gas circulating pump, a connecting piece, a gas-liquid circulating pipeline and a sampling pipeline, wherein a sampler is arranged on the sampling pipeline. According to the invention, through combined arrangement of the formation water pipeline, the gas pipeline, the Raman probe and the pipeline where the connecting piece is located, real-time measurement of Raman spectrum data in the whole water-rock reaction process is realized; liquid and gas are mixed and circulated in the device in the water-rock reaction process by utilizing the combined arrangement of a gas-liquid circulating pipeline, a gas circulating pump and a liquid circulating pump, so that the accuracy of detection data is improved.

The application discloses a watered-out layer secondary interpretation method under the condition of small layer level oil-water interface understanding, and steps are as follows: step 1, small layer geological modeling and oil-water interface fine calibration; step 2, well logging data standardization and quality control; step 3, continuous calculation of small layer mixed formation water resistivity; step 4, completion of reservoir parameter quantitative calculation; step 5, obtaining of primary interpretation based on small layer oil-water interface; step 6, implementation of secondary iteration correction under the constraint of production dynamics; and step 7, output of interpretation results and application suggestions. The application belongs to the technical field of oilfield development well logging interpretation, and solves the problems that the prior art is not accurate in key parameter calculation, the interpretation process is single, and the precision and actual development demand are not matched.

The invention belongs to the technical field of oil-gas field development, and discloses a low-salinity formation water identification method, which comprises the following steps of: obtaining data corresponding to a test oil well through drilling data, and comparing step by step according to the obtained data to judge whether water is discharged from a formation; the invention further discloses a low-salinity formation water recognition device and equipment and a storage medium. The method is suitable for identifying the low-salinity formation water, whether water flows out of the formation or not is judged in real time by draining the test oil well, an important basis is provided for identifying the low-salinity formation water, and the defects of a formation water judgment method are overcome.

The invention discloses a method for establishing initial conditions of a gas reservoir through uniform initialization of a heterogeneous large rock plate model, and belongs to the technical field of gas reservoir development. On the basis that a conventional rock plate is provided with injection and production well inlets and outlets, the two sieve pipe injection channels are additionally arranged, the two ends of the sieve pipe are connected through the pipeline, and fluid can be injected into the sieve pipe; plugging or heating plugging removal operation is achieved by injecting a plugging agent into the four pipelines in good time, namely, an injection well and a production well are plugged firstly, formation water is injected through a screen pipe to make a rock plate saturated, and then formation water in the rock plate is displaced through gas injection of the screen pipe; the screen pipe is plugged, and a plugging removal injection and production well preparation experiment is carried out; the rock plate reaches an initial state of a gas drive / depletion experiment; the problem that the screen pipe becomes a high-permeability channel to affect a gas drive experiment and cause distortion of gas drive experiment data is avoided, the accuracy of a large flat plate model longitudinal heterogeneous gas reservoir water invasion failure or constant volume failure evaluation experiment can be improved, and the method has important significance on compact reservoir transformation and effective development.

The application discloses a reservoir gas-water relative permeability determination method, and relates to the field of reservoir permeability determination. The method comprises the following steps: obtaining a core sample of a target reservoir and determining the geometric size of the core sample; injecting simulated formation water into the core sample until the core sample is saturated, and performing nuclear magnetic scanning to obtain a reference nuclear magnetic signal and an initial porosity distribution; performing a multistage gas injection pressure experiment in an intermittent displacement mode to obtain quasi-steady-state displacement data; constructing a two-phase percolation numerical model with phase permeability curve parameters and capillary pressure curve parameters as to-be-inverted parameters; constructing a target function based on the quasi-steady-state data and performing inversion solving to obtain optimal parameters; and determining the phase permeability curve and the capillary pressure curve based on the optimal parameters. The application obtains the fluid distribution inside the core through nuclear magnetic resonance, obtains quasi-steady-state data in combination with intermittent displacement, and inversely solves the phase permeability and the capillary pressure, so that the problem that the fluid distribution inside the core cannot be accurately reflected and the multi-solution problem cannot be solved is solved, and the influence of the capillary end effect is eliminated.

The invention relates to the technical field of water-preserved coal mining, and discloses a water-preserved coal mining method for reinforcing a water-resisting layer by grouting and filling a separation layer area, which comprises the following steps of: determining a water-resisting layer to be reinforced by grouting according to stratum hydrogeological conditions disclosed by geological data in a coal mine exploration stage; before coal seam mining, drill sites are arranged in a mining area and the periphery of the mining area, vertical drill holes are constructed, and the vertical drill holes penetrate into a water-resisting layer to be subjected to grouting reinforcement; after vertical drilling construction is completed, hole washing is conducted, the final hole static water level is observed, the unit water absorption rate of an injected layer section is measured through a drilling water pressing test, and after the grouting technical standard is met, a horizontal jet hole is constructed through the radial jet hole forming technology; the static water level of the vertical drill hole is observed after grouting is completed, and coal seam mining is conducted according to a mining scheme determined by a coal mine after the static water level is stable; after a coal seam is mined and a rock stratum separation layer is formed, grouting drill holes are formed in the ground to fill a rock stratum separation layer area. According to the invention, the coal mining mode that the water-bearing layer above the water-resisting layer does not leak and the surface water source supply is not reduced can be realized.

A quantitative evaluation method for determining the influence of formation water salinity on shale gas reservoir reserves relates to the field of shale gas resource quantity and reserve evaluation, and solves the problem that the existing method is difficult to accurately describe the influence of formation water distribution and salinity on formation water, thereby making the result of calculating the formation gas reservoir reserves inaccurate. The method comprises the following steps: S1: collecting basic data of target shale layer in a target area, and constructing a shale reservoir model consistent with the real underground situation; S2: inserting shale gas into the shale reservoir model; determining the size of the methane gas reservoir in the model; S3: inserting methane gas molecules under different temperatures and pressures into the three numerical models of the reservoir, and recording the calculated methane gas reservoir quantity simulation value; S4: establishing a three-dimensional data coordinate system; S5: establishing a quantitative fitting relationship between the methane gas reservoir quantity simulation value and the underground pressure and salinity conditions. The quantitative evaluation method can accurately calculate the result of the formation gas reservoir reserves.

The utility model relates to the field of oil field production, in particular to a device for simulating the air injection oxidation effect of a water-containing oil reservoir, which comprises a containing bin, a first bottle body, a second bottle body and a third bottle body. The first end of the containing bin communicates with the first outlet valve and the second outlet valve. The first bottle body is communicated with the containing bin through a first pipeline and a first valve. The second bottle body is communicated with the containing bin through a second pipeline and a second valve. The third bottle body is communicated with the containing bin through a third pipeline and a third valve. And the first bottle body, the second bottle body and the third bottle body are respectively used for filling formation water, crude oil and air. The formation water, the crude oil and the air filled in the corresponding bottle bodies are fed into the accommodating bins through the corresponding pipelines, so that the air injection oxidation process of the water-containing oil reservoir can be simulated, and the problem that the oxidation effect of the formation water-containing oil reservoir is difficult to simulate due to the fact that injection of the formation water into the oil reservoir oxidation simulation system is not considered in the prior art is solved.

The invention discloses a quantitative evaluation method for resistivity heterogeneity of logging fusion formation water, and relates to the technical field of oil exploration and development. The method comprises the following steps of: obtaining formation signal data acquired by various logging and calculating reference formation water resistivity; a machine learning model is constructed based on feature data extracted from conventional logging, the formation water resistivity is a target variable of the machine learning model, and the machine learning model is trained to obtain a formation water resistivity prediction model; collecting conventional logging data, extracting feature data in the conventional logging data, inputting the feature data into the formation water resistivity prediction model, and outputting a formation resistivity prediction value; the formation resistivity prediction values of multiple depths form a continuous prediction curve to serve as a quantitative evaluation result of formation water resistivity heterogeneity, and the problem of accurate evaluation in the absence of nuclear magnetic resonance logging data is solved.

The invention discloses a tight oil reservoir depletion type development wave and region evaluation device and method. The device comprises a tight oil reservoir simulation system, a horizontal well system, a pressure monitoring system and a production system, the tight oil reservoir simulation system comprises a reservoir simulation device and a fluid injection device which are connected. The reservoir simulation device can be filled with sand grains in a layered manner so as to simulate a target tight oil reservoir; the fluid injection device is used for injecting simulated formation water and simulated formation oil; the horizontal well system comprises a plurality of horizontal wells; each liquid production pipe is connected with a corresponding horizontal well outlet and is connected with a produced liquid metering device; the pressure monitoring system comprises a signal processor, a pressure sensor and a plurality of pressure probes; and the plurality of pressure probes are arranged in the reservoir simulation device. According to the device, the distribution rule of the sweep area can be identified according to the pressure change, the recovery ratio corresponding to the sweep area can be obtained, and therefore sweep area evaluation is achieved through physical simulation, and production guidance is provided for depletion type development of tight oil reservoirs.

The invention relates to a three-dimensional heterogeneous formation water control oil extraction multi-parameter synchronous simulation experiment device which comprises a device body, a plug, a production pipe column and a sensor unit. The device body is of a coaxial multi-layer nested structure, a plurality of independent simulation units are constructed in an internal annular sand filling area through replaceable sieve pore partition plates, and heterogeneous stratum reconstruction of fluid communication and sand body isolation is achieved. The production pipe column adopts a modular water control short section series connection structure, a replaceable fluid sensitive valve and a tracer agent storage cabin are integrated, and performance evaluation and fluid traceability of multiple types of water control tools are achieved; the sensor unit synchronously acquires outlet, wall surface and radial gradient pressure through three-dimensional arrangement of mandrels with various lengths, and realizes multi-dimensional data collaborative analysis in combination with flow and water content monitoring. The problems that an existing device is difficult to restore complex fluid channeling physical characteristics and is single in monitoring dimension are solved, full-process high-fidelity simulation from stratum seepage to tool water control is achieved, and key technical support is provided for water control strategy optimization.

The invention provides an oil field well casing residual strength evaluation method and system based on numerical simulation, and relates to the technical field of oil field development casing safety evaluation. Based on the casing damage evaluation basic data of the target oil field block, establishing a block scale fluid-solid coupling numerical model reflecting an injection-production dynamic and formation mechanical response coupling relationship, and obtaining redistributed crustal stress field data around a shaft; redistributed crustal stress field data are used as boundary conditions, a three-dimensional coupling mechanical model containing a stratum, a cement sheath and a casing pipe is established in combination with the casing pipe structure and material parameters, and the stress distribution and the maximum equivalent stress of the casing pipe under the injection-production load effect are obtained through numerical simulation; and based on the maximum equivalent stress and the yield strength of the casing material, performing residual strength evaluation and damage risk grading on the casing according to the strength utilization rate and the residual strength coefficient. Therefore, the accuracy and the dynamic prediction capability of the residual strength evaluation of the oil field casing are improved, and a scientific decision basis is provided for casing damage treatment.

The invention discloses a saturation quantitative calculation method based on water flooded layer classification, which comprises the following steps: firstly, determining the type of a water flooded layer by using the resistivity of original formation water and the resistivity of injected water, and then determining the calculation range of the saturation according to the physical definition of the water saturation of the water flooded layer; according to the water flooded layer resistivity model, calculating the corresponding saturation when the formation resistivity is the minimum value, and after a solving interval is further subdivided, solving the saturation by adopting a dichotomy loop iteration method; and finally, comprehensively determining the water saturation of the water flooded layer according to the water flooding type, wherein most of parameters involved in the process can be directly obtained. The result obtained through the method is high in precision, high in universality, wide in practicability and low in dependence on data and models.

The present application relates to the field of oil and gas well logging, and particularly relates to a method, system and device for determining formation water salinity and a storage medium; well section data, rock-electricity parameters, well temperature curves, shale content curves and porosity curves of a well section are obtained; a first water saturation is determined according to the rock-electricity parameters, the porosity curves and the formation water resistivity; a second water saturation is determined according to the shale content curves, the porosity curves and the thermal neutron capture cross section; a minimum value of the square difference between the first water saturation and the second water saturation is calculated, and the value corresponds to the optimal formation water salinity. By simultaneously solving the resistivity and neutron lifetime data, the resistivity and thermal neutron capture cross section data can correct the influence of salinity on each other when reflecting the formation properties, thereby reducing the error caused by single data, more accurately determining the water saturation, and making the results more comprehensive and accurate.

The present application belongs to the field of oil and gas field development, and particularly relates to a nitrogen foam flooding method for fractured shale oil reservoirs; it solves the problems of long production cycle and difficult matrix production of current foam flooding technology; the technical scheme is: through physical simulation experiment, reservoir core, crude oil and formation water are obtained; first, wettability reversal experiment is carried out to determine the optimal effective time of wettability reversal agent, and imbibition experiment is carried out to determine the optimal well shut-in time; after establishing the initial oil saturation of the core, formation water flooding and foam flooding experiments are carried out in turn; cumulative oil production is recorded and oil displacement efficiency is calculated; finally, staged foam flooding experiment is carried out, and oil displacement efficiency is also calculated; after the experiment, the curves of oil displacement efficiency and time change of staged foam flooding, foam flooding and formation water flooding are compared and analyzed; the results show that the final oil displacement efficiency of staged foam flooding is the highest; the new method can significantly shorten the production lag period and improve the final oil displacement efficiency.

The present application relates to the technical field of oilfield development, and particularly relates to a gas well drainage spiral degassing composite sand prevention device, which comprises a sand prevention oil well pump, a lower oil pipe section connected to the lower end of the sand prevention oil well pump, a special-shaped variable buckle connected to the lower end of the lower oil pipe section, outer and inner connecting parts provided at the upper and lower ends of the special-shaped variable buckle, an outer connecting part at the lower end of the special-shaped variable buckle connected to a sand settling tail pipe assembly, the sand settling tail pipe assembly comprising at least one sand settling pipe and a bottom plug connected to the bottom end, and a central pipe assembly coaxially arranged in the sand settling pipe. The uppermost sand settling pipe is connected to a wire-wound screen pipe with a gap of 0.2 mm, thereby performing the first filtration on the formation water, and the special-shaped variable buckle is connected to a laser slotted sand control screen pipe with a gap of 0.15 mm, thereby performing the second filtration on the formation water, effectively preventing the sand particles with different particle sizes from entering the sand prevention oil well pump, and avoiding the sand sticking of the pump cylinder and the failure of the valve.

This invention discloses a system and method for measuring parameters affecting the drainage capacity of a gas storage facility undergoing aquatic redevelopment, comprising: a core holder for holding experimental cores; a water injection device for saturating the experimental cores with the held formation water; an outlet backpressure and measurement device for gradually reducing the pressure at the core outlet to a specified exhaustion lower limit pressure; a gas injection device for gas-driven operation on the cores whose outlet pressure has reached the exhaustion lower limit pressure; an inlet backpressure and measurement device for first injecting gas into the core inlet and then gradually reducing the pressure at the core inlet to measure the gas production and water production at each pressure point during the pressure reduction process when the inlet pressure drops to the specified exhaustion lower limit pressure; and a data processing device for calculating the dynamic recovery degree and dynamic expansion characteristics based on the water production and gas production at each pressure point.

The invention discloses a shale formation horizontal well drill string system dynamics simulation experiment device and method, and the device comprises a data collection system, a control system, and a power system, a drill string system, a rock breaking system and a drilling fluid circulation system which are connected in sequence. The data acquisition system is used for acquiring drilling pressure, rotating speed, torque, drilling footage, mechanical drilling speed and vibration acceleration of a well bottom and the ground in a rock breaking experiment in real time; and the control system is used for regulating and controlling the drilling parameters and the drilling fluid circulating pressure in the experiment process on line. The device can simulate the motion state of the drill bit and the drill string horizontally drilling into the shale stratum, accurately measure the vibration characteristics of the coupling system in real time, and provide experimental data support for subsequent research on the dynamics of the shale layer horizontal well drill bit-drill string coupling system.

The embodiment of the invention discloses a carbon dioxide injection pressure determination method and device based on carbon sequestration. The method comprises the following steps: determining reservoir closing pressure of a target reservoir; calculating a first breakthrough pressure of the carbon dioxide on the saturated formation water cover layer; according to the first breakthrough pressure and the reservoir stratum pressure on the upper portion of the target cap stratum, the cap stratum capillary closing pressure upper limit is calculated; and determining a carbon dioxide injection pressure upper limit according to the reservoir closing pressure and the capping capillary closing pressure upper limit. According to the scheme, it can be guaranteed that the carbon dioxide injection pressure does not exceed the reservoir closing pressure and does not exceed the upper limit of the capping layer capillary closing pressure, the determination precision of the carbon dioxide injection pressure is improved, and carbon dioxide leakage is reduced.

The utility model relates to artificial sand mud content detection technical field, and disclose a kind of artificial sand mud content detection device, including machine body, and for containing sand sample beaker, still include: rotation connection on the stirring shaft of machine body, hollow formation water inlet channel in stirring shaft inside, the side wall of bottom is equipped with the water outlet hole of intercommunication water inlet channel;Lifting connection on the base of machine body, for driving beaker to stirring shaft close or away;At least one water suction pipe, fixedly connected on the machine body, water suction pipe bottom extends into beaker, and water suction pipe water inlet end detachably connected with filter screen, filter screen is located in the side of water outlet hole;The utility model is through lifting base to facilitate beaker to dismount, hollow stirring shaft water injection cooperation side filter screen, utilize water flow scouring anti-blocking, ensure that drainage is smooth, and integrated water supply and water suction component realize automatic elutriation, replace manual operation, significantly improve detection efficiency and result accuracy, satisfy large quantities engineering detection demand.

The present application relates to a method and system for determining the preservation effect of a sealed frozen core sample based on nuclear magnetic resonance re-saturation contrast, and belongs to the technical field of unconventional oil and gas exploration and development. The method comprises the following steps: first, obtaining and processing the sealed sample, performing a first T1-T2 two-dimensional nuclear magnetic resonance test after thawing, immediately performing re-saturation treatment, and immediately performing a second test after saturation; second, dividing each hydrogen-containing component fluid into regions and extracting signal amounts; third, calibrating the fluids of formation water, crude oil and dodecane, establishing a conversion relationship between oil-water hydrogen signal amounts and volumes, and then obtaining the oil-water volumes under sealed and re-saturated states; fourth, comparing the difference between the total fluid amount under the re-saturated state and the total fluid amount under the sealed state with the total fluid amount under the re-saturated state, and obtaining a ratio, which is defined as a re-saturation response coefficient, for quantitatively evaluating the preservation degree of the original pore fluid. The method can ensure the accuracy and reliability of the test results.