CN115653554A - Micro-experiment method for removing retrograde condensation injury through gas injection based on micro-fluidic control - Google Patents
Micro-experiment method for removing retrograde condensation injury through gas injection based on micro-fluidic control Download PDFInfo
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Abstract
The invention discloses a micro experimental method for removing retrograde condensation injury by gas injection based on micro-fluidic. The method utilizes a microscopic model to simulate the processes of depressurization, retrograde condensation and gas injection for removing retrograde condensation damage of a condensate gas reservoir, a microscopic model is manufactured on a glass sheet by etching a real core pore throat structure extracted through experiments such as micro-nano CT scanning, cast sheet observation and the like, a microscope and a high-speed camera are used for observing and recording the distribution of condensate oil in the pore throat during the experiment, the pressure change of an inlet and an outlet of the microscopic model is monitored through a high-precision pressure sensor, and finally the gas-phase permeability change rule of the microscopic model during the experiment is obtained. Compared with the conventional core gas injection experiment, the experimental method can observe the condensate oil saturation change in the microscopic pore throat from the microscopic pore scale, greatly shortens the experimental period, reduces the consumption of experimental materials and labor cost, and can realize the development of a large number of indoor experiments in a short time to provide experimental data and theoretical guidance for the development and production of condensate gas reservoirs.
Description
Technical Field
The invention relates to the field of gas injection and anti-condensation pollution removal of condensate gas reservoirs, in particular to a micro experimental method for gas injection and anti-condensation damage removal based on micro-fluidic control.
Technical Field
The condensate gas reservoir has the characteristics of high economic value and high oil and gas reserves, but the exploitation means of the condensate gas reservoir is different from that of a common oil reservoir or a gas reservoir due to the complex phase characteristics of the condensate gas reservoir. When condensate gas reservoir development is carried out, condensate oil is separated out along with produced gas as the reservoir pressure is reduced to be lower than dew point pressure, and a large amount of condensate oil is accumulated in a near-wellbore area, so that the original seepage channel is blocked, and the gas phase permeability of the reservoir is reduced. The gas medium is injected into the stratum to supplement the stratum energy, which is a main means for reducing the retrograde condensation damage of the condensate gas reservoir and can effectively improve the recovery ratio of the condensate gas reservoir.
A method for evaluating and relieving the retrograde condensation damage of condensed gas reservoirs in compact sandstone condensate reservoirs [ J ] Daqing petroleum geology and development 2020,39 (2): 139-146) includes simulating the retrograde condensation phenomena of condensed gases with different condensate oil contents in near-well and far-well zones in the processes of depletion, depressurization, gas injection and pressure maintaining by using full-diameter cores or plunger cores of reservoirs, and evaluating the retrograde condensation damage degree of the condensed gases (Von Qianghan, dengbaokang, yangzhou, and the like). By establishing a gas drive two-dimensional physical sand filling model and observing the change of a two-dimensional seepage field in the gas drive process, the gas injection blockage removal and gas drive effects in a condensate gas reservoir large channel can be simulated. (ziguixue, li zhong ji, liu ping, etc.. Condensate gas reservoir gas drive two-dimensional sand filling physical model experiment research [ J ]. Fault block oil and gas field, 2022, (2): 164-170), wanhua, etc. researches the precipitation position, migration track and occurrence state of condensate oil in the failure process by etching cracks on a rock plate (CN 112682013A), and the main research area is cracks or holes, and the distribution change of the condensate oil in a capillary tube is not researched. The Li Zhongji et al uses the core to simulate the gas reservoir main model and the near-wellbore area model, and injects gas into the core to simulate the condensate gas reservoir blockage removing process, so as to achieve the purpose of controllable blockage removing effect (CN 105239973A). However, in all the methods, the damage degree of condensate oil reverse condensation is represented by testing the change of the permeability of the rock core or the change of the seepage characteristic in a macroscopic physical model, and the distribution change rule of the condensate oil in pores cannot be directly observed; in addition, a large amount of fluid samples are consumed in a conventional core experiment or a large-scale physical simulation experiment, the experiment period is long, and manpower and material resources are consumed greatly, so that a large amount of experiment comparison researches cannot be carried out. Therefore, in recent years, researchers have tried to analyze the damage of reverse condensation on permeability by observing the distribution of condensate oil in the microstructure of the core through a micro model. Tanshihong et al quantitatively characterize the microscopic pore throat radius of a digital core mainly through CT scanning, thereby etching glass models with different capillary radii, and taking the contribution of the blocked throat radius to permeability as permeability damage (CN 112966365A), but do not reflect the distribution condition of condensate oil in the actual reservoir rock pore throat structure and the effect of relieving retrograde condensation damage. For the above reasons, it is therefore necessary to provide a microfluidic-based micro-experimental method for gas injection decondensation damage.
The gas injection reduces the gas condensate saturation degree of reverse condensation separation to a certain degree, so that the research on the micro phenomenon that the gas injection removes the reverse condensation pollution of the gas condensate reservoir has great significance for the development of the gas condensate reservoir. Based on a micro-fluidic control method, the micro pore throat structure of the actual reservoir rock core is extracted through micro-nano CT scanning, cast body slice observation and other experiments, the representative micro pore throat structure of the actual reservoir rock is etched on the plate glass, the distribution change rule of condensate oil in the pore throat is further observed through the experiments, and the influence of gas injection on the retrograde condensation phenomenon in the retrograde condensation process is eliminated through research. The method utilizes a microscopic model to simulate the processes of depressurization, retrograde condensation and gas injection for removing retrograde condensation damage of a condensate gas reservoir, an image processing method is needed for manufacturing the model, a real core pore throat structure extracted through experiments such as micro-nano CT scanning, cast body slice observation and the like is etched on a glass slice, a microscope and a high-speed camera are used for observing and recording the distribution condition of condensate oil in pores in the experiment process, and a high-precision pressure sensor is used for detecting the pressure change rule of an inlet and an outlet of the microscopic model. Compared with the conventional core for developing gas injection experiments, the experimental method greatly shortens the experimental period, reduces the consumption of experimental materials and the labor cost required by the experiments, and can realize the development of a large number of experiments in a short time to provide experimental data and theoretical guidance for the development and production of field condensate gas.
Disclosure of Invention
The invention aims to provide a visual experimental method for gas injection and reverse condensation of a condensate gas reservoir, which mainly uses a high-speed camera to directly capture the seepage mechanism of fluid in a simulated pore channel. The method can intuitively and effectively observe the distribution and the change of the condensate oil in the pore-throat structure of the microscopic model during gas injection, and analyze the influence of the gas injection on the condensate gas reservoir reverse condensation phenomenon from a microscopic angle. The reverse condensation phenomenon is that when the reservoir pressure is lower than the dew point pressure, heavy hydrocarbon components in a gas phase can be subjected to phase state change and separated out in the form of condensate oil, so that the reservoir which is very compact becomes more blocked, the single-well capacity is continuously reduced, and even the phenomenon that oil and gas are not produced occurs.
The invention is realized by the following technical means.
The invention simulates the difference of the retrograde condensation injury degree under different gas injection conditions in the exhaustion type exploitation experimental process of the condensate gas reservoir by establishing a microcosmic displacement model, and masters the retrograde condensation injury degree and mechanism, which comprises the following steps:
(1) Micro-modeling
And extracting the pore throat structure of the core slice after CT scanning by using an image processing method. And respectively etching the pores and the throat of the extracted core slice on a glass sheet to obtain a micro model capable of representing the reservoir structure.
(2) Preparation of condensate gas
According to the oil and gas industry standard GB/T26981-2020 'oil and gas reservoir fluid physical property analysis method', the original formation temperature T of a target reservoir is used 0 (° c), original formation pressure P 0 (MPa) and GOR 0 (GOR 0 ＝V g /V o ) And (4) preparing a condensate gas sample by using the degassed crude oil and associated gas extracted from the condensate gas reservoir as standards. And (3) carrying out phase state test by adopting the prepared fluid sample under the conditions of formation pressure and temperature so as to test whether the prepared condensate gas meets the experimental conditions.
(3) Preparation of the experiment
Before the experiment begins, the instrument is corrected, cleaned, dried, tested at a moderate temperature and tested at a pressure. The holder is used for placing the plate glass micro model, the heating jacket is wrapped on the outer part of the holder to achieve the purpose of heating due to the particularity of the plate glass micro model, and the intermediate container is placed in the oven. In the experimental process, the condensate gas exhaustion speed is controlled by the outlet end pressure drop speed which is controlled by the pump withdrawing speed of the back pressure pump.
(4) To simulate target reservoir conditions, the experimental temperature is set to the target reservoir temperature T 0 The experimental pressure is set as the original formation pressure P of the target reservoir 0 (MPa), condensate gas is prepared under the original condition.
(5) Modeling system pressure
Putting the micro-model of the plate glass into a holder, and raising the temperature of the heating jacket and the oven to the original formation temperature T 0 In order to better simulate the pressure environment of the original condition, the environment of the glass micro model is filled with distilled water, then vacuum is simultaneously pumped from two ends of the glass sheet for 24h, and then the glass sheet is pumped from the inlet end at a speed V 1 (mL/min) injecting natural gas into the micro plate glass model, establishing system pressure, and gradually increasing the pressure to original formation pressure P by adjusting a back pressure valve 0 (MPa), observing a microscopic model in a saturated natural gas state after the pressure in the glass sheet is stable.
(6) Establishing original formation conditions
Switching the connection of the first inlet of the holder to the condensate vessel at an injection velocity V 2 (mL/min) displacing the saturated natural gas in the microscopic model, and measuring the oil production and the gas production at the outlet end, wherein the gas-oil ratio to be produced is stabilized to the original gas-oil ratio GOR 0 (m 3 /m 3 ) And when the gas sample is left or right, performing chromatographic analysis on the gas sample output from the outlet end. And when the gas composition at the outlet end is basically consistent with the composition of the compound condensate gas, the saturated condensate gas is finished, and a microscopic image of the microscopic model in the saturated condensate gas state is recorded.
(7) Depressurization and reverse condensation process of condensate gas
In order to simulate the condensate gas exhaustion decompression and reverse condensation process, an outlet end valve is opened, a back pressure pump is adjusted to reduce the pressure of the back pressure valve by 1MPa at each time, in the decompression process, a micro model is recorded once after the pressure of an inlet end and the pressure of an outlet end are stable, and then the next-stage pressure reduction is started. Condensate begins to appear in the pore throats of the micromodel as the pressure drops to the dew point pressure, and increases as the pressure drops.
(8) Gas injection to remove the damage of reverse condensation
To simulate the process of gas injection to relieve retrograde condensation injury, natural gas (or carbon dioxide) was continuously injected from the inlet of the micromodel. When the pressure reaches the design pressure, the pressure difference between the inside and the outside of the glass sheet is kept unchanged, meanwhile, the back pressure is increased to be always higher than the internal pressure, then the gas is continuously injected into the glass sheet, the gas injection speed is controlled by using a displacement pump, and the gas injection speed V is used 1 (mL/min) continuously injecting natural gas into the microscopic model from the inlet end, recording the microscopic core model for 1 time when the natural gas with a certain volume is injected, recording the time, the pressure at the two ends of the holder and the volume of condensate in the microscopic model, gradually reducing the condensate oil in the microscopic model along with the increase of injected gas, and stopping injecting gas and closing the displacement pump when the injected natural gas does not influence the change of the precipitated condensate oil quantity.
(9) Data processing
And processing the data of the completed experiment to obtain the gas phase relative permeability of the rock core at each stage of exhaustion pressure point and gas injection pressure. And processing the image recorded by the camera equipment through a computer, regarding the distribution of the condensate in the microscopic model as two-dimensional distribution, calculating the area ratio of the condensate in different images and the condensate saturation under different conditions, analyzing the condensate saturation, and calculating the relative gas-phase permeability according to the pressure and flow data recorded in the experiment.
Compared with the prior art, the invention has the following characteristics: (1) For some special condensate gas reservoirs, such as offshore condensate gas reservoirs or fracture condensate gas reservoirs, a large number of practical reservoir rock cores are difficult to obtain for developing rock core experiments, and the method provides a new physical simulation thought for evaluating the effect of gas injection and anti-condensate gas damage removal of the condensate gas reservoirs. (2) Compared with other inventions, the invention provides the processes of condensate gas reservoir reverse condensation and gas injection removal reverse condensation from a microscopic angle, and provides a quantitative and operable technical method and implementation steps. (3) The invention is equally applicable to the study of other hypotonic reservoirs. (4) Compared with a rock core experiment, the microfluidic experiment greatly reduces the time and material consumption required by the experiment.
Drawings
FIG. 1 is a flow chart of the experiment.
FIG. 2 is a graph of the depletion pressure versus the average condensate saturation during depletion.
FIG. 3 is a graph of the amount of gas injected in a continuous gas injection mode versus the average saturation of condensate.
FIG. 4 is a profile of condensate after continuous gas injection.
FIG. 5 is a profile of condensate after continuous gas injection.
FIG. 6 is a graph of the change in gas phase permeability under the conditions of raw pressure, maximum retrograde condensation pressure, and pressure after gas injection.
FIG. 7 is a graph showing the change in gas phase relative permeability under the conditions of original pressure, maximum retrograde condensation pressure, and pressure after gas injection.
In the figure: 1-a displacement pump; 2. 3-an intermediate container; 4. 11-back pressure pump; 5. 10-a back pressure valve; 7. 9-a vacuum pump; 6. 8-vacuum valve; 12-a separator; 13-a chromatograph; 14-a microscopic camera; 15-a computer; 16-fluorescent lamps; 17-baking oven; 18-heating jacket.
Detailed description of the invention
The invention is further illustrated below with reference to the figures and examples in order to facilitate the understanding of the invention by a person skilled in the art. It is to be understood that the invention is not limited in scope to the specific embodiments, but is intended to cover various modifications within the scope of the invention as defined and defined by the appended claims, as would be apparent to one of ordinary skill in the art.
The invention adopts a plate glass microscopic model to simulate the condensate gas reservoir depletion type exploitation experiment process, carries out continuous gas injection development simulation experiment, observes the distribution of condensate oil in the pore throat structure of the rock core through scanning equipment, discusses the influence of gas injection on the anti-condensation degree of the rock core, and grasps the anti-condensation damage degree and mechanism from a microscopic angle.
The process mainly comprises an injection pump system, a holder, a back pressure regulator, a pressure difference meter, a vacuum system, a temperature control system, a liquid fraction collector, a gas meter, a gas chromatograph and a visual data acquisition device. The holder mainly comprises an outer cylinder, a heating sleeve and an axial connector.
Examples
(1) Micro-modelling
And extracting the pore throat structure of the core slice after CT scanning by using an image processing method. And respectively etching the pores and the throat of the extracted core slice on a glass sheet to obtain a microscopic model capable of representing the reservoir structure.
(2) Preparation of gas condensate
According to the oil and gas industry standard GB/T26981-2020 'oil and gas reservoir fluid physical property analysis method', the original formation temperature of a condensate gas reservoir BZ19-6-2Sa well in Bohai is 152 ℃, the original formation pressure is 46.93MPa and the original gas-oil ratio is 1150m 3 /m 3 And (4) preparing a condensate gas sample by using the degassed crude oil and associated gas extracted from the condensate gas reservoir as standards. And (3) carrying out phase state test by adopting the prepared fluid sample under the formation pressure and temperature, and testing whether the experimental conditions are met.
TABLE-separator gas sample chromatography test results
(3) Before the experiment begins, the instrument is corrected, cleaned and dried, and subjected to temperature and pressure tests. The holder is used for placing the plate glass micro model, the heating jacket is wrapped on the outer part of the holder to achieve the purpose of heating due to the particularity of the plate glass micro model, and the intermediate container is placed in the oven. In the experimental process, the condensate gas exhaustion speed is controlled by the outlet end pressure drop speed which is controlled by the pump withdrawing speed of the back pressure pump.
(4) To simulate target reservoir conditions, the experimental temperature is set to the target reservoir temperatureThe temperature is 152 ℃, the experimental pressure is set as the original formation pressure of a target reservoir of 46.93MPa, condensate gas is prepared under the original condition, the gas-oil ratio is 1150m 3 /m 3 (i.e., the original gas-oil ratio) and the maximum retrograde condensate saturation pressure P is measured 1 ＝23MPa。
(5) Connecting the inlet end of the clamp holder with an intermediate container and an injection pump, correcting an instrument, cleaning and drying, testing temperature and pressure, wherein the intermediate container is respectively filled with natural gas and condensate gas, the outlet end of the intermediate container is respectively connected with a back pressure valve and a separator, the back pressure valve is connected with a back pressure pump, the separator is connected with a gas meter, pressure meters and a sound wave transmitting and receiving device are arranged at the two ends of the clamp holder, and are simultaneously connected with a confining pressure pump, the clamp holder is wrapped by a heating sleeve, the intermediate container is positioned in an oven, and the temperature of the oven and the heating sleeve is increased to 152 ℃ of the original stratum temperature.
(6) Putting a plate glass microscopic model into a holder, simultaneously vacuumizing for 24h from two ends of the model after confining pressure is increased to 3MPa, then injecting natural gas into the model from an inlet end at the speed of 0.1mL/min, gradually increasing the pressure to an experimental pressure of 46.93MPa by adjusting a back pressure valve, keeping the confining pressure higher than the pore pressure by 5MPa all the time in the process, and recording a model image in a saturated natural gas state after the pressure in the holder is stable and unchanged.
(7) Switching the first inlet connecting port of the clamp to a condensate gas container, displacing the saturated natural gas in the model at an injection speed of 0.05mL/min, metering the oil production and the gas production at the outlet end, and stabilizing the gas-oil ratio to be produced to 1150m 3 /m 3 And when the gas sample is left or right, performing chromatographic analysis on the gas sample output from the outlet end. And when the gas composition at the outlet end is basically consistent with the composition of the compound condensate gas, the saturated condensate gas is finished, and a model image in a saturated condensate gas state is recorded.
(8) And opening the outlet end valve, adjusting the back pressure pump to reduce the pressure of the back pressure valve by 1MPa every time, scanning the model once after the pressure of the inlet end and the outlet end is stable and unchanged in the pressure reduction process every time, and then starting the next-stage pressure reduction.
(9) The depletion was continued until the pressure dropped to around the maximum retrograde condensation pressure (33 MPa), and model images in the maximum retrograde condensation state were recorded.
(10) And after the pressure is reduced to be near the maximum retrograde condensation pressure, the displacement pressure and the displacement differential pressure are kept unchanged, the simulation of continuous gas injection development is started, the gas injection speed is controlled by using the displacement pump, 0.5HCPV natural gas is continuously injected into the micro model from the inlet end at the gas injection speed of 0.01mL/min, 1-time recording is carried out on the micro model by using a visual data acquisition device every time 0.1HCPV is injected, and the time, the pressure at two ends of the clamp holder, the oil production amount, the gas production amount and other parameters are recorded. And when the gas injection amount reaches 0.5HCPV, stopping gas injection, and turning off the displacement pump.
(11) Data processing
And processing the data of the completed experiment to obtain the gas logging permeability of the rock core at each stage of exhaustion pressure point and gas injection pressure. And processing the images recorded by the camera equipment through a computer, regarding the distribution of the condensate in the microscopic model as two-dimensional distribution, calculating the area ratio of the condensate in different images and the condensate saturation under different conditions, and analyzing the condensate saturation.
Analysis of Experimental results
The method comprises the steps of firstly simulating the retrograde condensation of a condensate gas reservoir during stratum failure, and then simulating the process of removing retrograde condensation injury by continuous gas injection to obtain condensate oil distribution in different pore throats.
The observation result obtained by the method is not difficult to see, and when the formation pressure of the target gas field is lower than the dew point pressure, condensate oil can be gradually separated out and blocks a capillary with the throat radius on the glass model, so that the permeability of the reservoir is gradually reduced. After the gas injection is started, the fluidity of the condensate is increased, and the condensate is subjected to a reverse evaporation effect, so that the condensate content in the image is reduced, and the reservoir permeability is increased.
Claims (5)
1. A micro experimental method for removing retrograde condensation injury by gas injection based on micro-fluidic sequentially comprises the following steps:
(1) Manufacturing a microscopic model, and etching a real core pore throat structure extracted by micro-nano CT scanning, cast slice observation and other experiments on a glass slice to obtain the microscopic model capable of representing the pore throat structure characteristics of the reservoir;
(2) In order to better simulate the pressure environment of the original condition, under the original temperature and pressure condition, the environment of the glass micro model is filled with distilled water, then the glass is simultaneously vacuumized from the two ends of the glass sheet, and then the glass sheet is pumped from the inlet end at the speed V 1 (mL/min) injecting natural gas into the micro plate glass model, establishing system pressure, and gradually increasing the pressure to original formation pressure P by adjusting a back pressure valve 0 (MPa)；
(3) Switching the injection gas from natural gas to condensate gas at an injection velocity V 2 (mL/min) displacing the saturated natural gas in the microscopic model, and measuring the oil production and the gas production at the outlet end, wherein the gas-oil ratio to be produced is stabilized to the original gas-oil ratio GOR 0 (m 3 /m 3 ) When the gas composition at the outlet end is basically consistent with the composition of the compound condensate gas, the saturated condensate gas is finished, and an image of the saturated condensate gas state in the microscopic model under a microscope is observed and recorded;
(4) In order to realize the gas condensate decompression and reverse condensation process, an outlet end valve is opened, a back pressure pump is adjusted to reduce the pressure of the back pressure valve by 1MPa each time, in the decompression process, after the pressure of an inlet end and the pressure of an outlet end are stable and unchanged, a micro model is recorded once, then the next-stage pressure reduction is started, when the pressure is reduced to the dew point pressure, condensate oil begins to appear in the pore throat of the micro model, and when the precipitated condensate oil quantity is stable, the pressure is not reduced continuously;
(5) In order to simulate the process of relieving the retrograde condensation injury by gas injection, after (4) is finished, the speed V is set 1 (mL/min) continuously injecting natural gas into the microscopic model from the inlet end, recording the microscopic core model for 1 time when the natural gas with a certain volume is injected, recording the time, the pressure at the two ends of the holder and the volume of condensate in the microscopic model, gradually reducing the condensate oil in the microscopic model along with the increase of injected gas, and stopping injecting gas and closing the displacement pump when the injected natural gas does not influence the change of the precipitated condensate oil quantity.
(6) And (5) obtaining the gas logging permeability of the rock core under each stage of failure pressure points and gas injection pressure according to the data obtained in the steps (4) and (5). And processing the images recorded by the camera equipment through a computer, regarding the distribution of the condensate in the microscopic model as two-dimensional distribution, calculating the area ratio of the condensate in different images and the condensate saturation under different conditions, and analyzing and comparing the condensate saturation.
2. The microfluidic-based microcosmic experiment method for removing gas injection anticoagulation damage according to claim 1, wherein in the step (1), an image processing method is used to comprehensively extract a core pore throat structure and a core casting sheet microscopic pore throat structure after micro-nano CT scanning, the determined core micro pore throat structure is etched on plate glass and packaged to manufacture a microfluidic model.
3. The microfluidic-based microcosmic experiment method of gas injection desorption/desorption damage of claim 1, wherein in step (2), when the microscopic model of flat glass is placed in the holder and heated by using the heating jacket and the oven, the same pressure is applied to both ends of the holder to avoid the glass sheet from breaking.
4. The micro-fluidic based microcosmic experiment method for removing gas injection and retrograde condensation injury of claim 1, wherein in the step (3), the condensate gas is used according to the oil and gas industry standard GB/T26981-2020 "hydrocarbon reservoir fluid physical property analysis method", and the original formation temperature T of the target reservoir is used 0 (° c), original formation pressure P 0 (MPa) and GOR of raw gas-oil ratio 0 (GOR 0 ＝V g /V o ) As a standard, prepared from degassed crude oil and associated gas produced in condensate reservoirs.
5. The micro experimental method for micro fluid control-based gas injection decondensation damage, according to claim 1, wherein in the step (5), the pressure is increased along with the gas injection, when the design pressure is reached, the pressure difference between the inside and the outside of the glass sheet is kept unchanged, the back pressure is always increased to be higher than the internal pressure, then the gas is continuously injected into the glass sheet, and the gas injection speed is controlled by using a displacement pump.
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Cited By (5)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN115219739A (en) * | 2022-07-26 | 2022-10-21 | 西南石油大学 | Experimental method for simulating condensate gas reservoir anti-condensate damage based on micro-fluidic control |
| CN116291407A (en) * | 2023-02-17 | 2023-06-23 | 西南石油大学 | Device and method for testing gas phase reverse condensate saturation and damage of oil reservoir type gas storage |
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| CN116468188B (en) * | 2023-06-19 | 2023-09-01 | 西南石油大学 | Dynamic prediction method for paraffin precipitation phase state of condensate gas reservoir in constant volume failure |
| CN117969585A (en) * | 2024-03-28 | 2024-05-03 | 中国石油大学(华东) | Device and method for measuring oil-gas phase state and characteristic parameters in micro-nano pore |
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