CN114814160A - Rock fluid filling experimental device and method capable of realizing online observation - Google Patents
Rock fluid filling experimental device and method capable of realizing online observation Download PDFInfo
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- 239000011435 rock Substances 0.000 title claims abstract description 324
- 239000012530 fluid Substances 0.000 title claims abstract description 256
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- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 87
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- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 description 36
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Abstract
The invention provides a rock fluid filling experimental device and method capable of realizing online observation. The device includes: the device comprises a shell, a heating part, a rock fluid filling part and an observation window; the device comprises a shell, a heating part, a rock fluid filling part and an observation window; the rock fluid filling part comprises a transparent capillary and a rock core arranged in the transparent capillary; the rock fluid filling part is formed by nesting at least two transparent capillary tubes; the heating part is arranged in the shell, the rock fluid filling part penetrates through the shell and the heating part, and the heating part can heat the rock fluid filling part; the observation of the rock fluid filling section penetrating into the heating section can be achieved through the observation window.
Description
Technical Field
The invention relates to the technical field of petroleum and natural gas geology, deposit geology, fluid inclusion and microscopic analysis, in particular to a rock fluid filling experimental device and a rock fluid filling experimental method capable of realizing online observation.
Background
The density, solubility, viscosity, interfacial tension and other fluid properties of oil, gas and water fluids can be greatly changed under the condition of underground deep layer, and the oil, gas and water multiphase fluid migration mode is influenced. Therefore, the realization of observing the law of fluid migration under high temperature and high pressure is an important requirement in the geological field and the petroleum field, and is helpful for further understanding the deep fluid activity, the mineralization and the reservoir formation process.
At present, fluid migration experiments under high-temperature and high-pressure conditions are mainly performed by using a high-temperature and high-pressure holder, and a room fluid migration experiment is generally performed in a mode that a rock core is put into the holder and then fluid is injected from an inlet of the holder at a certain pressure or flow rate. In order to bear larger fluid pressure, the wall thickness of the kettle body is usually very thick, and the kettle body is mainly used for measuring parameters such as fluid flow rate and the saturation of fluid in rocks. The holder kettle body is invisible, and the filling process of the fluid in the rock pore space cannot be observed on line in real time.
Disclosure of Invention
Aiming at the defects of the prior art, the invention aims to provide a rock fluid filling experimental device capable of realizing online observation, which can be used for observing the change rule before and after rock filling under the condition of higher temperature and pressure and observing the fluid form of a contact interface between fluid and rock, thereby avoiding the defect that the high-temperature and high-pressure experiment cannot be observed online and visually.
In order to achieve the above object, the present invention provides a rock fluid filling experimental apparatus capable of realizing online observation, wherein the apparatus comprises:
the device comprises a shell, a heating part, a rock fluid filling part and an observation window; wherein the content of the first and second substances,
the rock fluid filling part comprises a transparent capillary and a rock core arranged in the transparent capillary;
the heating part is arranged in the shell, the rock fluid filling part penetrates through the shell, the heating part and the shell, and the heating part can heat the rock fluid filling part;
the observation of the rock fluid filling section penetrating into the heating section can be achieved through the observation window.
Among the above-mentioned rock fluid that can realize on-line observation fills the experimental apparatus, can move rock fluid along the direction of penetrating and fill the portion, realize adjusting the position that rock fluid fills the portion and penetrates in shell and the heating portion to realize using the observation window to observe each section of rock fluid filling portion.
In the above-mentioned rock fluid that can realize on-line observation fills experimental apparatus, thereby rock fluid fills portion and passes shell and heating portion and shell and can realize that rock fluid fills portion and shell and heating portion detachable connect together.
In the above rock fluid filling experimental device capable of realizing online observation, preferably, the number of the transparent capillaries is not less than 2, and the capillaries are nested together. More preferably, in the rock fluid charge, the length of the transparent capillary nested inside is less than the length of the transparent capillary nested outside. In this preferred embodiment, the cores may be placed in the transparent capillary tubes nested inside, or may be placed in the transparent capillary tubes nested outside, or some cores may be placed in the transparent capillary tubes nested inside, and some cores may be placed in the transparent capillary tubes nested inside.
In the above rock fluid filling experimental apparatus capable of realizing online observation, preferably, the transparent capillary is a quartz capillary.
In the above rock fluid filling experimental apparatus capable of realizing online observation, preferably, the heating part is a heating plate; in a specific embodiment, the heating plate comprises a metal plate and at least two heating rods arranged on the metal plate.
In the above rock fluid filling experimental apparatus capable of realizing online observation, preferably, the heating part is provided with a temperature acquisition member for acquiring the temperature of a contact position of the heating part and the rock fluid filling part. More preferably, the temperature acquisition member is used to acquire the temperature of a location in the heating portion in contact with the rock fluid charge and located near the viewing port.
In the above rock fluid filling experimental apparatus capable of realizing online observation, preferably, the heating portion is further provided with a temperature controller having a PID self-tuning function, so as to realize local accurate temperature control of the penetrated rock fluid filling portion.
In the above rock fluid filling experimental apparatus capable of realizing online observation, preferably, a heat insulation portion is provided between the heating portion and the housing. In a specific embodiment, the insulation portion comprises insulation wool.
In the rock fluid filling experimental device capable of realizing online observation, the diameter of the inner diameter of the transparent capillary is preferably 50nm-500 μm.
In the rock fluid filling experimental device capable of realizing online observation, preferably, the number of the transparent capillaries is 2, the capillaries are nested together, the inner diameter of the transparent capillary nested inside is 50nm-500nm, and the inner diameter of the transparent capillary nested outside is 50nm-500 μm. More preferably, the transparent capillary has an outer diameter of 100nm to 1000 μm.
In the rock fluid filling experimental device capable of realizing online observation, the length of the shell is preferably not more than 100mm, the width of the shell is not more than 100mm, and the height of the shell is not more than 100 mm. In the preferable scheme, the rock fluid filling experimental device capable of realizing online observation is small in size, and can be placed in instruments such as micro-Raman instruments and infrared instruments to perform online observation on physical and chemical properties, such as diffusion coefficients, wettability, breakthrough pressure, interfacial tension and other parameter measurement. Meanwhile, in the preferred scheme, the capillary tube can be placed on a microscope objective table due to small thickness, and the phase change condition and the migration condition of substances in the capillary tube are observed through the observation window by using a microscope, so that the image can be clearly seen in the working distance of the objective lens and the spectroscopic test is carried out.
In the above rock fluid filling experimental apparatus capable of realizing online observation, preferably, the length of the core is smaller than that of a transparent capillary tube for placing the core. When the rock fluid filling experimental device capable of realizing online observation is used for observing the process that fluid enters the rock core, the length of the rock core needs to be smaller than that of a transparent capillary tube for placing the rock core.
In the above rock fluid filling experimental apparatus capable of realizing online observation, the core may be obtained by: and processing the core sample by adopting a laser ablation technology to obtain the core with the diameter smaller than the inner diameter of the transparent capillary, namely the core required by the invention. The core disposed inside the transparent capillary tube may be bonded to the transparent capillary tube using glue. The method comprises the steps of drilling a large-scale core column (the diameter is larger than or far larger than 1mm) by using a mechanical drilling machine, fixing the lower part of the large-scale core column, performing rotary ablation on the upper part of the large-scale core column by using a laser beam (as shown in (a) in fig. 7), gradually ablating the large-scale core column to a target diameter, sleeving a micro capillary tube on the core column from top to bottom after ablation (as shown in (b) in fig. 7), and filling the small-scale core.
In the above-described visual fluid transport experiment apparatus, it is preferable that the quartz capillary tube is nested without welding. In one embodiment, the smaller diameter capillary is nested within the larger diameter capillary and placed directly within the capillary, and the outer surfaces of the smaller capillary may be glued to each other if the smaller capillary needs to be secured.
The invention also provides a rock fluid filling experimental method capable of realizing online observation, wherein the method is carried out by using the rock fluid filling experimental device capable of realizing online observation.
In the above rock fluid filling experiment method capable of realizing online observation, preferably, the method includes: and closing the outlet of the rock fluid filling part, heating the rock fluid filling part by using the heating part, injecting water into the rock fluid filling part at a preset temperature and a preset injection pressure, and observing the process of the water entering the core.
In the above rock fluid filling experiment method capable of realizing online observation, preferably, the method includes: and closing the outlet of the rock fluid filling part, heating the rock fluid filling part by using the heating part, filling oil into the rock fluid filling part at a preset temperature and a preset filling pressure, and observing the process of the oil entering the rock.
In the above rock fluid filling experiment method capable of realizing online observation, preferably, the method includes: after the rock core is saturated with water, heating the rock fluid filling part by using a heating part, closing an outlet of the rock fluid filling part, and injecting oil and/or gas into the rock fluid filling part at a preset injection pressure at a preset temperature; the process of fluid entering the core in the rock fluid-filled portion is observed, and/or the contact characteristics of oil and/or gas with water are observed. In the process, the temperature and the injection pressure can be determined according to the simulation requirement; for example, the determination may be made using conventional methods based on the conditions of the simulated formation, production conditions, and the like.
In the above rock fluid filling experiment method capable of realizing online observation, preferably, the method includes: after the rock core is saturated with oil, the rock fluid filling part is heated by the heating part, the outlet of the rock fluid filling part is closed, water and/or gas is injected into the rock fluid filling part at a preset temperature and a preset injection pressure, the process that the fluid in the rock fluid filling part enters the rock core is observed, and/or the contact characteristic of the water and/or the gas and the oil is observed. In the process, the temperature and the injection pressure can be determined according to the simulation requirement; for example, the determination may be made using conventional methods based on the conditions of the simulated formation, production conditions, and the like.
In the above rock fluid filling experiment method capable of realizing online observation, preferably, the method includes: after the rock core is saturated with water, the rock fluid filling part is heated by the heating part, an outlet of the rock fluid filling part is closed, gas is injected into the rock fluid filling part at a preset temperature and a preset injection pressure, and the contact relation of the interfaces of the gas, the water and the rock core is observed to determine a contact angle. More preferably, wettability is judged in terms of contact angle; when the contact angle is equal to 0, complete wetting; when the contact angle is less than 90 degrees, partial wetting or wetting is performed; when the contact angle is equal to 90 °, it is the boundary line between wetting and not; when the contact angle is more than 90 degrees, the paper is not wetted; when the contact angle is equal to 180 °, it is completely non-wetting. In the process, the temperature and the injection pressure can be determined according to the simulation requirement; for example, the determination may be made using conventional methods based on the conditions of the simulated formation, production conditions, and the like.
In the above rock fluid filling experimental method capable of realizing online observation, the fluid refers to a generic term of oil, gas and water, and the fluid for observing the migration process of the fluid in the rock fluid filling portion may include oil, gas and water.
In the above-described rock fluid filling experimental method capable of realizing online observation, water may be simulated formation water or actual formation water, such as brine, but is not limited thereto; the oil may use a simulated oil or an actual crude oil, but is not limited thereto.
In the above-mentioned rock fluid filling experiment method capable of realizing on-line observation, preferably, the observation is performed through the observation window using a microscope.
In the rock fluid filling experiment method capable of realizing online observation, the method preferably comprises the step of placing the rock fluid filling experiment device capable of realizing online observation inside a micro-Raman and/or infrared instrument to perform online observation on physical and chemical properties of the fluid, such as contact angle, wettability, interfacial tension, breakthrough pressure and other parameters.
In the above-mentioned rock fluid filling experimental method capable of realizing online observation, preferably, the method further comprises performing the above-mentioned processes at different temperatures.
In the above-mentioned rock fluid filling experimental method capable of realizing online observation, preferably, the method further comprises performing the above-mentioned processes at different injection pressures. More preferably, the method comprises: after the rock core is saturated with water, heating the rock fluid filling part by using a heating part, closing an outlet of the rock fluid filling part, and injecting gas into the rock fluid filling part at different injection pressures at a preset temperature so as to determine the breakthrough pressure of the rock core; for example, the minimum gas injection pressure at which bubbles can be observed at the outlet end of the core is determined as the breakthrough pressure of the core by observing the generation of the bubbles at the outlet end of the core; for example, the breakthrough pressure of the core may be determined by measuring the exit end gas composition of the core in water using laser raman or infrared spectroscopy.
In the visual fluid migration experiment method, the pipe diameter of the transparent capillary is selected and determined according to the simulation requirement.
The invention also provides a method for determining the gas diffusion coefficient, wherein the method is carried out by using the rock fluid filling experimental device capable of realizing online observation, wherein the rock fluid filling part comprises 1 transparent capillary tube and 1 core arranged in the transparent capillary tube, and the core divides the transparent capillary tube into two chambers, namely a chamber positioned in front of the inlet end of the core and a chamber positioned behind the outlet end of the core; the method comprises the following steps:
after the rock core is saturated with water, heating the rock fluid filling part by using a heating part, closing an outlet of the rock fluid filling part, injecting simulated gas into the rock fluid filling part at a preset injection pressure at a preset temperature, and controlling the pressure difference between the inlet end pressure and the outlet end of the rock fluid filling part to be less than 0.01 MPa;
determining the concentration difference of the simulated gas in the water at the rock core inlet end and the rock core outlet end at different moments until the concentration difference of the simulated gas in the water at the rock core inlet end and the rock core outlet end is zero;
and determining the diffusion speed of the simulated gas in the rock core based on the concentration difference of the simulated gas in the water at the inlet end and the outlet end of the rock core at different moments by combining the sectional area and the length of the rock core, the volume of the water before the inlet end of the rock core in the rock fluid filling part (note that the volume of the continuous gas column does not account for the volume) and the volume of the water after the outlet end of the rock core in the rock fluid filling part.
In the gas diffusion coefficient determining method, preferably, based on the concentration difference of the simulated gas in the water at the inlet end and the outlet end of the core at different times, the diffusion velocity of the simulated gas in the core is determined by combining the cross section and the length of the core, the volume of the water before the inlet end of the core in the rock fluid filling part and the volume of the water after the outlet end of the core in the rock fluid filling part according to the following formula:
wherein, the first and the second end of the pipe are connected with each other,
wherein D is the diffusion coefficient of the simulated gas in the rock sample, cm 2 ·s -1 ；ΔC 0 The concentration difference of simulated gas in water at the core inlet end and the core outlet end at the initial moment; delta C i The concentration difference of simulated gas in water at the rock core inlet end and the rock core outlet end at the moment i; t is t 0 Is the initial time, s; t is t i Time i, s; a is the sectional area of the core in cm 2 (ii) a L is the length of the core, cm; v 1 The volume of water in the rock fluid charge before the core entrance end (note that the continuous gas column volume does not account for this volume), cm 3 ；V 2 Volume of water, cm, in the rock fluid filling section after the exit end of the core 3 。
In the above gas diffusion coefficient determining method, preferably, determining the diffusion velocity of the simulant gas in the core based on the concentration difference of the simulant gas in the water at the core inlet end and the core outlet end at different times, in combination with the cross-sectional area and the length of the core, and the volume of the water before the core inlet end in the rock fluid filling section and the volume of the water after the core outlet end in the rock fluid filling section comprises:
determining diffusion time and natural logarithm values of relative concentration difference corresponding to different moments based on concentration difference of simulated gas in water at the rock core inlet end and the rock core outlet end at different moments; wherein the natural logarithm of the relative concentration difference is determined by the following formula:
in the formula, Y i Is the natural logarithm of the relative concentration difference at time i; delta C 0 The concentration difference of simulated gas in water at the core inlet end and the core outlet end at the initial moment; delta C i The concentration difference of simulated gas in water at the rock core inlet end and the rock core outlet end at the moment i;
performing linear simulation on the natural logarithm values of the relative concentration difference and the diffusion time corresponding to different moments, and determining the slope of the natural logarithm values of the relative concentration difference relative to the diffusion time;
determining the diffusion speed of the simulated gas in the rock core based on the slope of the natural logarithm value of the relative concentration difference relative to the diffusion time by combining the cross-sectional area and the length of the rock core, the volume of water before the inlet end of the rock core in the rock fluid filling part and the volume of water after the outlet end of the rock core in the rock fluid filling part; it is determined by the following formula:
wherein S is the slope of the natural logarithm of the relative concentration difference with respect to the diffusion time, S -1 (ii) a D is the diffusion coefficient of the simulated gas in the rock sample, cm 2 ·s -1 (ii) a A is the sectional area of the core in cm 2 (ii) a L is the length of the rock core, cm; v 1 Volume of water, cm, in the rock fluid filling section before the core entry end 3 ；V 2 For rock fluid fillingVolume of water, cm, behind the exit end of the mesocore 3 。
In the above method for determining a gas diffusion coefficient, preferably, determining the concentration difference of the simulated gas in the water at the core inlet end and the core outlet end at different times is performed by performing online observation using laser raman. In a specific mode, the concentration difference of simulated gas in water at the core inlet end and the core outlet end is directly characterized by using the spectral peak intensity difference of laser Raman spectrum. In a specific embodiment, determining the absolute value of the concentration of the simulated gas in water by using the peak intensity of a laser Raman spectrum of a concentration standard sample under the same condition and combining the laser Raman spectrum of the simulated gas in water at different moments, and further determining the concentration difference of the simulated gas in water at the inlet end and the outlet end of a rock core at different moments; wherein, the spectrum peak intensity of the Raman spectrum of the simulated gas has a linear relation with the concentration of the simulated gas.
In the above gas diffusion coefficient determining method, preferably, the simulated gas is methane. In the above-described gas diffusion coefficient determining method, it is preferable that the formation simulated brine be used for water separation.
The capillary tube can withstand relatively high fluid pressures due to its fine inner diameter (50nm-500 μm) (the inventors found that quartz capillary tubes can withstand up to 300Mpa of fluid pressure), and the transparent capillary tubes (e.g., quartz capillary tubes) are fully visible, can be observed and subjected to on-line spectroscopy under a microscope. According to the rock fluid filling experimental device capable of realizing online observation, provided by the invention, the real rock core is placed in the transparent capillary tube, so that the change rule before and after rock filling and the fluid form of the contact interface between the fluid and the rock can be observed. When the rock fluid filling experimental device capable of realizing online observation is used for carrying out a visual fluid migration experiment, conditions such as fluid pressure and flow rate of fluid at an inlet and an outlet can be controlled by injecting fluid such as oil, gas and water into the transparent capillary tube, so that the migration rules of the fluid in pores and at joints with different diameters can be realized, and the capillary tube is heated and pressurized to simulate underground high-temperature and high-pressure conditions; and the device can be connected with a micro-spectrum and other testing instruments to simulate a particle model to observe the phenomena of contact relation and contact angle of fluid interfaces of different rocks and fluid migration in different time, and can also be connected with a laser Raman spectrometer, an infrared spectrometer and the like to measure the component change of the fluid passing through the rocks on line.
Compared with the prior art, the technical scheme provided by the invention has the following beneficial effects:
1. placing a rock core in a transparent capillary tube to perform a rock fluid filling test, so as to realize the rock fluid filling test in a microscale; the defect that the high-temperature and high-pressure experiment cannot be observed on line and visually is overcome.
2. The capillary tube can bear high temperature and high pressure, the capillary tube can be heated through the heating part, and underground high temperature and high pressure conditions can be simulated by controlling the fluid pressure flow rate of the inlet and the outlet of the capillary tube and the like.
Drawings
Fig. 1 is a first structural schematic diagram of a rock fluid filling experimental apparatus capable of realizing online observation according to an embodiment of the present invention.
Fig. 2 is a schematic structural diagram two of the rock fluid filling experimental apparatus capable of realizing online observation according to an embodiment of the present invention.
Fig. 3 is a schematic diagram of a rock fluid filling part of the rock fluid filling experimental apparatus capable of realizing online observation according to an embodiment of the present invention.
FIG. 4 is a schematic diagram illustrating a contact angle test according to an embodiment of the present invention.
FIG. 5 is a diagram showing the exit end Raman spectrum change during rock diffusion coefficient measurement.
FIG. 6 shows V in capillary tube during rock diffusion coefficient measurement 1 And V 2 Schematic representation.
Fig. 7 is a schematic illustration of the processing of a core sample using a laser ablation technique.
Detailed Description
In order to make the objects, technical solutions and advantages of the embodiments of the present invention clearer, the technical solutions in the embodiments of the present invention will be described in detail and completely with reference to the drawings in the embodiments of the present invention. It is to be understood that the embodiments described are only a few embodiments of the present invention, and not all embodiments. All other embodiments, which can be derived by a person skilled in the art from the embodiments given herein without making any creative effort, shall fall within the protection scope of the present invention.
The principles and spirit of the present invention are explained in detail below with reference to several representative embodiments of the invention.
An embodiment of the present invention provides a rock fluid filling experimental apparatus capable of realizing online observation, wherein the apparatus includes:
the device comprises a shell, a heating part, a rock fluid filling part and an observation window; wherein the content of the first and second substances,
the rock fluid filling part comprises a transparent capillary and a rock core arranged in the transparent capillary; the heating part is arranged in the shell, the rock fluid filling part penetrates through the shell, the heating part and the shell, and the heating part can heat the rock fluid filling part; the observation of the rock fluid filling section penetrating into the heating section can be achieved through the observation window.
Furthermore, the number of the transparent capillaries is not less than 2, and the capillaries are nested together. Further, in the rock fluid charge, the length of the transparent capillary nested inside is less than the length of the transparent capillary nested outside. For example, the number of the transparent capillaries is 2, the capillaries are nested together, the inner diameter of the transparent capillary nested inside is 50nm-500nm, and the inner diameter of the transparent capillary nested outside is 50nm-500 μm (preferably, the outer diameter of the transparent capillary nested outside is 100nm-1000 μm).
Further, the transparent capillary is a quartz capillary.
Further, the heating part adopts a heating plate; further, the heating plate comprises a metal plate and at least two heating rods arranged on the metal plate.
Further, the heating part is provided with a temperature acquisition piece for acquiring the temperature of the contact position of the heating part and the rock fluid filling part; further, a temperature acquisition member is used to acquire the temperature of a position in the heating portion in contact with the rock fluid filling portion and located near the viewing port. The temperature acquisition part can be a thermocouple.
Further, the heating part is provided with a temperature controller having a PID self-tuning function.
Further, a heat insulation part is arranged between the heating part and the shell. For example, heat insulating cotton may be filled between the heating portion and the housing as the heat insulating portion.
Further, the length of the shell is not more than 100mm, the width is not more than 100mm, and the height is not more than 100 mm.
Further, the heating part can realize heating of not more than 300 ℃.
Referring to fig. 1 to 3, another embodiment of the present invention provides a rock fluid filling experimental apparatus capable of realizing online observation, wherein the apparatus includes: a housing 201, a heating section 202, a thermal insulation section 204, a rock fluid charging section 203, and a viewing window 205; wherein the content of the first and second substances,
the rock fluid filling part 203 comprises two transparent quartz capillary tubes which are nested together and three sections of cores which are arranged in the quartz capillary tubes; specifically, a rock core sample is denuded by laser denudation to obtain a No. 1 rock core, and the two rock cores are sequentially named as a No. 2 rock core and a No. 3 rock core; placing the No. 1 core into a small-diameter quartz capillary tube, then embedding the small-diameter quartz capillary tube into a large-diameter quartz capillary tube, and sequentially placing the No. 2 core and the No. 3 core into the large-diameter quartz capillary tube;
the heating part 202 is arranged in the shell 201, and a heat insulation part is arranged between the heating part 202 and the shell 201 and consists of heat insulation cotton; the shell 201 and the heating part 202 are drilled with holes with the diameter of 2mm for the rock fluid filling part 203 to pass through so as to realize that the rock fluid filling part 203 is detachably connected with the shell 201 and the heating part 202;
the heating section 202 enables heating of the rock fluid charging section 203; observation of the rock fluid charge 203 penetrating into the heating section 202 is enabled through the observation window 205;
the heating section 202 is provided with a thermocouple 2023 for collecting the temperature of a position in the heating section in contact with the rock fluid charging section 203 and located near the observation port 205; the heating part 202 is provided with a temperature controller with a PID self-tuning function, and the temperature precision is +/-0.5 ℃;
wherein the inner diameter of the transparent capillary tube nested inside is 50nm-500nm, the inner diameter of the transparent capillary tube nested outside is 50nm-500 μm, and the outer diameter of the transparent capillary tube nested outside is 100nm-1000 μm. The diameters of the three sections of rock cores are respectively 50nm-500nm, and the lengths of the three sections of rock cores are respectively 0.1mm-10 mm.
An embodiment of the invention provides a rock fluid filling experimental method capable of realizing online observation, wherein the method is carried out by using a rock fluid filling experimental device capable of realizing online observation shown in fig. 1-3; the method comprises the following steps:
step 1: the rock core is dried and then is loaded into the rock fluid filling part 203, and the rock fluid filling experimental device capable of realizing online observation is assembled;
step 2: installing a rock fluid filling experimental device capable of realizing online observation on a microscope observation platform; adjusting the microscope to enable the fluid filling process in the rock fluid filling portion 203 to be observable through the observation window 205 using the microscope; connecting the inlet of the rock fluid filling part 203 with an injection pump, and connecting the outlet of the rock fluid filling part 203 with a pressure limiting valve;
and step 3: heating the rock fluid charge 203 using the heating portion 202;
and 4, step 4: in a heating state, an outlet of the rock fluid filling part 203 is closed, saline is filled into the rock fluid filling part 203 at a preset filling pressure, and the migration process of the saline in the rock fluid filling part is observed by using a microscope;
and 5: filling the rock core saturated saline water into a rock fluid filling part 203 filled with saline water, and assembling a rock fluid filling experimental device capable of realizing online observation; then repeating the step 2 and the step 3;
closing an outlet of the rock fluid filling part 203, filling oil and/or gas into the rock fluid filling part 203 at a preset filling pressure, observing the process that the fluid in the rock fluid filling part enters the core by using a microscope, and observing the contact characteristics of the oil and/or gas and the water; when gas is injected into the rock fluid filling part 203 at a preset injection pressure, the contact relationship of the interfaces of the gas, the water and the rock can be synchronously observed and observed to determine the contact angle when the gas passes through the outer wall of the rock sample and the wall of the capillary; furthermore, the wettability can be judged according to the magnitude of the contact angle: 1) when theta is 0, completely wetting; 2) when theta is less than 90 degrees, partial wetting or wetting is performed; 3) when theta is 90 degrees, the boundary line between wetting and non-wetting is formed; 4) when theta is more than 90 degrees, the wetting is not performed; 5) when theta is 180 degrees, the film is not wetted completely;
step 6: filling the rock core saturated oil into the rock fluid filling part 203 filled with the oil, and assembling the rock fluid filling experimental device capable of realizing online observation; then repeating the step 2 and the step 3;
closing an outlet of the rock fluid filling part 203, filling water and/or gas into the rock fluid filling part 203 at a preset filling pressure, observing the process that the fluid in the rock fluid filling part enters the rock core by using a microscope, and observing the contact characteristics of the water and/or the gas and the oil;
and 7: the above steps 1 to 7 were repeated while changing the pressure and temperature.
In the method, the physical and chemical properties of the fluid, such as parameters of contact angle, wettability, interfacial tension, breakthrough pressure and the like, can be observed on line by combining instruments such as micro-Raman instruments, infrared instruments and the like;
in the above method, a schematic diagram of the contact angle test is shown in fig. 4.
In the method, the breakthrough pressure of the rock is obtained by observing bubble generation at the outlet end of the rock core in step 5 under different pressures, and/or measuring gas components in water at the outlet end of the rock core by using a laser Raman spectrometer or an infrared spectrometer, and recording the minimum gas injection pressure required by gas generated at the outlet end of the rock core.
An embodiment of the present invention further provides a method for gas diffusion coefficient, where the method is performed using a rock fluid filling experimental apparatus capable of achieving online observation, and the rock fluid filling experimental apparatus capable of achieving online observation used in this embodiment is different from the apparatus described in fig. 1 to 3 only in a rock fluid filling portion 203, the rock fluid filling portion 203 in the rock fluid filling experimental apparatus capable of achieving online observation used in this embodiment refers to fig. 6 that includes 1 transparent capillary and 1 core disposed inside the transparent capillary, and the core divides the transparent capillary into two chambers, a chamber located before an inlet end of the core and a chamber located after an outlet end of the core; the method comprises the following steps:
step 1: filling the rock core saturated saline water into a rock fluid filling part 203 filled with saline water, and assembling a rock fluid filling experimental device capable of realizing online observation; then installing a rock fluid filling experimental device capable of realizing online observation on a microscope observation platform; adjusting the microscope to enable the fluid filling process in the rock fluid filling portion 203 to be observable through the observation window 205 using the microscope; connecting the inlet of the rock fluid filling part 203 with an injection pump, and connecting the outlet of the rock fluid filling part 203 with a pressure limiting valve; heating the rock fluid charge 203 using the heating portion 202;
step 2: closing the outlet of the rock fluid charge 203, and injecting methane gas into the rock fluid charge 203 at a predetermined injection pressure; the pressure at the outlet end of the rock is adjusted to be the same as that at the inlet end of the rock through a back pressure device (the pressure difference is less than 0.01 MPa); testing the peak intensity of Raman spectra of methane gas in the brine at the inlet end and the outlet end of the rock core at different moments by using a laser Raman instrument (as shown in figure 5), and further determining the concentration difference of the methane gas in the brine at the inlet end and the outlet end of the rock core at different moments; until the concentration difference of methane gas in the brine at the core inlet end and the core outlet end is zero (namely, until the peak intensities of the Raman spectra measured at the core inlet end and the core outlet end are the same);
wherein the time when the methane gas starts to be injected is referred to as an initial time t 0 The concentration C of methane in the brine at the inlet end and outlet end of the core was measured at different times (i time) by laser Raman 1i And C 2i (ii) a The principle is that the relative concentration of methane gas in brine is obtained by calculating the peak intensity ratio of Raman spectrum, and under the same test condition, the spectrum peak intensity of Raman spectrum of methane gas and the methane gas concentration have linearityAnd (4) relationship.
And step 3: determining the diffusion speed of methane gas in the rock core based on the concentration difference of methane gas in the brine at the inlet end and the outlet end of the rock core at different moments by combining the cross section and the length of the rock core, the volume of the brine before the inlet end of the rock core in the rock fluid filling part and the volume of the brine after the outlet end of the rock core in the rock fluid filling part:
3.1 determining diffusion time and natural logarithm values of relative concentration difference corresponding to different moments based on concentration difference of methane gas in brine at the inlet end and the outlet end of the rock core at different moments; wherein the natural logarithm of the relative concentration difference is determined by the following formula:
in the formula, Y i Is the natural logarithm of the relative concentration difference at time i; delta C 0 The concentration difference of methane gas in brine at the inlet end and the outlet end of the rock core at the initial moment; delta C i The concentration difference of methane gas in brine at the inlet end and the outlet end of the rock core at the moment i;
3.2, performing linear simulation on the natural logarithm values of the relative concentration difference and the diffusion time corresponding to different moments by using a least square method, and determining the slope of the natural logarithm values of the relative concentration difference relative to the diffusion time; wherein the content of the first and second substances,
Δt i ＝t i -t 0 ，
in the formula, t 0 Is the initial time, s; t is t i Time i, s; Δ t i The diffusion time corresponding to the moment i, s;
the slope of the natural logarithm of the concentration difference with respect to the diffusion time corresponds to Y i ＝S·Δt i In the formula, Y i Is the natural logarithm of the relative concentration difference at time i; Δ t i The diffusion time corresponding to the moment i, s; s is the slope of the natural logarithm of the relative concentration difference with respect to the diffusion time, S -1 ；
3.3 determining the diffusion velocity of methane gas in the core based on the slope of the natural logarithm of the relative concentration difference relative to the diffusion time, combining the cross-sectional area and the length of the core, and the volume of brine before the inlet end of the core in the rock fluid filling part and the volume of brine after the outlet end of the core in the rock fluid filling part; it is determined by the following formula:
wherein S is the slope of the natural logarithm of the relative concentration difference with respect to the diffusion time, S -1 (ii) a D is the diffusion coefficient of methane gas in the rock sample, cm 2 ·s -1 (ii) a A is the sectional area of the core in cm 2 (ii) a L is the length of the core, cm; v 1 The volume of brine before the core entry end in the rock fluid-filled section (note that the continuous gas column volume does not account for this volume), cm 3 ；V 2 Volume of brine, cm, after the exit end of the core in the rock fluid-filled reservoir 3 。
The principle and the implementation mode of the invention are explained by applying specific embodiments in the invention, and the description of the embodiments is only used for helping to understand the method and the core idea of the invention; meanwhile, for a person skilled in the art, according to the idea of the present invention, there may be variations in the specific embodiments and the application scope, and in summary, the content of the present specification should not be construed as a limitation to the present invention.
Claims (23)
1. A rock fluid filling experimental device capable of realizing online observation, wherein the device comprises:
the device comprises a shell, a heating part, a rock fluid filling part and an observation window; wherein the content of the first and second substances,
the rock fluid filling part comprises a transparent capillary and a rock core arranged in the transparent capillary;
the heating part is arranged in the shell, the rock fluid filling part penetrates through the shell and the heating part, and the heating part can heat the rock fluid filling part;
the observation of the rock fluid filling section penetrating into the heating section can be achieved through the observation window.
2. The experimental device of claim 1, wherein the number of transparent capillaries is not less than 2, and each capillary is nested together.
3. The experimental apparatus of claim 2, wherein in the rock fluid charge, the length of the transparent capillary nested inside is less than the length of the transparent capillary nested outside.
4. The assay device according to any one of claims 1-3, wherein the transparent capillary is a quartz capillary.
5. An assay device as claimed in any one of claims 2 to 4, wherein the transparent capillary has an internal diameter of 50nm to 500 μm;
preferably, the number of the transparent capillaries is 2, the capillaries are nested together, the inner diameter of the transparent capillary nested inside is 50nm-500nm, and the inner diameter of the transparent capillary nested outside is 50nm-500 μm.
6. The experimental device of claim 1, wherein the heating part is a heating plate; preferably, the heating plate comprises a metal plate and at least two heating rods arranged on the metal plate.
7. An experimental device according to claim 1 or 6, wherein the heating part is provided with a temperature collector for collecting the temperature of the heating part at the position where the heating part contacts the rock fluid charging part.
8. The experimental apparatus of claim 7, wherein the temperature acquisition element is configured to acquire a temperature of a location in the heating portion in contact with the rock fluid charge and located near a viewing port.
9. The experimental device according to any one of claims 1 and 6 to 8, wherein the heating portion is further provided with a temperature controller having a PID self-tuning function.
10. The experimental device according to claim 1, wherein a heat insulating portion is provided between the heating portion and the housing.
11. The assay device of claim 1, wherein the housing has a length of no more than 100mm, a width of no more than 100mm, and a height of no more than 100 mm.
12. A rock fluid filling experiment method capable of realizing online observation, wherein the method is carried out by using the rock fluid filling experiment device capable of realizing online observation according to any one of claims 1 to 11.
13. The method of claim 12, wherein the method comprises: and closing the outlet of the rock fluid filling part, heating the rock fluid filling part by using the heating part, injecting water or oil into the rock fluid filling part at a preset temperature and a preset injection pressure, and observing the process of the water or the oil entering the core.
14. The method of claim 12, wherein the method comprises: after the rock core is saturated with water, heating the rock fluid filling part by using a heating part, closing an outlet of the rock fluid filling part, and injecting oil and/or gas into the rock fluid filling part at a preset injection pressure at a preset temperature; the process of fluid entering the core in the rock fluid-filled portion is observed, and/or the contact characteristics of oil and/or gas with water are observed.
15. The method of claim 12, wherein the method comprises: after the rock core is saturated with oil, the rock fluid filling part is heated by the heating part, the outlet of the rock fluid filling part is closed, water and/or gas is injected into the rock fluid filling part at a preset temperature and a preset injection pressure, the process that the fluid in the rock fluid filling part enters the rock core is observed, and/or the contact characteristic of the water and/or the gas and the oil is observed.
16. The method of claim 12, wherein the method comprises: after saturating the rock core with water, heating the rock fluid filling part by using a heating part, closing an outlet of the rock fluid filling part, injecting gas into the rock fluid filling part at a preset temperature and a preset injection pressure, and observing the contact relation of the interfaces of the gas, the water and the rock core to determine a contact angle;
preferably, wettability is judged by contact angle.
17. The method of claim 12, wherein the method comprises: after the rock core is saturated with water, the rock fluid filling part is heated by using the heating part, the outlet of the rock fluid filling part is closed, and gas is injected into the rock fluid filling part at different injection pressures at a preset temperature, so that the breakthrough pressure of the rock core is determined.
18. The method of any one of claims 12-17, wherein the observing is performed through an observation window using a microscope.
19. The method according to any one of claims 12 to 17, wherein the method comprises placing the rock fluid-filled experimental apparatus capable of realizing online observation according to any one of claims 1 to 11 inside a micro-raman and/or infrared instrument for online observation of physical and chemical properties of the fluid.
20. A method for determining a gas diffusion coefficient, wherein the method is carried out by using the rock fluid filling experimental device capable of realizing online observation according to any one of claims 1 to 11, the rock fluid filling part comprises 1 transparent capillary tube and 1 core arranged in the transparent capillary tube, and the core divides the transparent capillary tube into two chambers, namely a chamber located in front of the inlet end of the core and a chamber located behind the outlet end of the core; wherein, the method comprises the following steps:
after the rock core is saturated with water, heating the rock fluid filling part by using a heating part, closing an outlet of the rock fluid filling part, injecting simulated gas into the rock fluid filling part at a preset injection pressure at a preset temperature, and controlling the pressure difference between the inlet end pressure and the outlet end of the rock fluid filling part to be less than 0.01 MPa;
determining the concentration difference of the simulated gas in the water at the rock core inlet end and the rock core outlet end at different moments until the concentration difference of the simulated gas in the water at the rock core inlet end and the rock core outlet end is zero;
and determining the diffusion speed of the simulated gas in the rock core based on the concentration difference of the simulated gas in the water at the rock core inlet end and the rock core outlet end at different moments by combining the sectional area and the length of the rock core, the volume of the water before the rock core inlet end in the rock fluid filling part and the volume of the water after the rock core outlet end in the rock fluid filling part.
21. A method as in claim 20, wherein determining the diffusion rate of the simulant gas in the core based on the difference in concentration of the simulant gas in the core inlet end and the core outlet end water at different times, in combination with the cross-sectional area and the length of the core and the volume of water before the core inlet end in the rock fluid charge and the volume of water after the core outlet end in the rock fluid charge, is accomplished by the following equation:
wherein the content of the first and second substances,
wherein D is the diffusion coefficient of the simulated gas in the rock sample, cm 2 ·s -1 ；ΔC 0 The concentration difference of simulated gas in water at the core inlet end and the core outlet end at the initial moment; delta C i The concentration difference of simulated gas in water at the rock core inlet end and the rock core outlet end at the moment i；t 0 Is the initial time, s; t is t i Time i, s; a is the sectional area of the core in cm 2 (ii) a L is the length of the core, cm; v 1 Volume of water, cm, in the rock fluid filling section before the core entry end 3 ；V 2 Volume of water, cm, in the rock fluid filling section after the exit end of the core 3 。
22. A method as in claim 20, wherein determining the diffusion rate of the simulated gas in the core based on the difference in concentrations of the simulated gas in the water at the core inlet end and the core outlet end at different times, in combination with the cross-sectional area and the length of the core and the volume of water before the core inlet end in the rock fluid charge and the volume of water after the core outlet end in the rock fluid charge comprises:
determining diffusion time and natural logarithm values of relative concentration difference corresponding to different moments based on concentration difference of simulated gas in water at the rock core inlet end and the rock core outlet end at different moments; wherein the natural logarithm of the relative concentration difference is determined by the following formula:
in the formula, Y i Is the natural logarithm of the relative concentration difference at time i; delta C 0 The concentration difference of simulated gas in water at the core inlet end and the core outlet end at the initial moment; delta C i The concentration difference of simulated gas in water at the rock core inlet end and the rock core outlet end at the moment i;
performing linear simulation on the natural logarithm values of the relative concentration difference and the diffusion time corresponding to different moments, and determining the slope of the natural logarithm values of the relative concentration difference relative to the diffusion time;
determining the diffusion speed of the simulated gas in the rock core based on the slope of the natural logarithm value of the relative concentration difference relative to the diffusion time, and combining the cross-sectional area and the length of the rock core, and the volume of water before the inlet end of the rock core in the rock fluid filling part and the volume of water after the outlet end of the rock core in the rock fluid filling part; it is determined by the following formula:
wherein S is the slope of the natural logarithm of the relative concentration difference with respect to the diffusion time, S -1 (ii) a D is the diffusion coefficient of the simulated gas in the rock sample, cm 2 ·s -1 (ii) a A is the sectional area of the core in cm 2 (ii) a L is the length of the core, cm; v 1 Volume of water, cm, in the rock fluid filling section before the core entry end 3 ；V 2 Volume of water, cm, in the rock fluid filling section after the exit end of the core 3 。
23. The method as claimed in any one of claims 20 to 22, wherein determining the difference in concentration of the simulated gas in the water at the core entry end and the core exit end at different times is performed by online observation using laser raman.
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